RU2749138C1 - Clamp sleeve with ball expandable seal and / or radially expandable petals - Google Patents

Abstract

FIELD: hydraulics.SUBSTANCE: invention relates to a downhole tool that is used in hydraulic fracturing. The lip valve has a valve body, a sliding sleeve and a clamping sleeve. The valve body has one or more fluid openings in its upper borehole sidewall portion. The sliding sleeve is movable between a closed position upbore in which one or more fluid openings are closed, and an open position downhole in which one or more fluid openings are open. The clamping sleeve contains an expandable metal part near the end of the clamping sleeve located up the wellbore, and a ball seat having a ball seat surface that is inclined inward in a radial direction from top to bottom along the wellbore at an acute angle to the longitudinal axis of the clamping sleeve. The expandable part is configured to expand outward in a radial direction under pressure acting on the ball seated in the specified seat, which forms a seal at the point of contact between the clamping sleeve and the longitudinal channel of the sliding sleeve when the clamping sleeve is located in the sliding sleeve. To perform the method, the flow of the clamping sleeve is initiated downward into the wellbore and is fixed in the channel of the sliding sleeve, the ball flows downward into the wellbore and the ball is seated in the saddle. A first fluid pressure is applied to press the ball against the seat and expand the portion of the clamping sleeve in the area of the seat radially outward to form a seal at the point of contact between the clamping sleeve and the sliding sleeve. A second fluid pressure is applied to shear the shear pins and move the sliding sleeve down the wellbore and open the hole.EFFECT: increased reliability of the sequential engagement and displacement of the valve.29 cl, 76 dwg, 1 tbl

Description

The technical field to which the present invention relates

The present invention generally relates to a downhole tool that is used in hydraulic fracturing, and in particular to flow-through clamping sleeves that are used to actuate lip valves to open selected holes in a production string.

Prior art of the present invention

Downhole tools are widely used in the oil and gas industry. Many downhole tools have valves that are pressure actuated. Thus, the known technical solution for a ball-actuated collar valve provides for a tubular valve body with a channel, a sliding sleeve enters this channel. A ball seat is provided in the upper wellbore portion of the sliding sleeve and is initially designed to be in a closed position uphole, in which position it closes one or more fluid openings on the sidewall of the valve body. To actuate the lip valve, a ball is dropped and firmly seated on the ball seat of the sliding sleeve. Fluid pressure is then applied to the ball to open the sliding sleeve in the downhole portion so as to expose the fluid openings in the valve body.

During hydraulic fracturing, one or more ball-actuated lip valves may be used to fracture subterranean formations. However, the problem of sequential activation of a plurality of ball-actuated cup valves for the purpose of hydraulic fracturing is that the bore of the cup valve down the wellbore must be smaller than the bore of the cuff valves upstream of them in the wellbore so that the ball is smaller. size passes through these lip valves located higher up the wellbore and into the desired lip valve down the wellbore. In other words, the bores of the sequential lip valves must be reduced in the downhole direction in order to ensure trouble-free operation, thereby resulting in a decrease in flow rate at the downhole end.

US Pat. No. 4,043,392 to Gazda discloses a downhole system for selectively securing downhole tools along a conductive bore in a wellbore and a toolbox for use in a flow conductive bore, including a docking core, collar shear, and relief valve. The Selective Retention System features a slotted profile for seating and retention, including stops facing both up and down. One type of retention system is a spool valve and includes a cam release mechanism to release the selector and the detent key when the spool valve is moved between positions that are longitudinally spaced apart from each other. Another form of shutoff system may be located along the mounting tube and may require the downhole tool to be disengaged to release the selector and locking tools. The sleeve shifter provides devices for opening and closing the spool valve, including keys with stops facing up and down, and a profile with slots that are compatible with a profile with slots to seat and lock the slide valve or with slots in the mounting tube. The coupling shear device can also be used as a splice core. Selectivity is ensured by changing the fit and retention profiles and key profiles.

According to US Pat. No. 4,043,392, the spring-loaded key profiles are mutually exclusive. The key profile will only engage with a spool valve having a mating inner profile.

US Pat. No. 4,436,152 to Fisher et al. Discloses an improved pusher that connects to a downhole tool kit and is suitable for engaging a sliding sleeve and placing it in a sliding sleeve assembly in a wellbore conductive bore. Selective profiled pusher keys provide a better fit and greater contact area between the keys and sliding sleeves. When the engaged sliding sleeve cannot be moved upward and the follower does not automatically disengage, emergency disconnect means may be applied by applying an upward force to the follower and sufficient to shear the pins, with all keys at both ends retracted inward for complete disconnection. in order to remove the pusher from the sliding sleeve device.

Collins US Pat. No. 5,305,833 discloses a slide valve pusher for use in oil and gas wells that has locking latches that are used to selectively position and engage a stopper within the valve. The main keys engage and selectively move the sliding sleeve to the leveling position and also prevent premature movement to the fully open position. Also included is a device to selectively prevent movement after alignment. Additional keys move the main keys in the direction of travel, grip the sleeve and move it to the fully open locked position. It also selectively decouples the pusher from the spool valve, allowing the pusher to be removed from the well. In addition, a method of selectively and sequentially moving a slide sleeve for a spool valve from a closed position to an equalizing position and then from an equalizing position to a fully closed position is described.

In particular, US Pat. No. 5,305,833 discloses two separate spring-loaded keys, wherein the first of the two keys can fit the profile of the second of the two keys. However, the second key cannot match the profile of the first key.

US Pat. No. 5,309,988 to Shy et al. Discloses an underground well rate control system that includes a number of movable collar flow control devices that are installed in a conductive well bore in different fluid-containing fractured zones, and a pusher moving through the bore and suitable for selectively moving any selected number of sleeve portions in flow control devices in any direction between their open and closed positions, without removing the tool from the channel. Sets of radially retractable anchors and shear keys are inserted into the openings of the side walls of the tool body, and are accordingly adjusted to engage in a fixed engagement with the sets of grooves on the inner side of the body and movable clutch parts of any of the flow control devices. The key sets are spring-loaded radially outward in the direction of the extended positions, and an electromechanical drive system located in the tool body is designed to extend the key sets radially and move the shear key set axially towards or away from the anchor key set. This allows the tool to be moved into and through any flow control device in any direction along the axis, while the tool is fixed to this device, it is operated to move the sleeve parts completely or partially in any direction, and then disconnected from the flow control device and moved. to any other flow control device to move its sleeve. The interlocked triangular threaded connections on the body and sleeve portions of each of the flow control devices temporarily fix the sleeve portion in the partially offset position.

US Pat. No. 5,309,988 also describes two mutually exclusive key profiles.

US Pat. No. 5,730,224 to Williamson et al. Discloses an underground structure for accessing an adjusting tool to a sidetrack extending from a wellbore. In the subterranean structure, a transition sleeve is provided, which is located in the wellbore near the hole in the lateral wellbore and which has an access window through it to provide the tool access to the horizontal well through this hole. The transfer sleeve is also equipped with a sliding access control device coaxially connected to it. The kit also includes a switch that can engage with the sliding access control device to cause the sliding access control device to slide between an open position, where the tool can pass through the window and hole and into the sidetrack, and a closed position, in where the tool cannot pass through the window and hole and into the lateral wellbore. This patent also describes a method for controlling tool access to a lateral wellbore extending from a wellbore. The preferred method includes the steps of: 1) positioning the collar in the wellbore close to the hole in the lateral wellbore, wherein the collar has an access window through which the tool can be accessed into the lateral wellbore, the collar additionally has a movable access control device, connected to it coaxially; 2) engagement of the movable access control device and the sliding device for smooth movement of the movable access control device relative to the transfer sleeve; and 3) smooth movement of the movable access control device between an open position, in which the tool can pass through the window and hole and into the lateral wellbore, and a closed position, in which the tool cannot pass through the window and hole into the lateral wellbore.

US Pat. No. 5,730,224 describes two bushing profiles, one being the opposite of the other.

Murray, US Pat. Nos. 7,325,617 and US Pat. Nos. 7,552,779 describe a system that allows sequential treatment of portions of a zone. Each part can be accessed using a sliding sleeve that has a defined internal profile. Plugs can be used, pushed along the drill string, which have a certain profile and fix the plug on a certain sleeve. The pressure on the plug, which is in the fixed state, allows the couplings to be sequentially opened, while the already treated areas below are isolated. Plugs pushed down the drill string have a hole initially bridged with material that will fade over time in the anticipated downhole conditions. As a result, when all parts of the zone have been treated, fluid flow through the various fixed plugs is restored. Plugs can also be blown out of the sliding sleeve after use, and they can be equipped with a key that subsequently prevents the plug from rotating on its axis if it is later required to be drilled out.

US Pat. No. 9,611,727 to Campbell et al. Discloses an apparatus and method for hydraulic fracturing in a well drilled in an oil and gas bearing rock mass. The device provides a valve assembly with sections of the casing that forms the borehole support. The valve assembly provides a sliding piston that is secured in place to isolate ports that provide connectivity between the interior of the well casing and the pay zone in the rock formation. A lip-sealed dart may be lowered into the well casing and propelled by the pressure of the fracturing fluid until the dart reaches the valve assembly and blocks the well casing below the valve assembly. The pressure of the fracturing fluid on the dart and its lip seal pushes the piston downward, it shears the pins and opens the holes. The fracturing fluid can then escape from the holes and cause fractures in the pay zone of the rock strata.

US Pat. No. 9,739,117 to Campbell et al. Discloses a method and apparatus for selectively activating a downhole tool in a pipe. The actuator has an actuator mandrel with a bore passing through the actuator and a bypass and a key for selective engagement with the downhole tool. The downhole tool has one or more profiled receivers adapted to actuate the downhole tool. The drive device is lowered into the pipe and, if the profile key and the profile receiver fit together, the drive unit and the downhole tool engage, and the drive mechanism and the downhole tool do not engage if the profile key and the profile receiver do not fit together. The fluid can be pumped through the channel of the drive device for flushing or flushing upstream of the drive device.

Westgard Published US Patent Application No. 2003/0173089 discloses a full bore selective positioning and orientation system having a manifold that is installed in a pipe string and having internals for positioning and orientation of a known configuration and a positioning device operating within the pipe string and having attachments for installation and orientation, which mesh with said internal fixtures of said nozzle. A method for installing and orienting a downhole tool, comprising installing a cylindrical nipple having a certain configuration and internal dimensions in a pipe string that lowers a setting device having complementary external dimensions and configuration and pivoting said setting device to a position in which the displaced element is extended from said mounting device into the recess of the said cylindrical element.

Jani Published U.S. Patent Application Publication No. 2015/0226034 describes an apparatus and related methods for selectively actuating sliding sleeves in subs, with sleeves placed in the wellbore to open holes in such subs to fracture the formation. in a well or detonating explosive charges on them to perforate the wellbore, or both. A simplified dart and clutch are used, which reduces the number of operations with each of them. Preferably, the dart is equipped with coupling devices for attaching a retrieval tool thereto, when coupled with the retrieval tool, this enables the bypass valve to operate to assist in retrieving the dart from the valve sub. The upward movement of the retrieval tool allows the wedge to disengage the dart from its associated sleeve so that the dart can be retrieved.

US Patent No. 2014/0209306 to Hughes et al. Discloses a wellbore treating tool for landing supported on a boundary wall in a wellbore in which the well treating tool is located. A well treatment tool includes a tool body that includes a first end shaped to be connected to a tubing string and an opposite end; a no-feed key assembly that includes a cylindrical casing and a no-pass key, a cylindrical casing defining an inner bore that fits along the cylindrical casing, and an outward-facing surface to which the no-pass key is attached, the no-pass key being designed to secure the no-pass key and the cylindrical casing in in a fixed position relative to the bounding wall, a cylindrical body, coupled to the tool body, which is installed in the inner channel of the cylindrical body; and a sealing member surrounding the tool body and disposed between the first compression ring on the tool body and the second compression ring on the cylindrical housing, the sealing member expanding and forming an O-ring around the tool body by sealing between the first sealing ring and the second sealing ring.

In US patent No. 2015/0218916 issued to Richards et al. Circulation valves are described, which can be open and closed, as well as permanently closed. The completion system provides for a production string with a movable circulation valve located in it, a circulation valve with a landing profile on its outer cylindrical surface and a displacement profile on its inner cylindrical surface, a working tool designed at least for placement in the production string and providing a pusher with one or more dowels designed to align with the offset profile. When the movable keys are in position and aligned with the displacement profile, the axial load applied to the tool moves the circulating valve along the axis, and the trigger assembly located inside the production string and containing the trigger that defines a channel designed to receive the locking device. is clamped in the channel until the stop unit is displaced in the axial direction.

Canadian Patent No. 2,412,072 to Fehr et al. Describes a tubing arrangement for fluidizing a wellbore. The tubing can be used for staged treatment of a wellbore with fluid, whereby a selected section of the wellbore is treated while other sections are isolated. The tubing can also be used when it is necessary to run the tubing with an opening in a sealed state, and later it must be opened.

The fracturing industry is always of great interest in alternative and / or improved designs that provide consistent and reliable engagement and actuation of buried valves and improved sealing.

The essence of the present invention

According to one aspect of the present invention, a special clamping sleeve is provided for use with a lip valve to open selected holes in a wellbore.

The lip valve comprises a valve body having a longitudinal channel passing through it and one or more openings for a fluid medium on a part of its side wall located upstream of the wellbore, and a sliding sleeve located in the channel of the valve body and configured to move between a closed position upstream. borehole with one or more fluid openings closed and open downhole with one or more fluid openings open, wherein the sliding sleeve comprises a longitudinal bore for positioning a clamping sleeve therein.

