Patent Application
20140144642
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Hydrocarbon-producing wells often are stimulated by hydraulic fracturing operations, during which a servicing fluid such as a fracturing fluid or a perforating fluid may be introduced into a portion of a subterranean formation penetrated by a wellbore at a hydraulic pressure sufficient to create or enhance at least one fracture therein. Such a subterranean formation stimulation treatment may increase hydrocarbon production from the well.
A work string (e.g., tool string, coiled tubing string, and/or segmented tool string) is often used to communicate fluid to and from the subterranean formation, for example, during a wellbore stimulation (e.g., a hydraulic fracturing) operation. For example, jointed tubing may be used to form at least a portion of the work string. Additionally or alternatively, coiled tubing may also be used to form at least a portion of the work string.
Sometimes, during the performance of a wellbore servicing operation, it may be desirable to fluidicly isolate two or more sections of the work string (e.g. between a coiled tubing string and a jointed tubing string), for example, so as to close off fluid communication through the work string flowbore in at least one direction. For example, closing off fluid communication through a work string flowbore may allow, as an example, for the isolation of well pressure within the work string flowbore during run-in and/or run-out of a work string (e.g., facilitating connection and/or disconnection of one or more work string sections, such as a jointed tubing section and a coiled tubing section, two or more sections of jointed tubing, or combinations thereof). As such, there is a need for apparatuses, system, and methods of selectively allowing and/or preventing fluid communication through the flowbore of a workstring during the performance of a wellbore servicing operation.
Disclosed herein is a wellbore servicing system comprising a work string, and an actuatable valve tool defining an axial flowbore and incorporated within the work string, wherein the actuatable valve tool is transitionable from a first mode to a second mode, from the second mode to a third mode, and from the third mode to a fourth mode, wherein the actuatable valve tool is configured to transition from the first mode to the second mode upon an application of pressure to the axial flowbore of at least a threshold pressure, wherein the actuatable valve tool is configured to transition from the second mode to the third mode upon a dissipation of pressure from the axial flowbore to not more than the threshold pressure, wherein, in the first mode, the actuatable valve tool is configured to allow fluid communication via the axial flowbore in a first direction and to disallow fluid communication via the axial flowbore in a second direction, and wherein, in the second, and third modes, the actuatable valve tool is configured to allow fluid communication via the axial flowbore in both the first direction and the second direction.
Also disclosed herein is a wellbore servicing method comprising disposing a wellbore servicing system comprising an actuatable valve tool in a wellbore, the actuatable valve tool generally defining an axial flowbore, wherein the actuatable valve tool is configured in a first mode, wherein in the first mode, the actuatable valve tool allows downward fluid communication via the axial flowbore and disallows upward fluid communication via the axial flowbore, making a first application of fluid pressure of at least a pressure threshold to the axial flowbore, wherein the first application of fluid pressure transitions the actuatable valve tool to a second mode in which the actuatable valve tool allows both upward and downward fluid communication, allowing a first dissipation of fluid pressure applied to the axial flowbore to less than the pressure threshold, wherein allowing the first dissipation of fluid pressure transitions the actuatable valve tool to a third mode in which the actuatable valve tool allows both upward and downward fluid communication, making a second application of fluid pressure of at least the pressure threshold to the axial flowbore, wherein the second application of fluid pressure transitions the actuatable valve tool to a fourth mode in which the actuatable valve tool allows both upward and downward fluid communication, allowing a second dissipation of fluid pressure applied to the axial flowbore to less than the pressure threshold, wherein allowing the fluid pressure applied to the axial flowbore to dissipate transitions the actuatable valve tool to the first mode.
Further disclosed herein is a wellbore servicing method comprising disposing a wellbore servicing system in a wellbore, the wellbore servicing system comprising a actuatable valve tool generally defining an axial flowbore, wherein during disposing the wellbore servicing system within the wellbore, the actuatable valve tool is configured so as to allow downward fluid communication via the axial flowbore and to disallow upward fluid communication via the axial flowbore, reconfiguring the actuatable valve tool so as to allow downward and upward fluid communication via the axial flowbore, wherein reconfiguring the actuatable valve tool comprises applying a fluid pressure of at least a pressure threshold to the axial flowbore, allowing a fluid pressure applied to the axial flowbore to dissipate to less than the pressure threshold, or combinations thereof, reconfiguring the actuatable valve tool so as to allow downward fluid communication via the axial flowbore and to disallow upward fluid communication via the axial flowbore, wherein reconfiguring the actuatable valve tool comprises applying a fluid pressure of at least a pressure threshold to the axial flowbore, allowing a fluid pressure applied to the axial flowbore to dissipate to less than the pressure threshold, or combinations thereof, and repositioning the wellbore servicing system.
