US20180258721A1

US20180258721A1 - Downhole valve assembly and method of using same

Info

Publication number: US20180258721A1
Application number: US15/754,886
Authority: US
Inventors: Bharat B. PAWAR; Desmond W. JONES; Robert Gordon Howard
Original assignee: Halliburton Energy Services Inc
Current assignee: Halliburton Energy Services Inc
Priority date: 2015-10-14
Filing date: 2015-10-14
Publication date: 2018-09-13
Also published as: CA2998108A1; GB201803023D0; GB2557504B; GB2557504A; NL1042008B1; FR3042534A1; WO2017065752A1; NL1042008A; IT201600090975A1; CA2998108C

Abstract

Actuatable valve tool including a tubular housing forming an axial flowbore. A slidable flow tube disposed within the housing and a shear sleeve disposed around at least a portion of the slidable flow tube. One or more valves disposed within the housing, each having an open position and a closed position. In the open position the one or more valves permit fluid flow within the axial flowbore, and in the closed position the one or more valves block fluid flow therethrough. The slidable flow tube moveable within the housing to transition the one or more valves between the closed position and the open position.

Description

FIELD

The subject matter herein generally relates to a downhole valve assembly and method of using the same, and in particular, a downhole valve assembly to access wells under pressure.

BACKGROUND

Wells are often stimulated by hydraulic fracturing operations, during which a servicing fluid or a perforating fluid is introduced into at least a portion of a subterranean formation. The fluid can be at a hydraulic pressure sufficient to create or enhance at least one fracture therein, thereby increasing hydrocarbon production from the well.
A tubular work string can be used to communicate fluid to and from the subterranean formation during a wellbore stimulation operation. During a wellbore servicing operation, it can be desirable to fluidically isolate two or more sections of the work string, so as to close off fluid communication through the work string flowbore in at least one direction. Closing off fluid communication through a work string can allow for the isolation of well pressure within the work string flowbore during run-in and/or run-out of a work string.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 illustrates a system for preparation and delivery of a cement composition to a wellbore in accordance with aspects of the present disclosure;

FIG. 2 is cross-sectional view of an example embodiment downhole valve assembly in a first position;

FIG. 3 is cross-sectional view of an example embodiment a downhole valve assembly in a second position;

FIG. 4 is cross-sectional view of an example embodiment a downhole valve assembly in a third position;

FIG. 5 is cross-sectional view of an example embodiment a downhole valve assembly in a fourth position;

FIG. 6 is a cross-section view of an example embodiment of a downhole valve assembly in a fifth position;

FIG. 7 is an enlarged cross-sectional view of an example embodiment downhole valve assembly having a sheer sleeve in a first sheer position;

FIG. 8 is an enlarged cross-sectional view of an example embodiment downhole valve assembly having a sheer sleeve in a second sheer position;

FIG. 9 is an enlarged cross-sectional view of an example embodiment downhole valve assembly having a sheer sleeve in a third sheer position;

FIG. 10 is an isometric view of an example embodiment of a indexing sleeve of a downhole valve assembly; and

FIG. 11 is a flow chart of an exemplary method of a particulate dispenser in accordance with aspects of the present disclosure.