It is important to note that a clamping sleeve for use with the above lip valve contains:

- a ball seat having a ball seat surface that is inclined inward in the radial direction from top to bottom along the wellbore at an acute angle of inclination to the longitudinal axis of the clamping sleeve;

- a radially expandable portion located in close proximity and circumferentially around said ball seat;

the radially expandable portion is configured to expand radially outwardly by at least 0.09% under a pressure of at least 150 psi, which acts on the ball seated in said ball seat so that forms a seal at the point of contact between the clamping sleeve and the longitudinal bore of the sliding sleeve when the clamping sleeve is located in the sliding sleeve.

Therefore, it is advantageous that if the configuration of the clamping sleeve allows expansion in the radial direction, the overall outer diameter of the clamping sleeve can be reduced. This diameter, reduced not only in the area of the ball seat, but also in the area of the profile of the clamping sleeve, allows the clamping sleeve and its profile area to pass more freely down the wellbore, less interacting with various sliding sleeves that are undesirable to be actuated, thereby reduce frictional wear of the profiled area of the clamping sleeve and maintain the integrity of the profiles of the clamping sleeve, as well as better ensure the ability of sufficient and reliable adhesion of the profile of the clamping sleeve to the profile of the desired sliding sleeve, which it is desirable to activate when it reaches the sleeve, and at the same time creates a seal for increasing pressure on the upbore side of the ball to thereby shear the shear pins that hold the slide in place and allow the slide to move down the wellbore thereby opening the desired openings down the wellbore.

According to another aspect of this invention, the present invention provides a lip valve having a clamping sleeve with the functionality described above. Accordingly, according to such an embodiment of the present invention, this invention provides a cuff valve that comprises:

- a valve body having a longitudinal bore and one or more fluid openings on a portion of its lateral wall located upstream of the wellbore;

- a sliding sleeve located in the bore of the valve body and configured to move between a closed position up the wellbore, in which one or more fluid openings are closed, and an open position down the wellbore, in which one or more fluid openings are open environment, and the sliding sleeve contains a longitudinal channel; and

- clamping sleeve for positioning in the channel of the sliding sleeve;

wherein the clamping sleeve contains: a ball seat surface that has a ball seat surface that is radially inclined inward from top to bottom along the wellbore at an acute angle of inclination to the longitudinal axis of the clamping sleeve; and a radially expandable portion located in close proximity and extending circumferentially around said ball seat; and

wherein the radially expandable portion is configured to expand radially outwardly by at least 0.09% under a pressure of at least 150 psi, which acts on the ball sitting in said ball seat so that it forms a seal in the point of contact between the clamping sleeve and the longitudinal bore of the sliding sleeve when the clamping sleeve is located in the sliding sleeve.

According to another embodiment of the present invention, in order to successfully achieve the objectives in terms of the functionality of the clamping sleeve, the radially expandable portion of the clamping sleeve is configured to expand radially outwardly by at least 0.2% when the specified fluid pressure is applied to the ball. ...

In another embodiment, the clamping sleeve, at least in its radially expandable portion thereof, is configured to expand radially outwardly by at least 0.2% relative to the outer diameter of the clamping sleeve when a pressure of about 1500 psi is applied, or more.

The angle of inclination is preferably from about 25 ° to about 70 °, and preferably from about 35 ° to about 55 °. A ball seat and a radially expandable portion of said clamping sleeve are each positioned together in close proximity to an uphole end of said clamping sleeve.

In a preferred embodiment, the radially expandable portion is made of a material having a modulus of about 29,000,000 psi.

According to another embodiment, at least the radially expandable part of the clamping sleeve in the region of the ball seat is made of metal or contains metal.

In another embodiment, the radially expandable portion of the clamping sleeve in the area of the ball seat comprises American Petroleum Institute N80 steel (API N80).

In another embodiment, the radially expandable portion of the clamping sleeve in the area of the ball seat is made of API P110 grade steel.

In an improved form, the clamping sleeve may additionally contain:

- the cylindrical part up the wellbore;

- the cylindrical part down the wellbore; and

- at least one flexible-elastic petal located on the outer annular surface of the said clamping sleeve, while each petal is connected to a part located upstream of the wellbore and a part located downstream of the wellbore, respectively, on its two opposite to each other ends;

wherein at least one petal contains on its outer surface the profile of the clamping sleeve corresponding to the profile of the sleeve on the inner surface of the sliding sleeve.

Providing the advantage, in view of the above improvement, when the aforementioned clamping sleeve petal engages with the clutch profile, and upon application of fluid pressure to the ball while said ball sits in said ball seat, said at least one flexibly resilient petal flexes outward in the radial direction, so that the profile of the clamping sleeve additionally and to a greater extent engages with the profile of the sleeve on the inner surface of said sliding sleeve.

According to another aspect of the present invention, a clamping sleeve is provided for use with a lip valve. The lip valve comprises a valve body having a longitudinal channel passing through it and one or more openings for a fluid medium on a part of its side wall located above the wellbore, and a metal sliding sleeve located in the channel of the valve body and made with the possibility of moving between the closed position upwards along the wellbore, closing one or more fluid openings, and open down the wellbore, exposing one or more fluid openings, wherein the sliding sleeve comprises a sleeve profile on its inner surface and a longitudinal bore for positioning the clamping sleeve.

In turn, the clamping sleeve contains:

- a ball seat having a ball seat surface that is inclined inward in the radial direction from top to bottom along the wellbore at an acute angle of inclination to the longitudinal axis of the clamping sleeve;

- the cylindrical part up the wellbore;

- the cylindrical part down the wellbore; and

- a plurality of flexible-elastic petals, respectively, connected to a part above the wellbore and a part below the wellbore at their two longitudinally opposite ends;

wherein each of the said petals contains on its outer surface the profile of the clamping sleeve, corresponding to the profile of the coupling;

at the same time, when the said petals are coupled with the specified profile of the coupling and when the ball lands in the specified ball seat and when fluid pressure is applied to the specified ball, when the said ball sits in the specified ball seat, the said flexible-elastic petals are made with the possibility of bending outward in a radial direction, so that the profile of the clamping sleeve additionally and to a greater extent engages with the profile of the sleeve on the inner surface of said sliding sleeve.

According to yet another further aspect of the present invention, the invention provides a method for actuating a sliding sleeve having a longitudinal bore. The method includes:

- providing a clamping sleeve configured to be positioned in the channel of the sliding sleeve, wherein said clamping sleeve comprises a radially expandable metal portion located adjacent to the up-borehole end of the clamping sleeve, and a ball seat having a ball seat surface inclined radially inwardly from top to bottom along the wellbore at an acute angle of inclination to the longitudinal axis of the clamping sleeve;

- initiation of the downward flow of the clamping sleeve into the wellbore and its fixation in the channel of the sliding sleeve;

- the ball flow down into the borehole and the ball landing in the ball seat;

applying a first fluid pressure from the top of the wellbore to press the ball against the ball seat and cause the portion of the clamping sleeve in the area of the ball seat to expand outward in the radial direction so as to form a seal at the contact of the clamping sleeve in the area of the ball seat and the sliding sleeve; and

- applying a second fluid pressure from the top of the wellbore to shear the shear pins and slide the sliding sleeve down the wellbore and open the hole.

Brief description of the figures

Additional advantages and other embodiments of the present invention will become apparent from the foregoing, as well as the following detailed description of various specific embodiments of the present invention, taken in conjunction with the accompanying drawings, each of which is non-limiting:

FIG. 1, according to some embodiments of the present invention, is a cross-sectional view of a collar valve downhole tool having a valve body and a movable slide sleeve therein, with the slide sleeve in a closed position, and showing the safety sleeve being engaged.

FIG. 2 is a cross-sectional view of the valve body of the downhole tool shown in FIG. 1, without protective sleeve.

FIG. 3 is a cross-sectional view of the sliding sleeve of the downhole tool of FIG. 1, including an illustration of an additional protective sleeve.

FIG. 4 is a cross-sectional view of the housing of the sliding sleeve shown in FIG.

3.

FIG. 5 is a cross-sectional view of the protective sleeve of the sliding sleeve shown in FIG. 3.

FIG. 6 is a cross-sectional view of the retaining ring of the sliding sleeve shown in FIG. 3.

FIG. 7 is an exploded sectional view of the sliding sleeve shown in FIG. 3, the assembly process of the sliding sleeve is shown.

FIG. 8 is a cross-sectional view of a clamping sleeve for actuating the corresponding lip valve shown in FIG. one.

FIG. 9 to 12A are cross-sectional views of the clamping sleeve shown in FIG. 8 and the corresponding cuff valve shown in FIG. 1, the process of insertion of the clamping sleeve into the corresponding lip valve and fixation in it is shown.

FIG. 12B is an enlarged sectional view of a portion of FIG. 12A showing the profiled portions of the clamping sleeve and the corresponding lip valve when the clamping sleeve is locked into the corresponding sliding sleeve.

FIG. 13 is a schematic sectional view showing the clamping sleeve shown in FIG. 8 which is locked into the corresponding cuff valve shown in FIG. 1, as well as a ball dropped into the cuff valve to move the cuff valve to the open position.

FIG. 14 is a schematic cross-sectional view showing the sliding sleeve of the cuff valve shown in FIG. 13, which is brought to the open position by the pressure of the ball and the clamping sleeve to open the hydraulic fracturing passage holes.

FIG. 15A, in another embodiment, is a schematic cross-sectional view showing the sliding sleeve of the collar valve being pushed open by ball and collar pressure to expose the fracture ports, with the collar petals being able to expand radially outward under pressure. direction when fluid pressure is applied from the top of the wellbore and compression of the clamping sleeve causes the petals to expand outward in a radial direction so as to additionally engage the sliding sleeve for better grip and thus additional pressure resistance.

FIG. 15B is an enlarged sectional view of a portion of FIG. 15A showing a radially outwardly expanded clamping sleeve in engagement with a sliding sleeve.

FIG. 16 is a schematic diagram showing the multi-lip casing shown in FIG. 1 extended into a wellbore to fracture a subterranean formation in accordance with some embodiments of the present invention.

FIG. 17A is a cross-sectional view of a clamping sleeve according to some other embodiments.

FIG. 17B is an enlarged sectional view of a portion of FIG. 17A showing a ball seat on the clamping sleeve.

FIG. 18 is a sectional view of a specific example of the clamping sleeve shown in FIG. 17A and contained in a sliding sleeve as shown in FIG. 3, as well as a ball in a clamping sleeve, which is designed to expand radially in the expandable metal part of the clamping sleeve to form a tight metal-to-metal connection between the clamping sleeve and the sliding sleeve after the ball lands on the seat in the clamping sleeve and fluid pressure is applied to the ball from above along the wellbore.

FIG. 19 is a cross-sectional view of a clamping sleeve according to some other embodiments.

FIG. 20A through 20D are schematic diagrams showing a plurality of sleeve profiles and their corresponding clamping sleeve profiles in accordance with some other embodiments.

FIG. 21A is a schematic diagram showing the profile of the sleeve and the corresponding profile of the clamping sleeve to illustrate the parameters associated with the design of these profiles.

FIG. 21B is a schematic diagram showing the alignment of the clamping sleeve profile and the coupling profile.

FIG. 21C is a schematic diagram showing the clamping sleeve profile and the sleeve profile shown in FIG. 21B, with the profile of the clamping sleeve aligned with the profile of the sleeve.

FIG. 22 to 49 are schematic diagrams showing the different variants of the profiled sections of the sliding sleeve and clamping sleeve.

FIG. 50 is a schematic diagram showing an example of a multi-lip valve tubing string according to some embodiments of the present invention.

FIG. 51 is a schematic diagram showing a series of expanded sleeve and clamping sleeve profiles in accordance with some other embodiments of the present invention.

FIG. 52 is a schematic diagram showing a series of expanded sleeve and clamping sleeve profiles in accordance with still other embodiments of the present invention.

FIG. 53 is a schematic diagram showing a series of expanded sleeve and clamping sleeve profiles in accordance with some additional embodiments of the present invention.

FIG. 54 through 57 are schematic diagrams showing a number of expanded sleeve and clamping sleeve profiles in accordance with some other embodiments of the present invention.

FIG. 58 through 61 are schematic diagrams showing a number of expanded sleeve and clamping sleeve profiles in accordance with still other embodiments of the present invention.

FIG. 62 is a schematic diagram showing a series of expanded clutch and clamping sleeve profiles in accordance with some other embodiments of the present invention; and

FIG. 63A through 63F are schematic diagrams showing the profile of the clamping sleeve on the clamping sleeve and the profile of the sleeve on the sliding sleeve; according to some embodiments in which the clamping sleeve petals are capable of radially outward expansion under pressure when hydraulic pressure is applied from the top of the wellbore and compression of the collet causes the collar petals to expand radially outward so as to further engage the sliding sleeve for better grip and thus additional pressure resistance.

Detailed description of some embodiments

The embodiments described herein disclose the invention of a cuff valve that is pressurized. Further in the description, the term "downhole" means the direction along the wellbore towards the end of the wellbore and may coincide (for example, in a vertical wellbore) or not coincide (for example, in a horizontal wellbore) with the direction "down". The term "up-borehole" means a direction along the wellbore towards the surface and may coincide (for example, in a vertical wellbore) or not coincide (for example, in a horizontal wellbore) with an upward direction.