Further disclosed herein is an actuatable valve tool comprising a housing defining the axial flowbore, a flapper valve, wherein, when the flapper valve is in an activated state, the flapper valve is free to move between a closed position in which the flapper valve blocks the axial flowbore and an open position in which the flapper valve does not block the axial flowbore, and wherein, when the flapper valve is in an inactivated state, the flapper valve is retained in the open position, a sliding sleeve, wherein, in a first position, the sliding sleeve does not interact with the flapper valve, and wherein, in a second position and a third position, the sliding sleeve retains the flapper valve in the open position, and a transition system configured to control the longitudinal movement of the sliding sleeve, wherein the transition system comprises a j-slot, and a lug, wherein the lug is disposed within a least a portion of the j-slot.
For a more complete understanding of the present disclosure and the advantages thereof, reference is now made to the following brief description, taken in connection with the accompanying drawings and detailed description:
In the drawings and description that follow, like parts are typically marked throughout the specification and drawings with the same reference numerals, respectively. In addition, similar reference numerals may refer to similar components in different embodiments disclosed herein. The drawing figures are not necessarily to scale. Certain features of the invention may be shown exaggerated in scale or in somewhat schematic form and some details of conventional elements may not be shown in the interest of clarity and conciseness. The present invention is susceptible to embodiments of different forms. Specific embodiments are described in detail and are shown in the drawings, with the understanding that the present disclosure is not intended to limit the invention to the embodiments illustrated and described herein. It is to be fully recognized that the different teachings of the embodiments discussed herein may be employed separately or in any suitable combination to produce desired results.
Unless otherwise specified, use of the terms “connect,” “engage,” “couple,” “attach,” or any other like term describing an interaction between elements is not meant to limit the interaction to direct interaction between the elements and may also include indirect interaction between the elements described.
Unless otherwise specified, use of the terms “up,” “upper,” “upward,” “up-hole,” “upstream,” or other like terms shall be construed as generally from the formation toward the surface or toward the surface of a body of water; likewise, use of “down,” “lower,” “downward,” “down-hole,” “downstream,” or other like terms shall be construed as generally into the formation away from the surface or away from the surface of a body of water, regardless of the wellbore orientation. Use of any one or more of the foregoing terms shall not be construed as denoting positions along a perfectly vertical axis.
Unless otherwise specified, use of the term “subterranean formation” shall be construed as encompassing both areas below exposed earth and areas below earth covered by water such as ocean or fresh water.
Disclosed herein are embodiments of wellbore servicing apparatuses, systems and methods of using the same. Particularly disclosed herein are one or more embodiments of an actuatable valve tool (AVT), systems, and methods utilizing the same. In one or more of the embodiments as will be disclosed herein, the AVT may be generally configured to transition through one or more configurations and/or phases so as to selectively allow and/or disallow fluid communication through a tubular string (e.g., a work string) in one or both directions, for example, during the performance of a wellbore servicing operation (e.g., a subterranean formation stimulation operation).
Referring to
The wellbore 114 may extend substantially vertically away from the earth's surface over a vertical wellbore portion, or may deviate at any angle from the earth's surface 104 over a deviated or horizontal wellbore portion 118. In alternative operating environments, portions or substantially all of wellbore 114 may be vertical, deviated, horizontal, and/or curved and such wellbore may be cased, uncased, or combinations thereof. In some instances, at least a portion of the wellbore 114 may be lined with a casing 120 that is secured into position against the formation 102 in a conventional manner using cement 122. In this embodiment, the deviated wellbore portion 118 includes casing 120. However, in alternative operating environments, the wellbore 114 may be partially cased and cemented thereby resulting in a portion of the wellbore 114 being uncased. In an embodiment, a portion of wellbore 114 may remain uncemented, but may employ one or more packers (e.g., mechanical and/or swellable packers, such as Swellpackers™, commercially available from Halliburton Energy Services, Inc.) to isolate two or more adjacent portions or zones within wellbore 114. It is noted that although some of the figures may exemplify a horizontal or vertical wellbore, the principles of the apparatuses, systems, and methods disclosed may be similarly applicable to horizontal wellbore configurations, conventional vertical wellbore configurations, and combinations thereof. Therefore, the horizontal or vertical nature of any figure is not to be construed as limiting the wellbore to any particular configuration.