DETAILED DESCRIPTION

It will be appreciated that for simplicity and clarity of illustration, where appropriate, reference numerals have been repeated among the different figures to indicate corresponding or analogous elements. In addition, numerous specific details are set forth in order to provide a thorough understanding of the embodiments described herein. However, it will be understood by those of ordinary skill in the art that the embodiments described herein can be practiced without these specific details. In other instances, methods, procedures and components have not been described in detail so as not to obscure the related relevant feature being described. Also, the description is not to be considered as limiting the scope of the embodiments described herein. The drawings are not necessarily to scale and the proportions of certain parts have been exaggerated to better illustrate details and features of the present disclosure.
In the following description, terms such as “upper,” “upward,” “lower,” “downward,” “above,” “below,” “downhole,” “uphole,” “longitudinal,” “lateral,” and the like, as used herein, shall mean in relation to the bottom or furthest extent of the surrounding wellbore even though the wellbore or portions of it may be deviated or horizontal. Correspondingly, the transverse, axial, lateral, longitudinal, radial, etc., orientations shall mean orientations relative to the orientation of the wellbore or tool. Unless otherwise specified, any use of any form of the term “couple,” or any other term describing an interaction between elements is not meant to limit the interaction to direct interaction between the elements and also may include indirect interaction between the elements described.
The term “inside” indicate that at least a portion of a region is partially contained within a boundary formed by the object. The term “substantially” is defined to be essentially conforming to the particular dimension, shape or other word that substantially modifies, such that the component need not be exact. For example, substantially cylindrical means that the object resembles a cylinder, but can have one or more deviations from a true cylinder.
The term “radially” means substantially in a direction along a radius of the object, or having a directional component in a direction along a radius of the object, even if the object is not exactly circular or cylindrical. The term “axially” means substantially along a direction of the axis of the object.
Disclosed herein is an actuatable valve tool which facilities accessing wells under pressure allowing or preventing inflow of wellbore fluids into a well pipe. The well pipe can be coil tubing, jointed pipe, or a combination thereof. The actuatable valve tool can include a tubular housing forming an axial flowbore. A slidable flow tube can be disposed within the housing and have the axial flowbore therethrough. A shear sleeve can be disposed around at least a portion of the slidable flow tube. The shear sleeve can be disposed around the entire slidable flow tube, or can be a longitudinally extending shearable coupling, such as a shear rod. One or more valves can be disposed within the housing, each having an open position and a closed position. In the open position the one or more valves permit fluid flow within the axial flowbore, and in the closed position the one or more valves block fluid flow therethrough. The slidable flow tube can be moveable within the housing to transition the one or more valves between the closed position and open position.
The shear sleeve allows for separation of the slidable flow tube and retrieval of a portion of the actuatable valve tool along with the work string in response to an emergency condition. For example, the tool may become stuck or other issue arise requiring removal of the string. In the emergency procedure, a ball having a cross section equal to or slightly larger than the axial flowbore is dropped into the wellpipe, which flows to position within the axial flowbore to restrict flow therethrough. While the emergency procedure is described herein with reference to a ball, other shaped objects or darts capable of blocking the axial flowbore, including but not limited to tear-drop shapes and elliptical shapes, can be used without altering the scope of this disclosure.
As the pressure builds on the ball, the slidable flow tube is shifted and a shear process can occur. The shear sleeve can have two shear points. A first shear point allows separation of the slidable flow tube into the first portion and the second portion. A second shear point causes at least a portion of the shear sleeve to block one or more vent ports within the tubular housing while allowing the second portion of the slidable flow tube to transition downhole of one or more valves while remaining within the actuatable valve tool. The actuatable valve tool can be removed from the wellbore, and the shear sleeve can be replaced to recouple the slidable flow tube first portion and second portion. The actuatable valve tool can be repaired and returned downhole within the wellbore.
Referring now to FIG. 1, an environmental view of an operating system 100 for an actuatable valve tool 102 is illustrated. The operating system 100 can be a wellbore servicing system employing the actuatable valve tool 102. The operating system 100 can include a wellbore 104 that penetrates into a subterranean formation 106 for the purpose of recovering hydrocarbons, storing hydrocarbons, disposing of carbon dioxide, or the like. The wellbore 104 can be drilled into the subterranean formation 106 using any suitable drilling technique known in the art. A rig 108 can be can be disposed at the surface 110 and include a derrick 112 with a floor 114 through which a work string 116. The work string 116 can be a drill string, a tool string, a segmented tubing string, a jointed tubing string, or any other suitable conveyance, or combinations thereof.
The wellbore 104 can extend substantially vertical away from the surface, but can also deviate at any angle. The wellbore 104 can have a vertical portion 118 along with a horizontal portion 120. The wellbore 104 can have one or more vertical portions 118 and one or more horizontal portions over the length of the wellbore 104. The wellbore 104 can be lined with a casing 122 that is secured in position against the subterranean formation 106. The wellbore 104 can be partially cased, such as including the casing 122 only in a vertical portion 118, horizontal portion 120, or any combination thereof. At least a portion of the wellbore 104 can be uncased and employ one or more packers, such as mechanical and/or swellable packers, to isolate two or more adjacent portions of the wellbore 104.
It should be noted that while FIG. 1 generally depicts a land-based operation, those skilled in the art will readily recognize that the principles described herein are equally applicable to subsea operations that employ floating or sea-based platforms and rigs, without departing from the scope of the disclosure.