In some embodiments, a lip valve comprises a valve body having a longitudinal bore and one or more fluid openings in a sidewall thereof. A sliding sleeve is positioned in the bore and is movable between a closed position up the wellbore, blocking the fluid openings, and an open position down the wellbore, exposing the fluid openings.

The sliding sleeve contains a profiled section on its inner side, represented by annular grooves and protrusions that form the profile of the sleeve. The section of the profile contains a stop at its lower end along the wellbore for fixing a clamping sleeve element (for ease of description, it is also called a "clamping sleeve"), which has a corresponding profile of the clamping sleeve on its outer surface. As used herein, the term “appropriate” means a condition where the profile of the clamping sleeve matches the profile of the sliding sleeve such that the profiled portion of the clamping sleeve can fit into the profiled portion of the sliding sleeve to secure the clamping sleeve to the sliding sleeve of the lip valve.

In some embodiments, the upper wellbore surface of the retainer ring is radially tilted inwardly from the bottom up the wellbore to form a stop 194 at an acute angle a to the longitudinal axis of the retainer.

In some embodiments, the stop is formed by a retaining ring abutting the profiled portion of the sliding sleeve.

In some embodiments, the retaining ring is made of a high strength material such as tungsten carbide, cobalt chromium alloys, and / or the like.

In some embodiments, the collar is cage-shaped and includes an upbore portion, a downbore portion, and a plurality of petals affixed at opposite ends to the upbore and downhole portions of the bushing. One or more or all of the longitudinal tabs are flexible and profiled to form the profile of the clamping sleeve.

In some embodiments, the uphole portion of the clamping sleeve includes a ball seat for positioning a ball from the top of the wellbore therein to actuate a lip valve.

In some embodiments, the clamping sleeve includes a metal portion upbore that expands radially outwardly such that when the clamping sleeve is positioned in a corresponding lip valve and the ball is seated in the clamping sleeve, fluid pressure applied to the ball can induce the expandable up-wellbore portion expands outward in a radial direction and presses against the inner surface of the cup valve, thereby forming a tight metal-to-metal connection at the contact between the cup valve and the clamping sleeve.

In some embodiments, the ball seat on the clamping sleeve comprises an inclined surface.

In some embodiments, the angle of inclination θ of the sloped surface of the ball seat is about 55 degrees to the longitudinal reference axis. In some embodiments, the inclination angle θ is about 35 °. In some other embodiments, the angle of inclination θ ranges from about 50 ° to about 60 °. In some other embodiments, the angle of inclination 6 ranges from about 40 ° to about 70 °. In some other embodiments, the angle of inclination 6 ranges from about 30 ° to about 80 °.

Consider FIG. 1, a downhole tool is shown and generally referenced at 100. In these embodiments, the downhole tool 100 is in the form of a downhole collar valve and includes a cylindrical valve body 102 with a bore 104 and a sliding sleeve 106 disposed in bore 104. Slip sleeve 106 is secured by one or more shear pins 108 in a closed position upbore to close one or more fluid openings 110 on cylindrical body 102 and includes a longitudinal bore for positioning a corresponding clamping sleeve (described below). Under pressure from the top down the wellbore, the clamping sleeve can move the sliding sleeve 106 down the wellbore from a closed position to an open position to open one or more fluid openings 110 to fracture a subterranean formation (described below).

As seen in FIG. 2, the cylindrical body 102 includes a cylindrical valve body 112 that is detachably coupled to an upper sub 114 and a lower sub 116, respectively, up and down the wellbore by means of a threaded connection 118 and a set screw 120, and with a lip 122 to seal this. connections. In these embodiments, the lower end of the upper sub 114 and the upper end of the lower sub 116 define the upper and lower bore stops 124 and 126 to restrict movement of the sliding sleeve 106 therebetween.

In these embodiments, the top sub 114 is provided with a tapered interior surface 128 tapered from its upbore end to the downhole end such that the top sub 114 has an internal diameter gradually decreasing from its upbore end. down the wellbore to an end downhole to facilitate entry of the collar into the collar valve 100 (described below).

The valve body 112 on its sidewall includes one or more fluid openings 110 adjacent to the upbore end 132 for the fracturing fluid to exit into the subterranean formation as the sliding sleeve 106 moves from a closed position to an open position under the action of response pressure. ... The valve body 112 also includes one or more openings 136 for extending one or more shear pins 108 (see FIG. 1) to lock the sliding sleeve 106 in a closed position to close the openings 110. The valve body 112 further comprises one or more ratchet joints 138 on its outer surface adjacent to the downhole end 136.

FIG. 3 is a cross-sectional view of the sliding sleeve 106 and the sleeve body 152 with bore 151. The outer diameter (OD) of the sliding sleeve 106 is equal to or less than the inner diameter of the valve body 112 so as to allow the sliding sleeve 106 to move within the valve body 112. According to these embodiments, the sliding sleeve 106 comprises a sleeve body 152 in which, by means of threaded connections 156 on the inner surface of the sleeve body 152, at least a connecting portion 153 of the protective sleeve 154 is located downhole therefrom (FIG. 4), and the corresponding threaded connection 158 on the outer surface of the protective sleeve 154 (Fig. 5) for detachable connection with the protective sleeve 154.

As seen in FIG. 4, the clutch body 152 may include, on its outer surface, one or more annular lip seals 168 that are located at suitable locations, for example, near the top end 164 of the clutch body 152 to seal the contact between the valve body 112 and the sliding sleeve 106 (FIG. 1 ).

The clutch body 152 also includes one or more holes or recesses 170 at locations corresponding to holes 136 on the valve body 112 for the shear pins 108 to enter when the sliding sleeve 106 is inserted into the bore 104 of the valve body 112 in the closed position, and one or more ratchet rings 172 near its downhole end 166 to engage ratchet 138 on the inner surface of valve body 112 when sliding sleeve 106 is in the open position.

On its inner surface, the sleeve body 152 is made of a suitable material, such as steel, and includes a retaining ring seat 180 located downhole, located uphole of the threaded connection 156 and accessible from the end 166 of the sleeve body 152 located below along the wellbore for positioning and retaining the high strength retaining ring 192, and a profiled section 182 uphole from and adjacent to the retaining ring seat 180 (accordingly, another section of the inner surface of the sliding sleeve 106 is designated as a non-profiled section).

The profiled portion 182 on the sleeve body 152 comprises one and preferably two or more annular grooves 184, such as grooves 184A and 184B, forming a unique locking profile (also referred to as a “sleeve profile”). Each groove 184 has a wall in an uphole portion that slopes radially inwardly from top to bottom of the wellbore making an obtuse angle with the longitudinal axis of the sleeve body 152. Each groove 184 also includes a wall located downhole and at a right angle or an acute angle. That is, the wall of each groove 184 located downhole of the wellbore is either perpendicular to the longitudinal axis of the sleeve body 152 or is tilted radially inwardly from the bottom up the wellbore and forms an acute angle to the longitudinal axis of the sleeve body 152. The grooves 184 can receive a clamping sleeve 200 with a matching profile 212 on its outer surface (hereinafter referred to as a "matching clamping sleeve") into the profiled portion 182, and clamping bushings 200 with inappropriate external profiles (herein - “Inappropriate clamping sleeves”) (described below).

Depending on the number of grooves 184, the inner diameter of the profiled portion 182 on the sliding sleeve 106 may vary at different locations along it due to the grooves 184 therein. However, the minimum inner diameter of the profiled portion 182 including the retaining ring 192 is typically the minimum inner diameter the sliding sleeve 106. In other words, the sliding sleeve 106 has a minimum inner diameter in the region of the profiled portion 184 and the retaining ring 192.

The outer diameter of the profile 212 of the clamping sleeve 200 is greater than the minimum internal diameter of the profiled section 182 on the sleeve body 152, which allows a minimum initial engagement if the clamping sleeve matches the profile 212 of the clamping sleeve on such a corresponding clamping sleeve 200 with the profiled section 182 on the sleeve body 152, but below By fluid pressure applied to the clamping sleeve 200, the outer diameter of the profiled portion 212 may be significantly larger than the minimum inner diameter of the profiled portion 182 on the sleeve body 152 to maximize the engagement of the profiled portion 212 on the clamping sleeve 200 with the profiled portion 182 in a manner that is described in more detail below.

In particular, the outer diameter of the clamping sleeve 200 in the region of the ball seat 214 thereon is initially less than the inner diameter of both the bore 151 and the profiled section 184 on the sleeve body 152. However, the clamping sleeve 200 is capable of expanding radially outward in the region of the ball seat 214 upon application of fluid pressure from the top of the wellbore acting on the ball 242, which is in the ball seat 214, in a manner that is described in detail below, and causes its expansion in the radial direction. (i.e., increasing the outer diameter of the clamping sleeve 200 in the region of the ball seat 214), while its diameter becomes very close to or equal to the inner diameter of the bore 151 in the sleeve body 152, thereby providing the advantages and benefits that are described in more detail below.

Retaining ring 192 is made of a material that is harder than that of sliding sleeve 106. For example, retaining ring 192 is made from high strength material such as tungsten carbide, cobalt chromium alloys (such as stellite alloys), nitrided steels and / or other suitable high strength alloys, or their combination in order to provide increased resistance to pressure and wear.

In some embodiments, the hardness of said abutment 194 of said retaining ring 192 (described in more detail later) is increased at least to a hardness greater than that of the sliding sleeve 106 material, or provides a material having a hardness that exceeds that of the sliding sleeve 106.

FIG. 6 is a cross-sectional view of a high-strength retaining ring 192. Retaining ring 192 has an outer diameter suitable for seating on the retainer ring seat 180 in the sleeve body 152 and has a section height "h" sufficient to expand radially outward beyond the inner edge of the retainer seat 180 rings. In these embodiments, the upper wellbore surface of the retaining ring 192 is radially tilted inwardly from the bottom up the wellbore, forming at its up-bore edge a stop 194 forming an acute angle a with the longitudinal axis of the collar valve 100. Below will be in more detail, the stop 194 of the retaining ring 192 is adapted to support a portion of the clamping sleeve profile and engage with a corresponding stop of the clamping sleeve when the profile of the clamping sleeve engages the profile 182 of the collar and prevents the movement of the clamping sleeve 200 downhole relative to the sliding sleeve. Thus, the retaining ring 192 may also be called a "snap ring" for securing the clamping sleeve from below.

As seen in FIG. 7, the sliding sleeve 106 can be assembled by placing the retaining ring 192 into the sleeve body 152 to fit over the retaining ring seat 180. The sleeve 154 is then "screwed" to the downhole end of the sleeve body 152 using threads 158 on sleeve 154 and threads 156 on sleeve body 152. The upper end 160 of the collar 154 presses the retaining ring 192 against the retainer ring seat 180 to firmly clamp the retaining ring 192 in position. A slide sleeve 106 assembly is shown in FIG. 3.

The lip valve 100 may then be assembled by placing the slide sleeve 106 into the bore 104 of the valve body 112 from either end to the closed position, locking the slide sleeve 106 in place by extending the shear pin or shear screw 108 through the hole 136 in the valve body 112 into the hole. 170 of the sleeve body 152 and then joins the valve body 112 to the upper sub 114 and the lower sub 116. The cup valve assembly 100 is shown in FIG. one.

As seen in FIG. 1, the length of the slide sleeve 106 in the longitudinal direction is greater than the distance between the stoppers 124 and 126 of the valve body 112 so that when the slide sleeve 106 is closed, the shield sleeve 154 is in contact with the inner surface of the lower sub 116 to isolate the annular space 196 located in radially between the valve body 112 and the sliding sleeve 106, and between the downhole end 166 of the sliding sleeve 106 and the abutment 126 in the longitudinal direction, away from the bore 104 to prevent cement from entering the annulus 196 and disrupting the valve.

As described above, the lip valve 100 provides a profiled inner surface portion 182 with a unique retention profile that allows a corresponding clamping sleeve to be received and secured, as well as an inappropriate clamping sleeve to pass through the valve.

FIG. 8 is a cross-sectional view of a clamping sleeve 200, which in this embodiment is in the form of a cylindrical cage with a longitudinal bore 202. The clamping sleeve 200 generally has an outer diameter (with the exception of the projections 222 described below) that is slightly less than the minimum inner diameter. the diameter of the sliding sleeve 106, and provides one or more O-rings 204 on its outer surface where necessary to seal the contact between the clamping sleeve 200 and the sliding sleeve 106 when the clamping sleeve 200 is locked into the sliding sleeve 106.

As can be seen, the collar 200 provides a cylindrical portion 206 uphole, a cylindrical portion 208 downhole, and a middle portion 210 providing a profiled portion 212 with a unique retaining profile.

In these embodiments, the uphole portion 206 provides on its inner surface a ball seat 214 for landing a ball that is dropped into the borehole from above along the wellbore. The uphole portion 206 also provides a lip seal 216 on its inner surface to seal contact between the ball and the upborehole portion 206 of the collar 200.

The middle portion 210 contains a plurality of petals 218 distributed around the circumference and connected to portions 206 and 208 located above and below the wellbore. In these embodiments, the clamping sleeve 200 is made from a metal tube by cutting, punching, or otherwise forming a plurality of longitudinal slots 220 in the middle portion 210 to form petals 218.

One or more or all of the petals 218 are made of resiliently flexible material with sufficient elasticity and each of them provides a profile that is one or more of the protrusions 222, with the protrusions 222A and 222B on the shaped portion 212 expanding outward in a radial direction from the outer surface of the petals forming a radially flexible locking profile (also referred to as a “clamping sleeve profile”). The locations and sizes of the protrusions 216 are selected so that the maximum outer diameter of the clamping sleeve 200 is larger,

than the minimum inner diameter of the sliding sleeve 106, and the profile of its clamping sleeve matched the profile of the sleeve of the corresponding sliding sleeve 106. Thus, when the sleeve 200 enters a cup valve 100 having a corresponding sliding sleeve 106 (since the lip valve 100 is also referred to as a "corresponding sleeve valve valve 100 "), the clamping sleeve 200 can be fixed in the corresponding lip valve 106. The lowermost projection 222B along the wellbore provides a stop 236 on its lower side along the wellbore with the same acute angle a to the longitudinal axis of the lip valve 100 as in stop 194.

FIG. 9 through 12 show an example of the entry of the clamping sleeve 200 into the corresponding lip valve 100 from its upper side along the wellbore. As seen in FIG. 9, when the collar 200 enters the lip valve 100, the tapered inner surface 128 of the top sub 114 guides the collar 200 to enter the bore 104.

As seen in FIG. 10, when the profiled portion of the collar 200 enters bore 104 and since the maximum outside diameter of the collar 200 exceeds the minimum inside diameter of the sliding sleeve 106, the profiled tabs 218 deflect inward and the collar 200 continues to move downhole.

As seen in FIG. 11, when the profiled portion 212 of the clamping sleeve 200 completely overlaps the corresponding profiled portion 182 of the sliding sleeve 106, the profiled petals 218 do not deflect due to their elasticity. Thus, the clamping sleeve 200 fits from top to bottom into the sliding sleeve 106. As shown in FIG. 12A and 12B, the clamping sleeve 200 may further slide down the wellbore until the stop 236 of the lowest lip 222B engages with the stop 194 of the high strength retaining ring 192.

FIG. 12B is an enlarged view of the profiled sections 182 and 212 of the sliding sleeve 106 and the clamping sleeve 200. As seen, the profile of each of the profiled sections 182, 212 provides alternating grooves and ridges. In the example shown in FIG. 12B, the profile of the profiled portion 182 includes two grooves 184A and 184B and a longitudinal projection 232 therebetween. The profile of the profiled portion 212 includes two protrusions 222A and 222B and a groove 234 therebetween. To ensure that the profiled sections 182 and 212 match each other, the width of the groove in each of the two profiled sections 182 and 212 must be equal to or greater than the width of the corresponding protrusion on each of the two profiled sections 182 and 212 to receive the corresponding protrusion. In the example shown in FIG. 12B, the width of the groove (e.g., groove 184A, 184B, or 234) is sufficiently wider than the width of the corresponding longitudinal ridge (e.g., longitudinal ridge 222A, 232, or 222B) so that after the clamping sleeve 200 is secured from below in the sliding sleeve 106, the clamping sleeve 200 can move. further down the wellbore until the lowest lip 222B engages the high strength retaining ring 192.

As seen in FIG. 12B, a high strength retaining ring 192 is used to engage the lowest borehole lip 222B to enhance the high pressure retention of the sliding sleeve 106 and the collar 200 downhole under the high pressure. In addition, the shape of the retaining ring 192 provides a stop 194 in the upper part of the wellbore, where the stop is at an acute angle to the longitudinal axis of the collar valve 100, and the downhole side of the lowermost projection 222B also forms a stop 236 c an appropriate acute angle such that the engagement of stops 194 and 236 provides increased resistance to pressure applied to the collar 200 downhole. In these embodiments, when the stops 194 and 236 are engaged with each other, other corresponding longitudinal projections of the clamping sleeve 200 and the sliding sleeve 106, for example, the longitudinal projections 222A and 232, also engage to further improve resistance to pressure applied. to the clamping sleeve 200 downhole.

As seen in FIG. 13, after the clamping sleeve 200 is locked into the sliding sleeve 106, a ball 242 can be thrown from the surface and enters the collar valve 100. The ball 242 is made of a rigid material, such as ceramic or metal, and is sized to fit. into the seat 214 of the balls on the clamping sleeve 200.

After the ball 242 engages the ball seat 214 and seals the bore 202 of the clamping sleeve 200, fluid pressure is applied up the wellbore to the ball 242 and the clamping sleeve 200. After the clamping sleeve 200 is downwardly locked to the sliding sleeve 106, the sliding sleeve 106 is actuated and shears the shear pin 108 and moves down the wellbore to an open position to expose the fluid openings 110. As seen in FIG. 14, the ratchet rings 172 on the slide sleeve 106 engage a ratchet joint 138 on the valve body 112 to prevent the slide sleeve 106 from moving uphole. Fracturing fluid may then be injected downhole at high pressure and will be jetted out of the fracturing fluid holes 110 in the formation.

The fracturing fluid is typically under high pressure and any malfunction in the lip valve 100 can cause the fracturing to fail. For example, if the engagement between the collar 200 and the sliding sleeve 106 fails, the high pressure fracturing fluid can move the collar 200 downhole, causing the fracturing to fail.

Those skilled in the art will appreciate that in the aforementioned embodiments, the lip valve 100 provides a high strength retaining ring 192 to enhance the engagement between the clamping sleeve 200 and the sliding sleeve 106, which greatly reduces the risk of failure.

In some embodiments, the outer diameter of the clamping sleeve 200 at its projections 222A and 222B is less than the inner diameter of the sliding sleeve 106 in its grooves 184A and 184B. As shown in FIG. 15A and 15B, according to these embodiments, after the high pressure fracturing fluid is pumped down the wellbore and moves the sliding sleeve 106 to the open position, the high pressure fracturing fluid further slightly moves the collar 200 down the wellbore so that the petals 218 expand radially outward so that the projections 222A and 222B of the clamping sleeve 200 further engage with the grooves 184A and 184B of the sliding sleeve 106, thereby providing increased pressure resistance.

In some embodiments, a downhole fracturing system including a plurality of lip valves 100 may be used to fracture a subterranean formation. FIG. 16 illustrates an example of hydraulic fracturing in a subterranean formation using a collar valve 100. In this example, a horizontal well is drilled that provides a horizontal portion 272 of the wellbore in the subterranean formation 274. Then, a casing 276 containing a plurality of lip valves 100 is placed in a portion 272 of a wellbore. Each sliding sleeve 100 provides a unique sleeve profile. Other subs may be positioned between the lip valves 100 as needed.

Once the casing 276 has been set, cementing may be performed by injecting cement into the wellbore through the casing 276. As described above with reference to FIG. 1, in each lip valve 100, a protective sleeve 154 prevents cement from entering the annulus 196 and disrupting the operation of the valve. After cementing, flushing fluid may be pumped into the wellbore to clean the sub and lip valves 100. If necessary, scrapers may also be used for cleaning.

In this example, it is assumed that rock formation 274 is being fractured adjacent to wellbore section 278 and lip valves 100B and 100C are to be opened. Therefore, the first collar (not shown) corresponding to the collar valve 100C is pumped into the wellbore through the casing 276. Since the first collar does not match the collar valves 100A and 100B (i.e., the collar profile of the first collar does not match the sleeve profile of the sliding sleeves 100A and 100B and cannot fit), the first clamping sleeve passes through the sliding sleeves 100A and 100B and locks into the lip valve 100C.

To open the fluid openings of the cup valve 100C, a ball is dropped that engages the ball seat of the first collet and closes the bore of the first collet. Fluid pressure is then applied to actuate the engaging ball, the first clamping sleeve and sliding sleeve shear the shear pin of the collar valve 100C and move the sliding sleeve down the wellbore to an open position to expose the fluid holes in the sliding sleeve 100C.

After opening the cup valve 100C, a second clamping sleeve corresponding to the cup valve 100B is pumped down the wellbore to secure the cup valve 100B. The ball is then dropped to engage the second clamping sleeve and fluid pressure is applied to open the collar valve 100B.

After all lip valves 100B and 100C have been opened in section 278 of the wellbore, the balls in these lip valves, with the exception of the ball in the downhole lip valve, are removed, for example, by drilling, dissolving, retrieving to the surface and / or in similar ways. In the example shown in FIG. 16, the ball is in the cup valve 100C and the ball is removed from the cup valve 100B. Fracturing fluid is then pumped into the casing 276 under high pressure, which is jetted out of the fluid openings of the collar valves 100B and 100C to fracture the formation in the rock mass 274.

In the above example, wellbore isolation devices such as packers, which are known in the art, may be used to isolate a portion of the wellbore in which fracturing is performed, so they are not described herein.

As can be seen from the examples above, a plurality of sliding sleeves 100 may be employed in the fracturing process, having generally the same channel size 104 to provide the same fluid flow capacity. Collet 200 and balls 242 can also be the same size, which simplifies logistics and reduces completion costs.

In the above-mentioned embodiments, as shown in FIG. 3 through 7, the shield 154 is detachably coupled to the sleeve body 152 via threaded connections 158 and 156. In some other embodiments, the sleeve 154 may be coupled to the sleeve body 152 using other suitable devices. For example, in one embodiment, the sleeve 154 may be permanently welded to the sleeve body 152.

In the foregoing embodiments, the clamping sleeve 200 is in the shape of a cylindrical cage with a plurality of petals attached to the cylindrical portion 206 uphole and the cylindrical portion 208 downhole, eliminating the use of external devices such as springs for radial actuation. direction or modification of the clamping sleeve 200 for the purpose of engaging with and fixing the sliding sleeve. According to another specific embodiment, attaching the flexible petals at their longitudinally opposite ends to the portions 206 and 208 located up and down the wellbore, and an additional arrangement of the clamping sleeve so that the said petals, when initially engaged with the inner profile 184, in a sliding sleeve 106, when fluid pressure is applied uphole to the ball in the ball seat 214 on the clamping sleeve 200, advantageously allows the petals on the clamping sleeve 200 to bend further, which leads to additional and stronger adhesion of the petals having a profile 212 of the clamping sleeve in the profile 184 of the sliding sleeve 106, thereby reducing the risk of disengagement of the clamping sleeve 200 with the selected sleeve or, in another embodiment, reducing the risk of possible disengagement of the mating profile of the clamping sleeve 200 with the mating profile 184 of the sliding sleeve 106 when fracturing pressure is applied from the top along the borehole well This will prevent the injection of high pressure fracturing fluid from the well into the open hole 110 in the event of a failure.

In some other embodiments, a wellbore fracturing system may be used to fracture a section of a wellbore comprising a string of tubing with one or more collar valves 100. The wellbore may be a cased wellbore or an open hole.

Although in the example shown in FIG. 16, collar valves 100 are used to fracture a horizontal wellbore, those skilled in the art will appreciate that in some other embodiments, collar valves 100 may be used to fracture a vertical wellbore.

In the aforementioned embodiments, the clamping sleeve 200 may provide one or more sealing collars 204 on its outer surface to seal the contact between the clamping sleeve 200 and the sliding sleeve 106 when the clamping sleeve 200 enters the lip valve 100. However, while the clamping sleeve is in the barrel wells, such collars 204 can typically wear and become ineffective when the collar 200 moves in the sliding sleeve 106, resulting in the collar valve 100 malfunctioning. In addition, when pumping the collar through inappropriate sliding sleeves, a lot of pressure is usually required fluid to overcome the friction caused by the movement of the o-rings 204 along the outer surface of the sliding sleeve 106.

In some other embodiments, no o-rings 204 are provided on the outer surface of the clamping sleeve 200. In these embodiments, the cup valve 100 is the same as shown in FIG. 1, and the non-profiled portion of the clamping sleeve 200 has an outer diameter that is slightly less than the minimum inner diameter of the sliding sleeve 106, which avoids the friction otherwise caused by the o-rings 204 and thus allows the clamping sleeve 200 under less fluid pressure to pass through. through the corresponding cuff valve 100.

In these embodiments, the sliding sleeve is made from a suitable metal, such as steel. As shown in FIG. 17A and 17B, the uphole portion 206 of the collar 200 is designed to have a metal portion 206 'that expands radially outward and the ball seat 214 provides a ball seat surface 282 that slopes inward radially from bottom to top. along the wellbore at an acute angle to the longitudinal axis 284 of the clamping sleeve 200.

After the collar 200 is secured in the lip valve 100, a suitably sized ball 242 is pressed downhole by fluid pressure onto the ball seat 214. When fluid pressure is applied to the uphole side of the ball 242, the ball 242 presses against the inclined surface 282 of the ball seat 214 and converts the downhole fluid pressure into radial outward pressure and radially expands the expanding metal portion 206 'clamping sleeve 200 to substantially reduce the gap between the clamping sleeve 200 and the sliding sleeve 106, or even bring the outer surface of the expanding metal portion 206' into tight engagement with the inner surface of the sliding sleeve 106, thereby forming a tight metal-to-metal connection at the contact between the clamping sleeve 200 and sliding sleeve 106.

As seen in FIG. 17B, the surface 282 of the ball seat 214 is inclined at an angle θ to the longitudinal reference direction 284. In some embodiments, the inclination angle θ is about 55 °. An angle of inclination of about 55 ° is an angle sufficient to transfer sufficient radially outward force to the clamping sleeve 200 and to achieve sufficient radial expansion of the clamping sleeve 200 to form a sufficiently tight metal-to-metal connection with the sliding sleeve 106 for metal API Grade N80 steel clamping bush where the nominal 214 ball seat diameter on the 200 clamping bush is 4.555 inches with a 0.23 inch nominal clamping bushing thickness and 242 nominal 4.250 inches of pressure on the 242 ball of 4.250 inches about 1500 psi, and where the clamping sleeve 200 initially, prior to radial expansion, has a clearance with the outer diameter of the sliding sleeve 106 in the range of 0.004 to 0.014 inches (see Example A below and FIG. 18).