As can be appreciated in FIG. 1, the operating system 100 includes the work string 116 having actuatable valve tool 102 disposed within the wellbore 104. The work string 116 also includes a wellbore servicing tool 124 downhole from the actuatable valve tool 102. The wellbore servicing tool 124 can be proximate and/or substantially adjacent to one or more zones of the subterranean formation 106. The wellbore servicing tool 124 can be a hydrajetting tool for creating fractures in the subterranean formation 106. The operating system 100 also has an annulus 126 formed between the outer wall of the actuatable valve tool 102 and the inner well of the casing 122.
FIG. 2 illustrates a cross section view of an example embodiment of an actuatable valve tool 102 in a first position. The actuatable valve tool 102 includes a tubular housing 128 having an axial flowbore 130. The tubular housing 128 has a slidable flow tube 132 disposed therein. The slidable flow tube 132 is moveable within the tubular housing 128 between a plurality of positions. The slidable flow tube 132 extends at least a portion of the length of the tubular housing 128 and has a generally cylindrical shape with a slightly smaller cross section to be received within the tubular housing 128. The slidable flow tube 132 can include a carbide material insert 137 and proximate the uphole end to protect from operating environmental conditions, such as high velocity and turbulent flow due to the reduced flow area in the axial flowbore.
The axial flowbore 130 extends through the slidable flow tube 132. The actuatable valve tool 102 has one or more O-rings 133 disposed between the outer surface of the slidable flow tube 132 and the inner surface of the tubular housing 128 to seal the axial flowbore. As can be appreciated in FIG. 2, the actuatable valve tool 102 has four O-rings 133, two disposed at an upper portion of the slidable flow tube 132 and two disposed at a lower portion of the slidable flow tube 132.
The tubular housing 128 has a biasing element 134 coupled with the slidable flow tube 132 to resist and/or assist movement of the slidable flow tube 132 within the tubular housing 128. The biasing element 134 can be a spring disposed around the slidable flow tube 132 and within the tubular housing 128. The O-rings 133 prevent fluid or particulate from entering the annulus 135 between the tubular housing 128 and the slidable flow tube 132 where the biasing element resides. In some instances, the biasing element has a compression strength of approximately 1,000 pounds per square inch (psi). In other instances, the biasing element 134 has a compression strength between 200 psi and 5,000 psi.
The actuatable valve tool 102 has one or more valves 136 within the tubular housing 128. The one or more valves 136 each have an open position and a closed position. The open position permits fluid flow within the axial flowbore 130 in the downhole direction. The closed position blocking fluid flow within the axial flowbore 130 in the uphole (reverse) direction. Each valve 136 has a flapper 138 to block the axial flowbore 130 and reverse fluid flow therethrough. The flapper 138 is coupled at an outer edge of the valve 136 and is positioned to pivot downhole. In other embodiments, each valve 136 can have more than one flapper 138, such as a two flappers each covering substantially half the valve 136. The flapper 138 can be biased by a spring or other biasing element to a closed position covering the one or more valves 136.
Although the actuatable valve tool 102 is illustrated as having two valves 136, one or more valves 136 can be implemented within the actuatable valve tool 102, such as one valve, three valves, four valves, or any other number of valves. Increasing the quantity of valves generally increases the length of the work string.
The tubular housing 128 also has one or more ports 139 therethrough coupling the exterior of the tubular housing with the annulus 135. The one or more ports 139 allow the expulsion, or intake, of air or fluid from the annulus 135 of the tubular housing 128 as the slidable flow tube 132 transitions between positions. The fluid communication provided by the one or more ports 139 assist in the transition of the slidable flow tube 132 between positions.
The actuatable valve tool 102 is transitionable between a plurality of positions by the application, or removal, of a pressure differential between the axial flowbore 130 and the annulus 126 formed between the tubular housing 128 and the wellbore casing 122 (shown in FIG. 1). The transition between positions is guided by an indexing sleeve 140. In some instances, the indexing sleeve 140 can be a J-slot as described below with respect to FIG. 13. The actuatable valve tool 102 is illustrated in a first position in FIG. 2. In the first position, the slidable flow tube 132 is positioned uphole from the one or more valves 136 and the biasing element 134 is substantially uncompressed. The one or more valves 136 are in the closed position. In some instances of the first position, the one or more valves 136 of the actuatable valve tool 102 can be in the open position when a flow in a first direction through the axial flowbore 130 is present, and the pressure differential between the annulus 135 of tubular housing 128 and the slidable flow tube 132 is less than the compression strength of the biasing element 134.
FIG. 3 illustrates an actuatable valve tool 102 in a second position. The slidable flow tube 132 is transitioned to a second position by an application of a pressure differential. The pressure differential can be generated by a flow of fluid, or gas, downhole through the axial flowbore 130 causing the slidable flow tube 132 to transition downhole within the actuatable valve tool 102 compressing the biasing element 134. The second position may be a fully extended position, in which case it can be referred to as a “fully stroked” or “fully indexed” position. In transitioning to this position, the slidable flow tube 132 moves downhole within the tubular housing 128 and extends through the one or more valves 136. The one or more valves 136 are in the open position with at least a portion of the slidable flow tube 132 extending therethrough. The slidable flow tube 132 extending through the one or more valves 136 protects the valves from fluid flow pumped downhole and through the actuatable valve tool 102. In some instances, an abrasive, such as sand, is pumped through the actuatable valve tool 102 that can damage the one or more valves 136. The second position provides the slidable flow tube 132 extending beyond the one or more valves 136 thereby protecting the one or more valves 136 from any material passing through the axial flowbore 130. The actuatable valve tool 102 remains in the second position until release of the pressure differential, upon which causes the biasing element 134 to transition the actuatable valve tool 102 to a third position.
FIG. 4 illustrates an example embodiment of an actuatable valve tool 102 in a third position. The actuatable valve tool 102 is transitioned from the second position (shown in FIG. 3) to the third position by releasing of the pressure differential. The pressure differential can be released by stopping or decreasing the downhole flow of fluid, or gas, through the axial flowbore 130. The actuatable valve tool 102 is secured in the third position by the indexing sleeve 140, such that the slidable flow tube 132 permits reverse fluid flow. As the actuatable valve tool 102 transitions from the second position to the third position, the slidable flow tube 132 travels uphole relative to the tubular housing 128, though still extends beyond the one or more valves 136.
In the third position, the actuatable valve tool 102 permits flow within the axial flowbore 130 downhole (a first direction) and uphole (a second direction). Flow in the second direction can be referred to as “reverse flow”. Flow in the second direction can occur at any flow rate or pressure differential within the build parameters of the actuatable valve tool 102. Flow in the first direction can be limited to below the pressure differential required to actuate the biasing element 134. Flow in the first direction creating a pressure differential exceeding the pressure differential required to actuate the biasing element 134 compresses the biasing element 134 and transitions the actuatable valve tool 102 to a fourth position.
FIG. 5 illustrates an example embodiment of an actuatable valve tool 102 in a fourth position. The fourth position can be substantially similar to the second position (e.g. fully stroked), such that the slidable flow tube 132 transitions downhole relative to the third position. The actuatable valve tool 102 remains in the fourth position until release of the pressure differential, upon which the biasing element 134 can assist in transitioning the actuatable valve tool to a fifth position.
FIG. 6 illustrates an example embodiment of an actuatable valve tool 102 in a fifth position. The fifth position can be substantially similar to the first position. The slidable flow tube 132 moves uphole relative to the fourth position. In the fifth position, the slidable flow tube 132 does not extend through the one or more valves 136, and flow in the axial flowbore 130 is permitted only in a first direction. The one or more valves 136 are not protected by the slidable flow tube 132 in the fifth position, and flow within the axial flowbore 130 that exceeds the pressure differential will return the actuatable valve tool 102 to the second position.
FIG. 7 illustrates an example embodiment of an actuatable valve tool 102 during an emergency removal procedure. The actuatable valve tool 102 includes a shear sleeve 142 disposed around at least a portion of the slidable flow tube 132. During an emergency removal procedure, also known as a “trip out”, a ball 158 having a cross section substantially similar to the slidable flow tube 132 is placed within the axial flowbore 130 of the actuatable valve tool 102. The ball 158 lodges within the slidable flow tube 132 and blocks flow therethrough allowing a downhole flow through the axial flowbore 130 to increase pressure within the actuatable valve tool 102.
FIG. 8 illustrates an enlarged view of section A-A of the example embodiment of the actuatable valve tool of FIG. 7. The shear sleeve 142 couples a first flow tube portion 144 and a second flow tube portion 146 of the slidable flow tube 132. The shear sleeve 142 has three portions, an uphole portion 148, a middle portion 150, a downhole portion 152. The uphole portion 148 is coupled to the middle portion 150 at first shear section 154. The first shear section 154 can be a thinned portion of the shear sleeve 142 designed to separate at a first predetermined pressure. The downhole portion 152 is coupled to the middle portion 150 at a second shear section 156. The second shear section 156 can be a thinned portion of the shear sleeve 142 designed to separate at a second predetermined pressure. The first and second predetermined pressures exert a downhole (longitudinal) force on the shear sleeve 142 coupling the first flow tube portion 144 and second flow tube portion 146. The downhole force caused by the predetermined pressures can exceed the material strength of the first and second shear sections 154, 156. The thickness and material of the first and second shear sections 154, 156 can be adjusted to achieve a specific first and second predetermined pressure. The first predetermined pressure can be approximately 3000-4500 psi and is lower than the second predetermined pressure which can be approximately 5000-7000 psi. The first and second predetermined pressures can vary depending on desired application and use, and can be more or less than the above stated ranges. The first and second shear sections 154, 156 can be different materials from the shear sleeve 142 having lower shear strengths.
FIG. 9 illustrates an example embodiment of an actuatable valve tool 102 during an emergency removal procedure having the first flow tube portion 144 separated from the second flow tube portion 146 of slidable flow tube 132. The first shear section 154 of the shear sleeve 142 shears at the first specific pressure separating the first flow tube portion 144 from the second flow tube portion 146 of the slidable flow tube 132. The second flow tube portion 146 of the slidable flow tube 132 extends downhole through the one or more valves 136, thus transitioning the one or more valves 136 to the open position.
FIG. 10 illustrates an enlarged view of section B-B of an example embodiment of an actuatable valve tool 102. At the first predetermined pressure, the first shear section 154 shears thereby separating the first flow tube portion 144 and second flow tube portion 146 of the slidable flow tube 132. The first flow tube portion 144 remains uphole relative to the second flow tube portion 146 and is biased uphole by the biasing element 134. The pressure imposed on the lodged ball 158 shifts the second flow tube portion 146 and the downhole portion 152 of the shear sleeve 142 downhole until the middle portion 150 abuts a protrusion 160 extending from the inner surface of the tubular housing 128.
The protrusion 160 is positioned along the length of the tubular housing 128 to engage and abut the middle portion 150 of the shear sleeve 142 such that the middle portion 150 covers the one or more ports 139 in the tubular housing 128. The protrusion 160 restricts movement of the shear sleeve 142 downhole causing pressure within the second flow tube portion 146 of the slidable flow tube 132 to increase. The middle portion 150 at the first shear section 154 further engages a locking mechanism 161 to prevent uphole motion of the shear sleeve 142 and second portion of the slidable flow tube 132. The locking mechanism 161 can be plurality of inwardly extending fingers 163 allowing the shear sleeve 142 to pass through and move downhole, but prevent uphole hole motion by abutting the middle portion 150.
FIG. 11 illustrates an example embodiment of an actuatable valve tool 102 during an emergency removal procedure having the second shear section 156 sheared from the middle portion 150. The first flow tube portion 144 of the slidable flow tube 132 is moved uphole by the biasing element 134 and the second flow tube portion 146 of the slidable flow tube 132 is moved downhole of the one or more valves 136. The tubular housing 128 has a length sufficient to house the second flow tube portion 146 downhole of the one or more valves 136, while providing sufficient room for the flapper 138 to operate and transition the valves from the open position to the closed position.