In other embodiments, where the clamping sleeve 200 may be made of a harder or less elastic material (for example, having a higher modulus of elasticity) and / or may have a greater thickness, and / or where there is an initial difference between the diameter of the clamping sleeve 200 and the diameter sliding sleeve 106 with a difference greater than the 0.004 to 0.014 inch range, and / or where the pressure on ball 242 is less than 1500 psi, the tilt angle θ must be reduced to about 35 ° so that the ball seat 214 can transfer sufficient a radially outward force to achieve a sufficient radial increase in the diameter of the clamping sleeve 200 and thereby achieve the desired tight metal-to-metal connection with the bore.

In some other embodiments, the angle of inclination θ ranges from about 50 ° to about 60 °. In some other embodiments, the angle of inclination θ ranges from about 40 ° to about 70 °. In some other embodiments, the angle of inclination θ ranges from about 30 ° to about 80 °.

Accordingly, therefore, when the clamping sleeve 200 is designed to allow radial expansion, this allows the overall outer diameter of the clamping sleeve 200 to be reduced. Such a diameter, reduced not only in the region of the ball seat 214, but also in the region of the profile 212 of the clamping sleeve, thus thereby allows the clamping sleeve 200 and the region of the profile 212 to pass more easily and less interact with the regions of the profile 184 of the different up-hole sliding sleeves 106 that do not need to be actuated, thereby reducing the frictional wear of such a profiled portion 212 of the clamping sleeve 200, but at the same time retain the ability of the clamping sleeve 200 to ultimately create a seal in the area of the ball seat 214 upon contact with the clamping sleeve 200 upon reaching it and further in the region of the profile 212 of the clamping sleeve on it to engage with the intended sleeve 106 downstream wells and the corresponding required conjugate profile 184 on her.

In particular, and importantly, due to the use of this ability of the clamping sleeve 200 to expand in the radial direction, the wear of the profiles 212 of the clamping sleeve on it is reduced, thereby maintaining the technical serviceability of the profiles 212 of the clamping sleeve and ensuring that when the clamping sleeve 200 reaches the required sliding sleeve 106 to be actuated, the corresponding profile 212 thereon was capable of engaging sufficiently and reliably while simultaneously creating an initial tight metal-to-metal connection to pressurize the up-bore side of the ball 242. Once the clamping sleeve 200 has engaged in a fixed engagement with the sliding sleeve 106, the increased pressure on the up-bore side of the ball 242 in turn causes a "domino effect" in which such an increase in pressure causes the (additional) expansion of the clamping sleeve. 200 in the radial direction, which in turn leads to a tighter metal-to-metal bond, which causes a further increase in pressure, which again causes an even greater expansion in the radial direction and thus an even tighter metal-to-metal bond. The pressure higher up the wellbore will continue to increase in this manner until it displaces the shear pins 108 holding the sliding sleeve 106 in place and then allows the sliding sleeve 106 to move down the wellbore in the valve 100 to thereby open through holes 110.

FIG. 18 shows an example of a clamping sleeve 200 according to the present invention, wherein the clamping sleeve is fitted in a sliding fit into the sliding sleeve 106, the clamping sleeve 200 being the above-mentioned preferred embodiment. In particular, according to such a preferred embodiment, the clamping sleeve 200 in the region of the ball seat 214 is of such a thickness and material and has such an initial radial difference with the bore 151 in the sleeve body 152 that when the ball 242 fits onto the ball seat 214 and applying a fluid pressure of at least 150 pounds per inch thereto, the outside diameter increases radially outward by more than 0.09%, and this would provide a sufficient tight metal-to-metal connection between the outside diameter of the clamping sleeve 200 in the area of the ball seat 214 and the bore 151 in the clutch housing 152. In particular, the outer diameter of the clamping sleeve 200 in the region of the ball seat 214 can expand outward in the radial direction under the influence of the fluid pressure on the ball 242 in the seat, the expansion in the radial direction preferably being at least 0.09% , and preferably by an amount of at least 0.2%, and more preferably by an amount of at least 0.3%, under the action of a fluid pressure upstream of the wellbore of at least 150 pounds per inch, so that to ensure the best initial clearance of the profiled section 212 on the clamping sleeve 200 with inappropriate profiles, but when interacting with the required profiled section 184 on the selected sliding sleeve 106, provide a seal between the clamping sleeve 200 in the area of the ball seat 214, sufficient for the occurrence of a "domino effect" and additional expansion of the clamping sleeve 200 in the radial direction, which would reinforce the tight metal-to-metal bond such that the outward expansion in the radial direction and the tight metal-to-metal bond is sufficient to apply additional pressure sufficient to shear the shear pins 108.

In the above-described embodiments, the clamping sleeve 200 is made from a metal tube by cutting, punching, or otherwise forming a plurality of longitudinal slots 220 in the middle portion 210 to form the petals 218. In some other embodiments, the tabs 218 may be connected to the portions 206 and 208 up and down the wellbore by other suitable means, such as welding, screwing or the like.

Example A

As noted above, FIG. 18 shows an example of a clamping sleeve 200 according to the present invention, wherein the clamping sleeve is slide fit into a sliding sleeve 106. A radially expanding portion 206 'is provided on the clamping sleeve 200 in the region of the ball seat 214.

Specifically, in this example, the clamping sleeve 200 in the area of the ball seat 214 is made of API NP 80 steel having a modulus of elasticity of 29,000,000 and a Poisson's ratio of 0.29. Sliding sleeve 106 is also made of API N80 grade steel.

According to this selected example, the clamping sleeve 200 was provided with an initial radial clearance at the contact between the outer radial edge of the clamping sleeve 200 in the region of the ball seat 214 and the inner bore 151 of the sleeve body 152, the clearance being 0.002 to 0.007 inches as determined by application of material tolerances of the clamping sleeve 200, namely the difference between the maximum and minimum dimensional tolerances of the outer diameter of the clamping sleeve 200 and the diameter of the inner bore 151 of the sliding sleeve 106 [(i.e. (4,567-4,553) / 2 and (4,562-4,558) / 2 )].

The nominal thickness of the clamping sleeve 200 in the region of the ball seat 214, namely the up-hole side of the ball seat 214, was 0.149 to 0.1515 inches [i.e. (4.553-4.255) / 2 to (4.558-4.255 ) / 2], and on the downhole side of the ball seat 214 was 0.2305 to 0.233 inches [ie, (4.553-4.092 / 2 to (4.558-4.092) / 2].

The angle of inclination θ of the ball seat 214 on the clamping sleeve 200 was 55 °. Ball 242 had a nominal diameter of 4.250 inches.

After ball 242 seated on ball seat 214, 1500 psi fluid pressure was applied to ball 242 downhole, with 0.002-0.007 in. Initial radial clearance mentioned above sufficient to initially partially stop fluid flow through this contact. As the fluid continues to be pumped under pressure, in the presence of such a partial initial obstruction, the pressure of the fluid up the wellbore from the ball 242 rises. In response to the force applied to the ball 242 by fluid pressure, the radially expandable portion 206 'of the clamping sleeve 200, due to the angle θ of the ball seat 214, creates a force directed radially outward and applied to the cylindrical clamping sleeve 200 in the region of the ball seat 214 ... This radially outwardly applied force causes the metal portion 206 'to expand outwardly in the radial direction, thereby eliminating or substantially reducing the above 0.002 to 0.007 inch gap and establishing a tight connection at the contact between the clamping sleeve 200 and the sliding sleeve 106. metal-metal.

Specifically, the radially outwardly expanding metal portion 206 'expands by at least 0.09% (in the case where the outer diameter of the radially outwardly expanding metal portion 206' is at most 4.558 inches and the inner diameter of the duct of the sliding sleeve is a minimum of 4.558 inches, namely (4.562-4.558 / 4.558)), and nominally expands in the radial direction by 0.02% (in the case where the outer diameter of the metal part 206 'expanding outwardly in the radial direction is nominally 4.555 and the inner diameter of the bore of the sliding sleeve is nominally 4.565 inches, namely (4.565-4.555 / 4.555)) and expands radially by at least 0.03% (in the case where the outer diameter of the metal part 206 ', expanding outwardly into radial direction, is a minimum of 4.553 inches and the inner diameter of the sliding sleeve is a maximum of 4.567 inches, namely (4.567-4.553 / 4.553)), which in all cases This results in a reduction in radial clearance and a tight metal-to-metal connection between the clamping sleeve 200 and the sliding sleeve 106.

It will now be clearly understood by those skilled in the art that in order to achieve the desired result of providing a clamping sleeve that expands radially, the advantage of which is that it is thereby able to reduce contact with the sliding sleeves higher up the wellbore when passing through them. to the desired sliding sleeve 106, and thus maintaining dimensional tolerances of the clamping sleeve 200, can make changes in the specific parameters listed above, in particular, in sections of its profile 212 and the outer diameter in the area of the ball seat 214, and for subsequent easier passage downward along the wellbore, due to reduced diameters, but after fixed engagement with the desired selected collar and application of fluid pressure, may "grow" to maintain an effective seal and allow sufficient pressure build-up to shear the shear screws 108.

In this example, for illustration, the sliding sleeve 106 and the clamping sleeve 200 are made of API N80 grade steel. It will be appreciated by those skilled in the art that in various other embodiments, the sliding sleeve 106 and the clamping sleeve 200 may be made from another suitable material, such as API P110 steel having a similar modulus, thereby achieving similar radial expansion for applied pressure 1500 psi.

However, according to another embodiment, in order to reduce the amount of injection pressure, but nevertheless achieve a similar amount of expansion in the radial direction (i.e., a nominal increase in the radial direction of 0.02%), the clamping sleeve 200 can be made of a material having an elastic modulus of an order of magnitude less than that of steel of the API NP 80 class (that is, 1/10 of the elastic modulus of steel of the API NP 80 class). This can then result in the applied pressure also having to be only 1/10 of the applied pressure, namely 150 psi, to still achieve the required nominal radial expansion of 0.02%.

Likewise, by decreasing or increasing the angle θ of the ball seat 214 on the clamping sleeve 200 as seen in FIG. 18, the radially outward force of the ball 242 on the edge of the clamping sleeve 200 in the region of the ball seat 214 can be varied, thereby increasing or decreasing, respectively, the magnitude of the force applied radially to the clamping sleeve 200.

So, for example, at a constant fluid pressure of 1500 psi, decreasing the tilt angle θ from 55 ° to 30 ° will increase the applied force, while decreasing the required fluid pressure from 1500 psi or using a material with a proportionally lower modulus. (that is, using a less rigid material with greater radial bending per unit of force applied) can then achieve a similar increase in radial expansion (nominally 0.02%).

Specialists in the art can now make additional changes and combine the above-mentioned variables to achieve the above-mentioned increase in the radial direction.

For example, if the angle of inclination 6 was increased from 55 ° to 80 °, thereby reducing the force acting on the clamping sleeve 200 outward in the radial direction, to achieve a similar expansion of the clamping sleeve 200 in the radial direction (nominally 0.02%), one or more of the following conditions:

(i) replacing the material from which the clamping sleeve 200 is made with a material with a lower decrease in modulus of elasticity (i.e., lower rigidity);

(ii) increasing the applied pressure of the fluid to 1500 psi, acting on the ball 242, to achieve the same tangential force that was previously applied at an angle of inclination θ equal to 55 °; or

(iii) reducing the thickness of the clamping sleeve 200 in the region of the ball seat 214 (provided that the applied pressure and the resulting force acting in the radial direction does not exceed the ultimate shear stress of the clamping sleeve 200 in the region of the ball seat 214).

Continuation of the description

FIG. 19, in some other embodiments, a clamping sleeve 200 is shown. In these embodiments, the cup valve 100 is the same as shown in FIG. one.

As seen in FIG. 19, according to these embodiments, the collar 200 provides a closed end 284 located uphole. Other parts of the clamping sleeve 200 are the same as shown in FIG. eight.

In these embodiments, no ball 242 is required to actuate the collar valve 100. Instead, a corresponding clamping sleeve 200 is pumped downhole under pressure to actuate the collar valve 100 and secured to the collar valve 100. To the uphole closed wellbore the end 284 of the collar 200 is applied fluid pressure and as a result shears the shear pin 108 and actuates the sliding sleeve 106 of the collar valve 100, which moves down the wellbore to the open position. As described above, the high strength retaining ring 192 provides improved pressure and wear resistance.

In the embodiments described above, the slide sleeve 106 provides a high strength retaining ring 192 in its downhole portion of the profiled section 182, forming a stop 194 for securing the corresponding clamping sleeve 200. In some other embodiments, the retaining ring 192 is made from the same material. as the sliding sleeve 106, but preferably of a higher strength and / or hardened material and / or nitrided material, such as, but not limited to, tungsten carbide. In some embodiments, at least stop 194 of retaining ring 192 is stiffened or stiffened substantially or approximately equal to the downhole portion of the profile of the corresponding collar 200.

In some other embodiments, the slide sleeve 106 does not include a retaining ring 192. Instead, the downhole end of the shield sleeve 154 forms a stop 194 for securing a corresponding clamping sleeve.

In some other embodiments, the sleeve body 152 and the shield sleeve 154 are combined to form a slide sleeve 106 that includes a radially outwardly expanding collar defining an abutment 194. Thus, in these embodiments, the slide sleeve 106 does not provide a retaining ring 192 ...

In some other embodiments, the sliding sleeve 106 only provides a sleeve body 152 and does not provide a protective sleeve 154. In these embodiments, the retaining ring 192 is welded, mounted, or otherwise integrated into the sleeve body 152.