FIG. 12 illustrates an enlarged view of section C-C of an example embodiment of an actuatable valve tool 102. As can be appreciated in FIG. 12, upon shearing of the second shear section 156, the middle portion 150 remains covering the one or more ports 139 and the one or more valves 136 are in the closed position. The second flow tube portion 146 remains within the tubular housing 128 and downhole of the one or more valves 136. The emergency removal procedure is completed upon shearing of the second shear section 156 and the actuatable tool valve 102 (shown in FIG. 11) can be removed or POOH (pulled-out-of-hole) from the wellbore 104. A plurality of vents 165 can be provided downhole of the one or more valves 136 allowing communication between the tubular housing 128 and the annulus 126 of the tubular housing 128. The plurality of vents 165 can confirm separating of the second shear section 156 to a surface operation/operator by indicating a drop in tubing pressure. Upon separation of the second shear section 156, the tubing pressure will be vented into the annulus 126 indicating the operation is complete and the tool is ready to POOH.
The actuatable valve tool 102 is repairable such that a new shear sleeve can be inserted into the tubular housing 128 recoupling the first flow tube portion 144 and the second flow tube portion 146, thus allowing reinsertion (run-in-hole) into the wellbore 104.
FIG. 13 illustrates an example embodiment of an indexing sleeve 140. The indexing sleeve 140 is a J-slot type sleeve. The indexing sleeve 140 can be coupled with the slidable flow tube 132 and have one or more grooves 162 formed on the outer surface to transition the actuatable valve tool 102 (shown in FIGS. 2-6) between the first position, second position, third position, fourth position, and fifth position. The tubular housing 128 can engage the grooves 162 of the indexing sleeve 140 thereby causing slidable flow tube 132 to transition between the various positions. As the slidable flow tube 132 (shown in FIGS. 2-6) moves between positions within the tubular housing 128, the grooves 162 formed in indexing sleeve 140 cause slidable flow tube 132 to rotate. The indexing sleeve 140 allows the slidable flow tube 132 to fixed in the third position such that the actuatable valve tool 102 allows flow in the first direction and the second direction.
Referring to FIG. 14, a flowchart is presented in accordance with an example embodiment. The example method 1400 is provided by way of example, as there are a variety of ways to carry out the method 1400. The method 1400 described below can be carried out using the configurations illustrated in FIGS. 1-13, for example, and various elements of these figures are referenced in explaining example method 1400. Each block shown in FIG. 14 represents one or more processes, methods or subroutines, carried out in the example method 1400. Furthermore, the illustrated order of blocks is illustrative only and the order of the blocks can change according to the present disclosure. Additional blocks may be added or fewer blocks may be utilized, without departing from this disclosure. The example method 900 can begin at block 1402.
At block 1402, an actuatable valve tool 102 is provided in a first position and has a tubular housing 128, a slidable flow tube 132, and one or more valves 136. The actuatable valve tool 102 can transition between various positions with the slidable flow tube 132 moving within the tubular housing 128.
At block 1404, a pressure differential is generated transitioning the actuatable valve tool 102 from the first position to a second position. In the second position, the slidable flow tube 132 slides downhole extending through the one or more valves 136. The pressure differential is the hydrostatic pressure compared with the well pressure and must be sufficient to compress a biasing element 134. The pressure differential is caused by a flow through the actuatable valve tool 102 in a first direction. In the second position, flow through the actuatable valve tool 102 is only permitted in the first direction.
At block 1406, the pressure differential is released, thereby transitioning the actuatable valve tool 102 from the second position to a third position. The third position allows flow through the actuatable valve tool 102 in the first direction and a second direction substantially opposite the first direction. The second direction can be referred to as “reverse flow”. In the third position, the slidable flow tube 132 extends beyond the one or more valves 136, but is uphole relative to the second position.
At block 1408, a pressure differential is generated transitioning the actuatable valve tool 102 from the third position to a fourth position. The fourth position is substantially similar to the second position. The slidable flow tube 132 extends further downhole relative to the third position and beyond the one or more valves 136. Flow is permitted only in the first direction.
At block 1410, the pressure differential is released transitioning the actuatable valve tool 102 to a fifth position. The fifth position is substantially similar to the first position. The slidable flow tube is uphole relative to the fourth position and does not extend through the one or more valves 136. Flow is permitted in the first direction so long as the generated pressure does not exceed the pressure differential, if the pressure differential is reached the actuatable valve tool 102 returns to the second position.
At block 1412, a ball 158 is disposed within the axial flowbore 130 of the actuatable valve tool 102. The ball 158 blocks flow therethrough increasing pressure within the axial flowbore 130.
At block 1414, a pressure is generated by flow through the axial flowbore 130 and impeded by the ball 158. A shear sleeve 142 disposed at least a portion of the slidable flow tube 132 shears at a first shear section 154 causing the slidable flow tube 132 to become a two pieces a first flow tube portion 144 and a second flow tube portion 146. The first flow tube portion 144 is moved uphole by the biasing element 134, and the second flow tube portion 146 is moved downhole by the generated pressure.
At block 1416, a second shear section 156 shears by the increased pressure generated. A middle portion 150 of the shear sleeve 142 remains covering one or more ports 139, and the second flow tube portion 146 of the slidable flow tube 132 transitions within the actuatable valve tool 102 downhole past the one or more valves 136.
At block 1418, the flow is stopped causing the one or more valves 136 transition to the closed position. The second flow tube portion 146 of the slidable flow tube 132 is downhole of the closed one or more valves 136, and the first flow tube portion 144 is uphole of the closed one or move valves 136. The actuatable valve tool 102 can then be removed from the wellbore 104.
The embodiments shown and described above are only examples. Even though numerous characteristics and advantages of the present technology have been set forth in the foregoing description, together with details of the structure and function of the present disclosure, the disclosure is illustrative only, and changes may be made in the detail, including in matters of shape, size and arrangement of the parts within the principles of the present disclosure up to, and including, the full extent established by the broad general meaning of the terms used in the claims.

Statements of the Disclosure Include:

Statement 1: An actuatable valve tool comprising a tubular housing having an axial flowbore, a slidable flow tube disposed within the housing and having the axial flowbore therethrough, a shear sleeve disposed around at least a portion of the slidable flow tube, and one or more valves disposed within the housing, each having an open position and a closed position, wherein in in the open position the one or more valves permit fluid flow within the axial flowbore, and in the closed position the one or more valves block fluid flow therethrough, and wherein the slidable flow tube is moveable within the housing to transition the one or more valves between the closed position and the open position.
Statement 2: The actuatable valve tool of Statement 1, wherein the slidable flow tube is moveable from a first position to a second position by a pressure differential, in the first position the one or more valves are in the closed position and in the second position the one or more valves are in the open position, thereby allowing fluid flow in a first direction.
Statement 3: The actuatable valve tool of Statement 2, wherein the pressure differential is formed between the axial flowbore and an annulus between the tubular housing and the slidable flow tube.
Statement 4: The actuatable valve tool of Statement 2, wherein the slidable flow tube is moveable to a third position, the third position having the slidable flow tube fixed relative to housing with one more valves in the open position such that the flowbore allows fluid flow in the first direction and a second direction opposite the first direction.
Statement 5: The actuatable valve tool of any one of the preceding Statements 2-4, wherein the slidable flow tube is moveable from the first position to the second position by application of a pressure differential and the slidable flow tube is movable to the third position by releasing of the pressure differential.
Statement 6: The actuatable valve tool of any one of the preceding Statements 4-5, wherein the slidable flow tube is moveable to a fourth position by the application of a pressure differential, and upon release of the pressure differential the slidable flow tube returns to the first position.
Statement 7: The actuatable valve tool of any one of the preceding Statements 1-6, wherein an indexing sleeve is coupled with the slidable flow tube and configured to allow the slidable flow tube to move between a first position, a second position, a third position, and a fourth position.
Statement 8: The actuatable valve tool of Statement 7, wherein the indexing sleeve is a J-slot.
Statement 9: The actuatable valve tool of any one of the preceding Statements 1-8, wherein the slidable flow tube includes a first flow tube portion and a second flow tube portion coupled together by the shear sleeve, the sections separable when the shear sleeve is sheared.
Statement 10: The actuatable valve tool of Statement 9, wherein the shear sleeve has two shear sections, a first shear section adjacent the first flow tube portion of the slidable flow tube, and a second shear section adjacent the second flow tube portion of the slidable flow tube.
Statement 11: The actuatable valve tool of Statement 10, wherein the first shear section is configured to shear at a first pressure differential and the second shear section is configured to shear at a second pressure differential, the second pressure differential higher than the first pressure differential.
Statement 12: The actuatable valve tool of Statement 10, wherein the shear sleeve has a middle portion disposed between the first shear section and the second shear section.
Statement 13: The actuatable valve tool of Statement 12, wherein the tubular housing has a plurality of ports and the middle portion covers the plurality of ports upon shearing of the first shear section.
Statement 14: The actuatable valve tool of Statement 11, wherein shearing of the first shear section decouples the first flow tube portion of the slidable flow tube and the second flow tube portion of the slidable flow tube.
Statement 15: A wellbore servicing system comprising a work string, and an actuatable valve tool comprising a tubular housing having an axial flowbore, a slidable flow tube disposed within the housing, a shear sleeve disposed around at least a portion of the slidable flow tube, one or more valves disposed within the housing, each having an open position and a closed position, wherein in in the open position the one or more valves permit fluid flow within the axial flowbore, and in the closed position the one or more valves block fluid flow therethrough, wherein the slidable flow tube is moveable within the housing to transition the one or more valves between the closed position and the open position.
Statement 16: The wellbore servicing system of Statement 15, wherein the slidable flow tube is moveable from a first position to a second position by a pressure differential, in the first position the one or more valves are in the closed position and in the second position the one or more valves are in the open position, thereby allowing fluid flow in a first direction.
Statement 17: The wellbore servicing system of any one of the preceding Statements 15-16, wherein the slidable flow tube includes a first flow tube portion and a second flow tube portion coupled together by the shear sleeve, the sections separable when the shear sleeve is sheared.