In some embodiments, a plurality of collar and collar profiles may be produced and the collar profiles may be used on the same tubing in a fracturing wellbore system.

For example, in FIG. from 20A to 20D four profiles of the coupling 182-1 ÷ 182-4 (the general number for designating this position is 182) are presented on the inner surface of the sliding couplings 106-1 ÷ 106-4, respectively, and the corresponding profiles of the clamping sleeve 212-1 ÷ 212-4 (the general number for this position is 212) on the inner surface of the clamping sleeves 200-1 ÷ 200-4, respectively.

It can be seen that each profile 106-1 ÷ 106-4 provides at least two grooves 184A and 184B (hereinafter they are also referred to as "clutch grooves) and one longitudinal protrusion 232 (hereinafter referred to as" clutch longitudinal protrusion " ) passing between two grooves 184A and 184B.

Accordingly, each profile 200-1 ÷ 200-4 provides at least two longitudinal protrusions 222A and 222B (hereinafter also referred to as “longitudinal protrusions of the clamping sleeve”) and one groove 234 (hereinafter also referred to as “groove clamping sleeve ") between the two longitudinal projections 222A and 222B. In addition, the length of each groove 184A, 184B, 234 is greater than or equal to the length of each longitudinal protrusion 222A, 222B, 232 so that the profile of the clamping sleeve 200-1 ÷ 200-4 can fit into the corresponding profile 106-1 ÷ 106-4 of the sleeve.

By varying the lengths of grooves 184A and 184B and longitudinal lip 232, a variety of unique and individual sleeve profiles (and corresponding unique and individual collars of the clamping sleeve) can be obtained. According to these embodiments, the difference in lengths of the two sleeve profiles, for example the difference in lengths of the sleeve profiles 182-2 and 182-3, is an integer multiplication of a predetermined design parameter L _b , where L _b > 0. In addition, the difference in lengths between the respective grooves and longitudinal projections of the two sleeve profiles, for example, the difference in the lengths of the grooves 184A of the sleeve profiles 182-1 and 182-2, or the difference in the lengths of the grooves 184B of the sleeve profiles 182-1 and 182-2, is also an integer multiplication a given design parameter L _b , where L _b > 0.

As seen in FIG. 21A, the following parameters are used for the profile 182 of the clutch (they are all greater than zero):

L _s is the length of the profile 182 of the sleeve in the longitudinal direction;

S _g1 is the length of the groove 184A of the profile 182 of the sleeve in the longitudinal direction;

S _r is the length of the longitudinal projection 232 of the profile 182 of the coupling in the longitudinal direction; and

S _g2 is the length of the groove 184B of the sleeve profile 182 in the longitudinal direction.

The parameters L _s , S _g1 , S _r and S _g2 are measured at diametrically opposite, farthest from each other points of the profile 182 of the sleeve.

For profile 182 of the clamping sleeve, the following parameters are used (they are all greater than zero):

L _c is the length of the profile 212 of the clamping sleeve in the longitudinal direction;

C _r1 is the length of the longitudinal protrusion 222A of the profile 212 of the clamping sleeve in the longitudinal direction; and

C _g is the length of the groove 234 of the profile 212 of the clamping sleeve in the longitudinal direction; and

C _r2 is the length of the longitudinal protrusion 222B of the profile 212 of the clamping sleeve in the longitudinal direction.

The parameters L _c , C _r1 , C _g and C _{r2 are} also measured at diametrically opposite points farthest from each other on the profile 212 of the clamping sleeve.

As described above, the lengths of the grooves in the pair of corresponding clamping sleeve profile and sleeve profile, including the lengths S _g1 , S _g2 and C _{g of the} sleeve grooves 184A and 184B and the clamping sleeve grooves 234, must be greater than or equal to the lengths of the respective longitudinal projections, including the lengths C _r1 , C _r2 and S _{r of the} longitudinal protrusions 222A and 222B of the clamping sleeve and the longitudinal protrusion 232, that is, S _g1 ≥C _r1 , S _g2 ≥C _r2 and C _g ≥S _r , so that the profile 212 of the clamping sleeve fits into the corresponding profile 182 couplings.

In these embodiments, the uphole surfaces of the collar grooves 184A and 184B and the retaining ring 192 are tilted so that they expand inwardly radially up the wellbore. The uphole collar longitudinal tabs 222A and 222B and the downhole surface of the longitudinal tab 222B are inclined so that they expand outward radially down the wellbore. These tilts affect how the sleeve groove 232 and the longitudinal projections 222A and 222B can fit into the clamping sleeve groove 234 and the sleeve grooves 184A and 184B.

For ease of description, in these embodiments, the slopes of the upbore surfaces of the collar grooves 184A, 184B, the retaining ring 192, the collar longitudinal lips 222A, 222B, and the downhole surface of the longitudinal collar 222B of the collar are substantially the same.

As shown in FIG. 21B and 21C, due to the above described inclined bevels, after aligning the profile 212 of the clamping sleeve with the corresponding profile 182 of the sleeve, the clamping sleeve 200 can expand outward in the radial direction and move further down the wellbore for a short distance ε ₁ , which is a design parameter defined by the above-described ramps and the degree of engagement to engage the clutch profile 182 until the downhole surface of the collar longitudinal lip 222B engages with the stop 194 of the retaining ring 192.

As seen in FIG. 21A, the length S _{r of the} longitudinal protrusion 232 on the clutch profile 182 is defined as:

where 1≥δ≥0 is a predetermined design parameter, L _a is a predetermined design parameter and L _a > 0, n is an integer and n ≥ 0, L _b is a predetermined design parameter and L _b > 0. Thus, when n = 0, the longitudinal projection 232 has a minimum length S _r = δL _a .

The lengths S _g1 and S _{g1 of the} grooves 184A and 184B are defined as:

where m ₁ is an integer and m ₁ ≥1, and m ₂ is an integer and m ₂ > 1. Moreover,

where K> 2 is a positive integer, whereby for coupling profiles with the same K, increasing m ₁ will decrease m ₂ , thereby effectively changing the location of the longitudinal protrusion 232 on the coupling profile.

Then the length L _{s of the} profile 182 of the coupling:

Since L _a and L _b are predetermined design parameters, by choosing different n and K, a plurality of coupling profiles 182 with different lengths L _s can be obtained.

On the profile 212 of the clamping sleeve, the lengths C _r1 , C _r2 , C _{g of the} longitudinal protrusions 222A and 222B and the grooves 234 of the clamping sleeve are defined as:

where t ₁ , t ₂ and ε ₂ represent the given design parameters with 1≥t ₁ ≥0, 1≥t ₂ ≥0 and ε ₂ ≥0. Length L _from profile 212 of the clamping sleeve:

The parameter ε ₂ only determines whether the downhole surface of the collar longitudinal lip 222A will engage with the downhole surface of the collar groove 184A. In some embodiments, ε ₂ = 0 so that when the collar 200 engages with collar 106 under pressure applied from the top of the wellbore, the downhole surface of the longitudinal shoulder 222A of the collar engages the downhole along the wellbore, the surface of the collar groove 184A and the down-wellbore surface of the longitudinal lip 222B engages with the stop 194, thereby providing pressure resistance. In some other embodiments, ε ₂ > 0, in conjunction with other conditions (described below), provides additional radial outward expansion of the petals 218 and fluid pressure flexion for improved grip of the clamping sleeve 200 with the sliding sleeve 106.

As seen in FIG. 21A, in embodiments where ε ₂ = 0, at t ₁ = 1, there is a maximum difference in length L _b between the sleeve groove 184A and the longitudinal projection 222A of the clamping sleeve; when t ₁ = 0, the sleeve groove 184A and the clamping sleeve longitudinal projection 222A are of the same length. Likewise, at t ₂ = 1, there is a maximum difference L _{b between the} lengths of the sleeve groove 184B and the longitudinal projection 222B of the clamping sleeve; when t ₂ = 0, the sleeve groove 184B and the longitudinal projection 222B of the clamping sleeve have the same length.

In some embodiments, the design parameters are set as L _a = L _b , t ₁ = t ₂ = t, and 1>t> 0. Then the parameters of the profile 182 of the coupling take the form:

The parameters of the profile 212 of the clamping sleeve take the form:

Taking into account ε ₂ , the parameter t determines the difference in the lengths of the grooves and the corresponding longitudinal projections. If t = 0, the sleeve profile 182 and the clamping sleeve profile 212 have the same length. If t = 1, the sleeve profile 182 and the clamping sleeve profile 212 have a maximum difference in length L _b . In embodiments where ε ₂ = 0, if t = 0, the grooves and their corresponding longitudinal ridges are of the same length. If t = 1, the grooves and their corresponding longitudinal projections have a maximum difference in length L _b .

Various coupling profiles and clamping sleeve profiles are available. For ease of description, coupling profiles and clamping sleeve profiles are grouped into profile sets, and profile sets are grouped into profile categories. Further in this document, the clutch profile is designated as "S ({category letter} {set number} - {profile number})", where "{category letter" can be the letter A, B, C, ..., this reflects the category profile to which the coupling belongs, "{set number}" can be 1, 2, 3, ..., this reflects the set of profiles to which the coupling profile belongs, and {profile number} can be 1, 2, 3, ... , this reflects the serial number of the coupling profile in the set. For example, the sleeve profile "S (A1-1)" denotes the first sleeve profile in set A1.

Likewise, the profile of the clamping sleeve is designated as "C ({category letter} {set number} - {profile number}". For example, the profile of the clamping sleeve "C (B2-3)" denotes the third sleeve profile in the set B2.

As can be seen, by varying the values of n , K and m ₁ , a plurality of sleeve profiles 182 and clamping sleeve profiles 212 are obtained. Thus, for ease of description, the profile of the sleeve may also be denoted as S [ n , K, m ₁ ], and the profile of the clamping sleeve may be denoted as C [ n , K, m ₁ ].

According to these embodiments, for a given L _{b, the} sum ( n + K) determines the length L _{s of} the sleeve profile and the length L _{c of the} sleeve profile. In particular, the coupling profiles in each profile category (for example, "A") have the same length L _s = ( n + K + 1) L _b , and the clamping sleeve profiles in one profile category have the same length L _c = ( n + K + 1-t) L _b .

The parameter n defines the length of the longitudinal projection 232 of the sleeve and the length of the groove 234 of the clamping sleeve. Thus, the profiles of the sleeve in each set of profiles (for example, "A1") have the same length of the longitudinal protrusion 232, which is defined as S _r = ( n + δ) L _b , and the profiles of the clamping sleeve in one set of profiles have the same length of the groove 234 , which is defined as C _g = ( n + t + δ) L _b + ε ₂ .

Each set of profiles contains (K-2) coupling profiles and (K-2) corresponding clamping sleeve profiles with the same n and the same K, in which all (K-2) coupling profiles have the same length L _s = ( n + K + 1 ) L _b and the same S _r = ( n + δ) L _b , and all (K-2) profiles of the clamping sleeve have the same length L _c = ( n + K + 1-t) L _b and the same C _g = ( n + t + δ) L _b + ε ₂ .

It will be understood by those skilled in the art that if t is equal to or close to 0, then the profile of the clamping sleeve completely or almost completely coincides with the profile of the sleeve, and therefore there may be a risk that the profile of the clamping sleeve cannot enter the corresponding profile of the sleeve, for example, due to the large tolerance for the profile of the clamping sleeve and / or the profile of the sleeve, and / or the high speed of entry of the clamping sleeve 200 into the sliding sleeve 106, so that the offset profile of the clamping sleeve does not have enough time to return to the unbiased position before the clamping sleeve 200 will come out of sliding sleeve 106.

On the other hand, if t is equal to or close to 1, the grooves and their corresponding longitudinal ridges have a maximum difference in lengths L _b , and there may be a risk that the profile of the clamping sleeve may mistakenly enter the inappropriate profile of the sleeve (described below).

In some embodiments, t may be selected large enough to zero and less than one enough to provide the following:

(i) the profile of the clamping sleeve, corresponding to the profile of the sleeve in the set, can easily be overridden by any other profile of the sleeve in the same set; and

(ii) the difference in lengths between the groove and its corresponding longitudinal ridge (for example, the difference in lengths between the sleeve groove 184A and the longitudinal ridge 222A of the clamping sleeve, the difference in length between the groove 234 of the clamping sleeve and the longitudinal ridge 232 of the sleeve, or the difference in lengths between the groove 184B of the sleeve and the longitudinal clamping sleeve protrusion 222B) is sufficient for easy entry of the longitudinal protrusion into the groove.

For example, in one embodiment, t may be selected according to 0.9≥t≥0.1. In other embodiments, t may be selected according to the expression 0.8 t. 0.2. In other embodiments, t may be selected according to 0.7≥t≥0.3. In other embodiments, t may be selected according to 0.6≥t≥0.4. In other embodiments, t may be selected to be about 0.5.

FIG. 22 shows a set A1 of four coupling profiles and four corresponding clamping sleeve profiles, where n = 0 and K = 6, while the coupling profiles have the same length L _s = 7L _b .

FIG. 23 shows a set B1 of six profiles of the coupling and six corresponding profiles of the clamping sleeve at n = 0 and K = 8, while the profiles of the coupling have the same length L _s = 9L _b .

FIG. 24 shows a set C1 of eight sleeve profiles and eight corresponding clamping sleeve profiles, where n = 0 and K = 10, while the sleeve profiles have the same length L _s = 11L _b .