Statement 18: The wellbore servicing system of Statement 17, wherein the shear sleeve has two shear sections, a first shear section adjacent the first flow tube portion of the slidable flow tube, and a second shear section adjacent the second flow tube portion of the slidable flow tube.
Statement 19: The wellbore servicing system of Statement 18, wherein the first shear section is configured to shear at a first pressure differential and the second shear section is configured to shear at a second pressure differential, the second pressure differential higher than the first pressure differential.
Statement 20: The wellbore servicing system of any one of preceding Statements 17-19, wherein the tubular housing has a plurality of ports and the middle portion covers the plurality of ports upon shearing of the first shear section and the shear sleeve has a middle portion disposed between the first shear section and the second shear section configured to cover the plurality of vents.
Statement 21: The actuatable valve tool of Statement 1, wherein at least a portion of the slidable flow tube comprises a carbide material insert.
Statement 22: The actuatable valve tool of Statement 9, wherein the first portion further comprises a slidable the carbide metal insert.
Statement 23: The actuatable valve tool of any one of the preceding Statements 10-11, wherein a locking mechanism is provided to lock the shear sleeve in place once the first shear section has separated.
Statement 24: The actutable valve tool of any one of the preceding Statements 1-14, wherein a plurality of vents are provided to communicate between the tubular housing and the annulus of the tubular housing downhole of the one or more valves.
Statement 25: The actuatable valve tool of Statement 24, wherein the plurality of vents reduce tubing pressure upon separation of the second shear section.
Statement 26: A method of wellbore servicing comprising generating a pressure differential within an actuatable valve tool having a tubular housing having one or more valves and a slidable flow tube capable of transitioning from a first position to a second position upon the application of a pressure differential; transitioning the actuatable valve tool to a third position up release of the pressure differential; transitioning the actuatable valve tool to a fourth position upon application of the pressure differential; and transitioning to a fifth position upon release of the pressure differential; wherein the actuatable valve tool has an indexing sleeve to transition the slidable flow tube between positions.
Statement 27: The method of wellbore servicing of Statement 26, further comprising dropping a ball within an axial flowbore of the actuatable valve tool to impede flow through the axial flowbore.
Statement 28: The method of wellbore servicing of Statement 27, further comprising generating a flow into the axial flowbore and impeded by the ball, thereby increasing pressure and shearing a first shear section of a shear sleeve disposed around the slidable flow tube.
Statement 29: The method of wellbore servicing of Statement 28, further comprising increasing the pressure within the axial flowbore thereby shearing a second shear section of the shear sleeve.
Statement 30: The method of wellbore servicing of Statement 29, further comprising stopping the flow into the axial flowbore allowing the one or more valves to close and returning the actuatable valve tool to surface.
Statement 31: A method comprising disposing an actuatable valve tool within a wellbore, the actuatable valve tool having a tubular housing having an axial flowbore and one or more valves. The one or more valves transitionable between an open position and a closed position, the open position permitting fluid flow through the axial flowbore, and the closed position blocking flow through the axial flow bore. A slidable flow tube disposed within the housing and slidable between a first position and second position to transition the one or more valves between the open position and closed positions. The slidable flow tube having a first flow tube portion and a second flow tube portion, and a shear sleeve disposed about the slidable flow tube and joining the first flow tube portion and a second flow tube portion. Shearing the shear sleeve disposed about the slidable flow tube and separating the first portion and the second portion of the slidable flow tube.
Statement 32: The method of Statement 32 further comprising dropping a ball within the axial flowbore of the actuatable valve tool to impede flow through the axial flowbore, thereby increasing pressure and shearing the shear sleeve.
Statement 33: The method of any of the preceding Statements 31-32, wherein the shearing occurs in response to generating a first pressure differential in the actuatable valve tool.
Statement 34: The method of Statement 33, further comprising generating a second pressure differential higher than the first pressure differential within the actuatable valve tool thereby shearing a second shear section of the shear sleeve.
Statement 35: The method of any of the proceeding Statements 31-34, wherein the tubular housing has one or more ports to the exterior of the tubular housing, and upon shearing the second section of the shear sleeve, a middle portion of the shear sleeve blocks the one or more ports.