FIG. 25 shows a set D1 of ten coupling profiles and ten corresponding clamping sleeve profiles, where n = 0 and K = 12, while the coupling profiles have the same length L _s = 13L _b .

FIG. 26 shows a set A2 of three coupling profiles and three corresponding clamping sleeve profiles, where n = 1 and K = 5, while the coupling profiles have the same length L _s = 7L _b .

FIG. 27 shows a set B2 of five coupling profiles and five corresponding clamping sleeve profiles for n = 1 and K = 7, while the coupling profiles have the same length L _s = 9L _b .

FIG. 28 shows a set C2 of seven sleeve profiles and seven corresponding clamping sleeve profiles, where n = 1 and K = 9, with the sleeve profiles having the same length L _s = 11L _b .

FIG. 29 shows a set D2 of nine sleeve profiles and nine corresponding clamping sleeve profiles, where n = 1 and K = 11, with the sleeve profiles having the same length L _s = 13L _b .

FIG. 30 shows a set A3 of two sleeve profiles and two corresponding clamping sleeve profiles, where n = 2 and K = 4, the sleeve profiles having the same length L _s = 7L _b .

FIG. 31 shows a set B3 of four sleeve profiles and four corresponding clamping sleeve profiles, where n = 2 and K = 6, the sleeve profiles having the same length L _s = 9L _b .

FIG. 32 shows a set C3 of six coupling profiles and six corresponding clamping sleeve profiles for n = 2 and K = 8, while the coupling profiles have the same length L _s = 11L _b .

FIG. 33 shows a set D3 of eight coupling profiles and eight corresponding clamping sleeve profiles, where n = 2 and K = 10, while the coupling profiles have the same length L _s = 13L _b .

FIG. 34 shows a set A4 of one profile of the sleeve and one corresponding profile of the clamping sleeve, where n = 3 and K = 3, while the profile of the sleeve has a length L _s = 7L _b .

FIG. 35 shows a set B4 of three sleeve profiles and three corresponding clamping sleeve profiles, where n = 3 and K = 5, the sleeve profiles having the same length L _s = 9L _b .

FIG. 36 shows a set C4 of five coupling profiles and five corresponding clamping sleeve profiles for n = 3 and K = 7, while the coupling profiles have the same length L _s = 11L _b .

FIG. 37 shows a set D4 of seven coupling profiles and seven corresponding clamping sleeve profiles, where n = 3 and K = 9, while the coupling profiles have the same length L _s = 13L _b .

FIG. 38 shows a set B5 of two sleeve profiles and two corresponding clamping sleeve profiles, where n = 4 and K = 4, while the sleeve profiles have the same length L _s = 9L _b .

FIG. 39 shows a set C5 of four sleeve profiles and four corresponding clamping sleeve profiles, where n = 4 and K = 6, with the sleeve profiles having the same length L _s = 11L _b .

FIG. 40 shows a set D5 of six profiles of the coupling and six corresponding profiles of the clamping sleeve with n = 4 and K = 8, while the profiles of the coupling have the same length L _s = 13L _b .

FIG. 41 shows a set B6 of one sleeve profile and one corresponding clamping sleeve profile, where n = 5 and K = 3, the sleeve profile having a length L _s = 9L _b .

FIG. 42 shows a set C6 of three sleeve profiles and three corresponding clamping sleeve profiles, where n = 5 and K = 5, the sleeve profiles having the same length L _s = 11L _b .

FIG. 43 shows a set D6 of five coupling profiles and five corresponding clamping sleeve profiles for n = 5 and K = 7, while the coupling profiles have the same length L _s = 13L _b .

FIG. 44 shows a set C7 of two sleeve profiles and two corresponding clamping sleeve profiles, where n = 6 and K = 4, with the sleeve profiles having the same length L _s = 11L _b .

FIG. 45 shows a set D7 of four coupling profiles and four corresponding clamping sleeve profiles, where n = 6 and K = 6, with the coupling profiles having the same length L _s = 13L _b .

FIG. 46 shows a set C8 of one sleeve profile and one corresponding clamping sleeve profile, where n = 7 and K = 3, the sleeve profile having a length L _s = 11L _b .

FIG. 47 shows a set D8 of three coupling profiles and three corresponding clamping sleeve profiles, where n = 7 and K = 5, while the coupling profiles have the same length L _s = 13L _b .

FIG. 48 shows a set D9 of two coupling profiles and two corresponding clamping sleeve profiles, where n = 8 and K = 4, while the coupling profiles have the same length L _s = 13L _b .

FIG. 49 shows a set D8 of one sleeve profile and one corresponding clamping sleeve profile, where n = 9 and K = 3, while the sleeve profile has a length L _s = 13L _b .

Table 1 summarizes the profile sets shown in FIG. 22 to 49. It can be seen that by limiting the sleeve profile lengths to 7L _b , 9L _b , 11L _b, and 13L _b , a total of 122 sleeve profiles and 122 corresponding collar profiles can be obtained and used for fracturing in the well.

In embodiments in which two or more collar valves 100 with the above-described coupling profiles are used on the tubing string, the order of the coupling profiles should be as follows:

(a) lip valves must have different sleeve profiles; in other words, for any two cuff valves, at least one of n , K and m ₁ is different;

(b) lip valves with a shorter L _s length should be located higher up the wellbore than those with a longer L _s length; in other words, the lip valve with a smaller value (n + K) have uphole than those in which (n + K) is larger;

(c) in the case of cup valves of equal length L _s, those with _{larger S r} should be located higher up the wellbore than those with smaller _{S r;} in other words, for cup valves with the same value ( n + K), those with more n are located higher up the wellbore from those with less n; and

(d) lip valves with the same set of profiles, that is, with the same n and the same K, but with different m ₁ , can be arranged in any order.

In other words, collar valves marked with a "lower" category (eg, "A"), that is, collar valves with a shorter _{sleeve profile length L s} should be located higher up the wellbore than those marked with a "higher "Category (for example," D "), that is, having a greater value of the length L _{s of} the sleeve profile. Among the collar valves designated by the letter of the same category, that is, having the same length L _{s of} the sleeve profile, those that have a lower set number (for example, "A1") should be located lower along the wellbore than those that have a larger dial number (for example, "A3"). FIG. 50 illustrates an example of a tubing string (eg, casing or tubing) with a plurality of collar valves 100 arranged in the order described above.

In some other embodiments, where t is equal to or close to 1, and the grooves and their corresponding longitudinal ridges have a maximum difference in length L _b, and therefore the two "adjacent" profiles of the sleeve and the clamping sleeve are compatible.

That is, the profile of the clamping sleeve can be included not only in the corresponding profile of the coupling, but also in the profile of the coupling, which is indicated by a letter of the same category, with the same set number and an "adjacent" profile number (that is, 1 higher or lower) ... For example, the profile of the clamping sleeve C (A1-2), that is, C [0, 6, 2], can be included in the previous and next coupling profiles S (A1-1) and S (A1-2), that is, S [0, 6, 1] and S [0, 6, 3], but cannot be included in other coupling profiles from the set of profiles A1, for example, S (A1-4).

In other words, a sleeve profile can be included in the previous and next sleeve profiles from the same set of profiles, but cannot be included in other coupling profiles from the same set of profiles. That is, the profile of the clamping sleeve C [ n , K, i] can enter into the coupling profiles S [ n , K, i + 1] and S [ n , K, i-1], but cannot enter into other coupling profiles, that is, into the profiles of the coupling S [ n , K, j], where j ≠ i, j ≠ i + 1 and j ≠ i-1.

Thus, in embodiments in which t = 1, two or more collar valves 100 are used on the pipe string with coupling profiles as shown in FIG. from 22 to 49, the order of the coupling profiles should be as follows:

(a) lip valves must have different sleeve profiles; in other words, for any two cuff valves, at least one of n , K and m ₁ is different;

(b) in each set of profiles, two coupling profiles S [ n , K, j ₁ ] and S [ n , K, j ₂ ] should not be used on the same pipe string if ⏐j ₁ -j ₂ ⏐≤1 ; in other words, for any two cuff valves with the same n and the same K, the difference between their m ₁ must be greater than 1;

(c) lip valves with a shorter L _s length should be located higher up the wellbore than those with a longer L _s length; in other words, the lip valve with a smaller value (n + K) have uphole than those in which (n + K) greater;

(d) in the case of cup valves of equal length L _s, those with _{larger S r} should be located higher up the wellbore than those with smaller _{S r;} in other words, for cup valves with the same value ( n + K), those with more n are located higher up the wellbore from those with less n; and

(e) lip valves with the same set of profiles, that is, with the same n and the same K, but with different m ₁ , can be arranged in any order.

In some other embodiments, the above described coupling profiles and clamping sleeve profiles can be connected in series or cascade together with other suitable profiles to form elongated profiles. For example, in FIG. 51 shows a set of elongated sleeve profiles and clamping sleeve profiles that are obtained by connecting the same profile 286 in series between a profile in profile set A1 and a retaining ring 192. As seen in FIG. 52, in some embodiments, to obtain elongated profiles, the same profile 286 may be connected in series uphole with profiles from set A1.

In some embodiments, profiles in the same set can be connected in series with different profiles to form elongated profiles. For example, in FIG. 53 shows the profiles of set A1 connected in series with the first four profiles from set B2 to obtain elongated profiles.

In the above embodiments, the collar profile is on the inner surface of the collar body 152 such that the stop 194 of the retaining ring 192 is located downhole therefrom. In some other embodiments, such as shown in FIG. 54 through 56, the sleeve profile provides a part of the profile on the inner surface of the sleeve body 152, as described above, and a part of the profile on the inner surface of the shield 154, so that the stop 194 of the circlip 192 is in the profile of the sleeve.

Accordingly, the clamping sleeve 200 may have a clamping sleeve profile on both the sleeve body 152 and the sleeve 154 to match the profile of the sleeve. To allow the front or downhole portion of the collar 200 to pass freely through the stop ring 192, each protrusion 292 on the collar 200 that matches the profile on the collar 154 has an obtuse angle on the downhole side.

The profile on the sleeve 154 can be of any suitable shape and can be combined with any suitable profile of the sleeve body 152, such as those shown in FIGS. 22 to 49. For example, in FIG. 54 to 57 show a protective sleeve 154 with a groove 294 of length 2L _b , which is combined with the sets of profiles A1, B1, C1 and D1, respectively, shown in FIGS. 22 to 25. Accordingly, the profile of the clamping sleeve on the clamping sleeve 200 provides for a projection or longitudinal projection 292 of length L _b to correspond to a groove 294.

In some embodiments, groove 294 may have other suitable lengths. For example, in FIG. 58 to 61 show a protective sleeve 154 with a groove 294 of length 3L _b , which is combined with the sets of profiles A1, B1, C1 and D1, respectively, shown in FIGS. 22 to 25. Accordingly, the profile of the clamping sleeve on the clamping sleeve 200 provides a protrusion or longitudinal protrusion 292 of length 2L _b to correspond to the groove 294.

In some embodiments, the profile of the protective sleeve 154 may include one or more grooves and / or one or more longitudinal ridges.

In some embodiments, the profile of the protective sleeve 154 may be a profile selected from those shown in FIG. 22 to 49. For example, a set of elongated profiles can be obtained by daisy-chaining them in a set of profiles A1 with the first four profiles in a set of profiles B2, with the first four profiles in a set of profiles B2 located downhole from the retaining ring 192 or on protective sleeve 154.

As seen in FIG. 62, in some other embodiments, the collar profile (eg, the collar profile in the set of profiles A1) may be located downhole from the retaining ring 192. Therefore, the stop 194 is located uphole from the collar profile. In these embodiments, each protrusion on the collar 200 has an obtuse angle on the downhole side to allow the retaining ring 192 to pass through the collar 200 without obstruction.

As described above and shown in FIG. 15A and 15B, the sliding sleeve 126 of the lip valve 100 may be pushed open by pressure from the ball 242 and the clamping sleeve 200 to expose the fracturing ports, whereby the petals 218 of the clamping sleeve 200 are able to expand radially outward under pressure. when fluid pressure is applied from the top of the wellbore and compression of the clamping sleeve causes the profile 212 of the clamping sleeve to engage with the stop 194 of the retaining ring 192, causing the petals 218 to expand radially outward to further engage the sliding sleeve 106 for better grip, and , thus, additional resistance to pressure. FIG. 63A through 63F show in greater detail the profile 212 of the clamping sleeve expanding radially outward.

As seen in FIG. 63A, for ease of description, sleeve grooves 184A and 184B are assumed to have the same inner diameter and longitudinal projections 222A and 222B of the clamping sleeve are assumed to have the same outer diameter.

The depth H _{sg1 of the} uphole collar groove 184A is measured radially between its outermost surface (i.e., their "bottom") and its closest to the center edge (i.e., its "top" edge located above along the wellbore). The height H _{sr of the} collar longitudinal lip 232 is measured radially between its closest to the center surface (ie, its “top”) and its most out-of-center edge (ie, its “bottom” edge). The depth H _{sg2 of the collar} groove 184B downhole is measured radially between its outermost surface and its outermost edge, which is also the centermost edge of the abutment 194.

Likewise, the height H _{cr1 of the} up-bore longitudinal collars 222A of the collar is measured in the radial direction between their outermost surface (i.e., their "top") and their near-center edge located upstream of the wellbore (i.e. is, their "bottom" edge located higher along the wellbore). The depth H _{cg of the} clamping sleeve longitudinal ridge 234 is measured radially between its closest to the center surface (ie, its “bottom”) and its most out-of-center edge (ie, its “top” edge). The height H _cr2 of the downhole longitudinal collars 222B of the collar is measured radially between their outermost surface (i.e., their "top") and their closest downhole edge (i.e., their "bottom" edge located down the wellbore).