Claims

1. An actuatable valve tool comprising:

a tubular housing having an axial flowbore;

a slidable flow tube disposed within the housing and having the axial flowbore therethrough;

a shear sleeve disposed around at least a portion of the slidable flow tube;

one or more valves disposed within the housing, each having an open position and a closed position;

wherein in the open position the one or more valves permit fluid flow within the axial flowbore, and in the closed position the one or more valves block fluid flow therethrough;

wherein the slidable flow tube is moveable within the housing to transition the one or more valves between the closed position and the open position.

2. The actuatable valve tool of claim 1, wherein the slidable flow tube is moveable from a first position to a second position by a pressure differential, in the first position the one or more valves are in the closed position and in the second position the one or more valves are in the open position, thereby allowing fluid flow in a first direction.

3. The actuatable valve tool of claim 2, wherein the pressure differential is formed between the axial flowbore and an annulus between the tubular housing and the slidable flow tube.

4. The actuatable valve tool of claim 2, wherein the slidable flow tube is moveable to a third position, the third position having the slidable flow tube fixed relative to housing with one more valves in the open position such that the flowbore allows fluid flow in the first direction and a second direction opposite the first direction.

5. The actuatable valve tool of claim 4, wherein the slidable flow tube is moveable from the first position to the second position by application of a pressure differential and the slidable flow tube is movable to the third position by releasing of the pressure differential.

6. The actuatable valve tool of claim 5, wherein the slidable flow tube is moveable to a fourth position by the application of a pressure differential, and upon release of the pressure differential the slidable flow tube returns to the first position.

7. The actuatable valve tool of claim 1, wherein an indexing sleeve is coupled with the slidable flow tube and configured to allow the slidable flow tube to move between a first position, a second position, a third position, and a fourth position.

8. The actuatable valve tool of claim 7, wherein the indexing sleeve is a J-slot.

9. The actuatable valve tool of claim 1, wherein the slidable flow tube includes a first flow tube portion and a second flow tube portion coupled together by the shear sleeve, the portions separable when the shear sleeve is sheared.

10. The actuatable valve tool of claim 9, wherein the shear sleeve has two shear sections, a first shear section adjacent the first flow tube portion of the slidable flow tube, and a second shear section adjacent the second flow tube portion of the slidable flow tube.

11. The actuatable valve tool of claim 10, wherein the first shear section is configured to shear at a first pressure differential and the second shear section is configured to shear at a second pressure differential, the second pressure differential higher than the first pressure differential.

12. The actuatable valve tool of claim 10, wherein the shear sleeve has a middle portion disposed between the first shear section and the second shear section.

13. The actuatable valve tool of claim 12, wherein the tubular housing has a plurality of ports and the middle portion covers the plurality of ports upon shearing of the first shear section.

14. The actuatable valve tool of claim 11, wherein shearing of the first shear section decouples the first flow tube portion of the slidable flow tube and the second flow tube portion of the slidable flow tube.

15. A wellbore servicing system comprising:

a work string coupled with an actuatable valve tool; and

the actuatable valve tool comprising:

a tubular housing having an axial flowbore;

a slidable flow tube disposed within the housing;

a shear sleeve disposed around at least a portion of the slidable flow tube;

16. The wellbore servicing system of claim 15, wherein the slidable flow tube is moveable from a first position to a second position by a pressure differential, in the first position the one or more valves are in the closed position and in the second position the one or more valves are in the open position, thereby allowing fluid flow in a first direction.

17. The wellbore servicing system of claim 15, wherein the slidable flow tube includes a first flow tube portion and a second flow tube portion coupled together by the shear sleeve, the sections separable when the shear sleeve is sheared.

18. The wellbore servicing system of claim 17, wherein the shear sleeve has two shear sections, a first shear section adjacent the first flow tube portion of the slidable flow tube, and a second shear section adjacent the second flow tube portion of the slidable flow tube.

19. The wellbore servicing system of claim 18, wherein the first shear section is configured to shear at a first pressure differential and the second shear section is configured to shear at a second pressure differential, the second pressure differential higher than the first pressure differential.

20. The wellbore servicing system of claim 17, wherein the tubular housing has a plurality of ports and the middle portion covers the plurality of ports upon shearing of the first shear section and the shear sleeve has a middle portion disposed between the first shear section and the second shear section configured to cover the plurality of vents.

21. A method comprising:

disposing an actuatable valve tool within a wellbore, the actuatable valve tool having

a tubular housing having an axial flowbore and one or more valves, the one or more valves transitionable between an open position and a closed position, the open position permitting fluid flow through the axial flowbore, and the closed position blocking flow through the axial flow bore,

a slidable flow tube disposed within the housing and slidable between a first position and second position to transition the one or more valves between the open position and closed positions, the slidable flow tube having a first flow tube portion and a second flow tube portion, and

a shear sleeve disposed about the slidable flow tube and joining the first flow tube portion and a second flow tube portion; and

shearing the shear sleeve disposed about the slidable flow tube and separating the first portion and the second portion of the slidable flow tube.

22. The method of claim 21 further comprising dropping a ball within the axial flowbore of the actuatable valve tool to impede flow through the axial flowbore, thereby increasing pressure and shearing the shear sleeve.

23. The method of claim 21, wherein the shearing occurs in response to generating a first pressure differential in the actuatable valve tool.

24. The method of claim 23, further comprising generating a second pressure differential higher than the first pressure differential within the actuatable valve tool thereby shearing a second shear section of the shear sleeve.

25. The method of claim 24, wherein the tubular housing has one or more ports to the exterior of the tubular housing, and upon shearing the second section of the shear sleeve, a middle portion of the shear sleeve blocks the one or more ports.