In some embodiments, as shown in FIG. from 63A to 63C, H _sg1 = H _sg2 = H _sr = H _s and H _cr1 = H _cr2 = H _cr . As seen in FIG. 63B, in order to allow the profile 212 of the clamping sleeve to expand radially outwardly when the profile 212 of the clamping sleeve engages the profile 182 of the sleeve, it is necessary that between each of the grooves 184A and 184B and the groove 234 of the clamping sleeve and each of the longitudinal the lugs 222A and 222B and the longitudinal projection 232 of the sleeve retained clearance. In other words, H _s -H _cr > 0, H _cg -H _cr > 0 and ε ₂ > 0. Therefore, according to these embodiments, H _s > H _cr , H _cg > H _cr, and ε ₂ > 0.

In some embodiments, where H _sg1 = H _sg2 = H _sr = H _s and H _cr1 = H _cr2 = H _cr and the collar groove 234 is at a location near the center of the long axis of the collar profile 212, the collar groove 234 is the most an expanded portion where the petals 218 are radially expanded outward or curved (FIG. 63C). According to these embodiments, H _s > H _cr , H _cg > H _cr, and ε ₂ > 0 are required. Preferably, the clearance between the collar groove 232 and the sleeve longitudinal lip 232 is greater than or equal to the clearance between the sleeve groove 184A / 184B and the corresponding collar longitudinal lip 222A / 222B. In other words, H _s -H _cr > 0, H _cg -H _cr > 0, H _cg -H _cr > H _s -H _cr and ε ₂ > 0. Therefore, according to these embodiments, H _cg ≥ _{H s} > H _cr and ε ₂ > 0. In some embodiments, it is preferred that H _cg = H _s > H _cr and ε ₂ > 0 so that when the clamping sleeve profile 212 is expanded radially outward in the sleeve profile 182, the longitudinal protrusion 234 of the clamping sleeve can fully engage with longitudinal protrusion 232 of the coupling and close the gap between them.

As shown in FIG. 63B and 63C, after the collar 200 engages with the sliding sleeve 106, additional pressure uphole therefrom may move the collar 200 further down the wellbore causing the petals 218 to expand radially outward or flex and further engage even more strongly with the sliding sleeve 106.

In some embodiments, as shown in FIG. 63D through 63F, the depth of the up-hole sleeve groove 184A is the same as the height of the longitudinal lip 232 of the sleeve. However, the collar groove 184B below the wellbore has a depth that is greater than the depth of the upbore collar groove 184A. That is, H _sg1 = H _sr = H _s and H _sg2 > H _s . The heights of the clamping sleeve longitudinal projections 222A and 222B and the depth of the clamping sleeve groove 234 are the same. That is, H _cr1 = H _cr2 = H _cr .

As seen in FIG. 63E, according to these embodiments, H _cg + H _sg2 -H _cr -H _s > 0, H _sg2 -H _cr > 0, and ε ₂ > 0 to allow the clamping sleeve profile 212 to expand radially outwardly when the clamping profile 212 is sleeve engages with profile 182 of the coupling.

In some embodiments, where H _sg1 = H _sr = H _s , H _sg2 > H _s , H _cr1 = H _cr2 = H _cr, and the collar groove 234 is at a location near the center of the long axis of the collar profile 212, the collar groove 234 is the most widened portion where the petals 218 are radially extended outward (FIG. 63E).

According to these embodiments, H _cg + H _sg2 —H _cr —H _s > 0, H _sg2 —H _cr > 0, and ε ₂ > 0. Preferably, the clearance between the collar groove 232 and the sleeve longitudinal lip 232 is greater than or equal to the clearance between the sleeve groove 184A / 184B and the corresponding collar longitudinal lip 222A / 222B. In other words, H _cg + H _sg2 -H _cr -H _s ≥H _sg2 -H _cr . Therefore, according to these embodiments, H _sg2 > H _cr , H _cg ≥ _{H s,} and ε ₂ > 0. According to some embodiments, it is preferred that H _sg2 > H _cr , H _cg = H _s and ε ₂ > 0 so that when the clamping sleeve profile 212 is expanded radially outward in the sleeve profile 182, the longitudinal protrusion 234 of the clamping sleeve can fully enter into engagement with the longitudinal protrusion 232 of the clutch and close the gap between them.

Although the embodiments have been described above with reference to the accompanying figures, those skilled in the art will appreciate that changes and additions can be made without departing from the scope of the present invention.

For a complete definition of the present invention and its intended scope, reference should be made to the Summary of the Invention and the appended claims, together with the detailed description and drawings included herein, in accordance with their intended interpretation.

Claims (58)

1. A clamping sleeve for use with a lip valve, comprising a valve body having a longitudinal bore extending therethrough and one or more fluid openings on an uphole portion of its sidewall, and a sliding sleeve disposed in the longitudinal bore of the valve body, and movable between a closed position up-borehole, closing one or more fluid openings, and an open position down-borehole, opening one or more fluid openings, wherein the sliding sleeve comprises a longitudinal channel for positioning a clamping sleeve therein , and the clamping sleeve contains: a ball seat having a ball seat surface that is inclined radially inwardly from top to bottom along the wellbore at an acute angle of inclination to the longitudinal axis of the clamping sleeve; and a radially expandable portion located in close proximity and circumferentially around said ball seat; and the radially expandable portion is configured to expand radially outwardly by at least 0.09% under a pressure of at least 150 psi, which acts on the ball seated in said ball seat so that it forms a seal in the point of contact between the clamping sleeve and the longitudinal bore of the sliding sleeve when the clamping sleeve is located in the sliding sleeve. 2. A clamping sleeve as claimed in claim 1, wherein when said pressure is applied to the ball, the radially expandable portion expands radially outwardly by at least 0.2%. 3. The clamping sleeve of claim 2, wherein when said fluid pressure of about 1500 psi or more is applied to the ball, the radially expandable portion expands radially outwardly by at least 0.2%. 4. The clamping sleeve of claim 1, wherein the angle of inclination is from about 25 ° to about 70 °. 5. A clamping sleeve according to claim 1, wherein the angle of inclination is about 35 °. 6. The clamping sleeve of claim 3, wherein the angle of inclination is from about 50 ° to about 60 °. 7. A clamping sleeve according to claim 1, wherein a ball seat and a radially expandable portion of said clamping sleeve are each positioned together adjacent an uphole end of said clamping sleeve. 8. Clamping sleeve according to any one of paragraphs. 1-7, in which the angle of inclination is about 55 °. 9. Clamping sleeve according to any one of paragraphs. 1-8, in which the radially expandable portion of the clamping sleeve in the area of the ball seat is composed of a material having a modulus of elasticity of about 29,000,000 psi. 10. Clamping sleeve according to any one of paragraphs. 1-9, in which at least the radially expandable part of the clamping sleeve in the region of the ball seat is made of metal or contains metal. 11. Clamping sleeve according to any one of paragraphs. 1-10, wherein the radially expandable portion of the clamping sleeve in the area of the ball seat contains American Petroleum Institute N80 (API N80) steel. 12. Clamping sleeve according to any one of paragraphs. 1-10, in which the radially expandable part of the clamping sleeve in the area of the ball seat is made of API P110 steel. 13. Clamping sleeve according to any one of paragraphs. 1-12, which additionally contains: the cylindrical part up the wellbore; a cylindrical part down the wellbore; and at least one flexible-elastic petal located on the outer annular surface of the specified clamping sleeve, with each petal being connected to a part above the wellbore and a part below the wellbore at its two corresponding longitudinally opposite each other ends; and wherein at least one petal contains on its outer surface the profile of the clamping sleeve corresponding to the profile of the sleeve on the inner surface of the sliding sleeve. 14. The clamping sleeve according to claim 12, in which when the said petal is coupled with the specified profile of the coupling and when the specified pressure is applied to the specified ball, when the specified ball is seated on the specified ball seat, the specified at least one flexible-elastic petal is bent outward in radially so that the profile of the clamping sleeve additionally and to a greater extent engages with the profile of the sleeve on the inner surface of said sliding sleeve. 15. A cuff valve containing: a valve body having a longitudinal bore extending therethrough and one or more fluid openings on an up-borehole portion of its sidewall; a sliding sleeve located in the longitudinal bore of the valve body and configured to move between a closed position up-borehole, closing one or more fluid openings, and an open position down-borehole, opening one or more fluid openings, the sliding the sleeve contains a longitudinal channel; and clamping sleeve for positioning in the channel of the sliding sleeve; the clamping sleeve contains: a ball seat having a ball seat surface that is radially inclined inwardly from top to bottom along the wellbore at an acute angle of inclination to the longitudinal axis of the clamping sleeve; and a radially expandable portion located in close proximity and circumferentially around said ball seat; and the radially expandable portion is configured to expand radially outwardly by at least 0.09% under a pressure of at least 150 psi, which acts on the ball seated in said ball seat so that it forms a seal in the point of contact between the clamping sleeve and the longitudinal bore of the sliding sleeve when the clamping sleeve is located in the sliding sleeve. 16. The lip valve of claim 15, wherein when said pressure of at least 150 psi is applied, the radially expandable portion of the clamping sleeve expands radially outwardly by at least 0.2%. 17. The lip valve of claim 16, wherein when a pressure of about 1500 psi or more is applied, the radially expandable portion of the clamping sleeve expands radially outwardly by at least 0.2% of the outer diameter of the collet. 18. The lip valve of claim 15, wherein the ball seat angle of the clamping sleeve is about 15 ° to about 70 °. 19. The lip valve of claim 15, wherein the ball seat angle is about 35 °. 20. The cuff valve of claim 15, wherein the angle of inclination is from about 50 ° to about 60 °. 21. The cuff valve according to any one of paragraphs. 15-20, in which the ball seat is located adjacent to the up-wellbore end of the specified clamping sleeve. 22. The cuff valve according to any one of paragraphs. 15-18, in which the angle of inclination is about 55 °. 23. The cuff valve according to any one of paragraphs. 15-22, in which at least the radially expandable portion of the clamping sleeve is made of metal or contains metal. 24. The cuff valve according to any one of paragraphs. 15-20, in which the radially expandable portion of its clamping sleeve contains API N80 steel. 25. The cuff valve according to any one of paragraphs. 15-20, in which the radially expandable part of its clamping sleeve contains steel grade API P110. 26. The cuff valve according to any one of paragraphs. 15-25, in which the clamping sleeve additionally contains: the cylindrical part up the wellbore; a cylindrical part down the wellbore; and a plurality of flexible-elastic petals, respectively, connected to a part above the wellbore and a part below the wellbore at their two longitudinally opposite ends; and wherein at least one petal contains on its outer surface the profile of the clamping sleeve corresponding to the profile of the sleeve on the inner surface of the sliding sleeve. 27. A cuff valve according to claim 26, wherein when said petal is coupled to said clutch profile and when said pressure is applied to said ball, when said ball is seated on said ball seat, said at least one flexible petal is bent outward in a radial direction so that the profile of the clamping sleeve additionally and to a greater extent engages with the profile of the sleeve on the inner surface of said sliding sleeve. 28. A clamping sleeve for use with a lip valve, comprising a valve body having a longitudinal bore extending therethrough and one or more openings in an up-borehole portion of its sidewall, and a metal sliding sleeve disposed in the bore of the valve body and configured to movement between a closed position up-borehole, closing one or more fluid openings, and an open position down-bore, opening one or more fluid openings, wherein the sliding sleeve comprises a sleeve profile on its inner surface and a longitudinal channel for positioning it contains a clamping sleeve, wherein the clamping sleeve contains: a ball seat having a ball seat surface that is radially inclined inwardly from top to bottom along the wellbore at an acute angle of inclination to the longitudinal axis of the clamping sleeve; the cylindrical part up the wellbore; a cylindrical part down the wellbore; and a plurality of flexible-elastic petals, respectively, connected to a part above the wellbore and a part below the wellbore at their two longitudinally opposite ends; and wherein each of the said petals contains on its outer surface the profile of the clamping sleeve, corresponding to the profile of the coupling; and at the same time, when the said petals are coupled with the specified profile of the coupling, and when the ball lands on the specified ball seat, and when fluid pressure is applied to the specified ball, when the specified ball is seated on the specified ball seat, the said flexible petals are made with the ability to bend outward in a radial direction so that the profile of the clamping sleeve additionally and to a greater extent engages with the profile of the sleeve on the inner surface of said sliding sleeve. 29. A method for actuating a sliding sleeve having a longitudinal channel, the method comprising: providing a clamping sleeve configured to be positioned in a bore of a sliding sleeve, said clamping sleeve comprising a radially outward expandable metal portion adjacent the uphole end of the clamping sleeve, and a ball seat having a ball seat surface that is radially inclined inwardly from top to bottom along the wellbore at an acute angle of inclination to the longitudinal axis of the clamping sleeve; initiating downward flow of the clamping sleeve into the wellbore and fixing it in the bore of the sliding sleeve; flowing the ball down into the borehole and landing the ball in the ball seat; applying a first fluid pressure from the top of the wellbore to press the ball against the ball seat and cause the portion of the clamping sleeve in the area of the ball seat to expand outward in the radial direction to form a seal at the contact of the clamping sleeve in the area of the ball seat and the sliding sleeve; and applying a second fluid pressure from the top of the wellbore to shear the shear pins and slide the sliding sleeve down the wellbore and open the hole.

Images