Referring to
The wellbore servicing tool 150 may be generally configured to deliver a wellbore servicing fluid to the wellbore 114, the subterranean formation 102 and/or one or more zones thereof, for example, for the performance of one or more servicing operations. For example, the wellbore servicing tool 150 may generally comprise a stimulation tool (such as a fracturing, perforating tool, and/or acidizing tool), a drilling tool (such as a drill bit), a wellbore cleanout tool, or combinations thereof. While this disclosure may refer to a wellbore servicing tool 150 configured for a stimulation operation (e.g., a perforating and/or fracturing tool), as disclosed herein, a wellbore servicing tool incorporated with the wellbore servicing system may be configured for various additional or alternative operations and, as such, this disclosure should not be construed as limited to utilization in any particular wellbore servicing context unless so-designated. In an embodiment, the wellbore servicing tool 150 may be selectively actuatable, for example, being configured to provide or not provide a route of fluid communication from the wellbore servicing tool 150 to the wellbore 114, the subterranean formation 102, and/or a zone thereof. In such an embodiment, the wellbore servicing tool 150 may be configured for actuation via the application of fluid pressure to the wellbore servicing tool 150, via the operation of a ball or dart, via the operation of a shifting tool (e.g., a wireline tool), or combinations thereof, as will be appreciated by one of skill in the art upon viewing this application. Although the embodiment of
In the embodiment of
Additionally, although the embodiment of
In one or more of the embodiments disclosed herein, one or more AVTs 200 may be configured to be activated while disposed within a wellbore like wellbore 114. In an embodiment, a valve tool 200 may be transitionable from a “first” mode or configuration to a “second” mode or configuration, from the “second” mode or configuration to a “third” mode or configuration, and from the “third” mode or configuration to a “fourth” mode or configuration. Further, in an embodiment, the AVT 200 may be configured so as to be transitionable from the “fourth mode or configuration back to the “first” mode or configuration. Further still, in an embodiment, the AVT 200 may be transitionable through such a sequence (e.g., first, second, third, then fourth mode) an unlimited number of iterations/cycles, as will be disclosed herein.
Referring to
Referring to
Referring to
Referring to
Once the AVT 200 has been returned to the first mode, in an embodiment, as will be disclosed herein, the AVT 200 may be configured so as to again be transitioned (cycled) from the first mode to the fourth mode as disclosed herein.
Referring to
While an embodiment of the AVT 200 is disclosed with respect to
In an embodiment, the housing 51 may be characterized as a generally tubular body having a first terminal end 51a (e.g., an uphole end) and a second terminal end 51b (e.g., a downhole end). The housing 51 may also be characterized as generally defining a longitudinal, axial flowbore 52. In an embodiment, the housing 51 may be configured for connection to and/or incorporation within a string, such as the work string 112. For example, the housing 51 may comprise a suitable means of connection to the work string 112 (such as the jointed tubing 20 and/or the coiled tubing 80 as illustrated in
In an embodiment, the one or more valves 53 may be generally configured, when activated, as will be disclosed herein, to close and/or seal the longitudinal bore 52 through the AVT 200 to fluid communication therethrough in at least one direction and to allow fluid communication in the opposite direction. In an embodiment, the one or more valves 53 may be characterized as one-way or unidirectional valve, that is, configured to allow fluid communication therethrough in only a single direction (e.g., when activated). For example, in an embodiment, the one or more valves 53 may comprise flapper valves. In such an embodiment, each of the activatable flapper valves may comprise a flap or disk movably (e.g., rotatably) secured within the housing 51 (e.g., directly or indirectly) via a hinge. For example, the flapper may be hinged to the housing 51, alternatively, to a body which may be disposed within the housing 51. In an embodiment, the flapper may be rotatable about the hinge from a first, closed position in which the flapper extends into the longitudinal bore 52 to a second, open position in which the flapper does not extend into the longitudinal bore 52. In an embodiment, the flapper may be biased, for example, biased toward the first, closed position via the operation of any suitable biasing means or member, such as a spring-loaded hinge. In an embodiment, when the flapper is in the second position, the flapper may be retained within a recess within the longitudinal bore of the housing 51, such as a depression (alternatively, a groove, cut-out, chamber, hollow, or the like). Also, when the flapper is in the first position, the flapper may protrude into the longitudinal bore 52, for example, so as to sealingly engage or rest against a portion of the housing 51 (alternatively, so as to engage a shoulder, a mating seat, the like, or combinations thereof). The flapper may be round, elliptical, or any other suitable shape.
In an embodiment, as will be disclosed herein, the one or more valves 53 may be activated and/or inactivated through an interaction with the movement of the sleeve 55. As used herein, reference to the one or more valves 53 as being in an “activated” state may mean that the one or more valves 53 are free to move between the first, closed position and the second, open position. Also, as used herein, reference to the one or more valves 53 as being in an “inactivated” state may mean that the one or more valves 53 are not free to move between the first, closed position and the second, open position. For example, in an embodiment as will be disclosed herein,
While the embodiments of
In an embodiment, the sleeve 55 generally comprises a cylindrical or tubular structure. In an embodiment, for example, in the embodiment of
In an embodiment, the relative longitudinal position of the sleeve 55 may determine if the one or more valves are in an activated state or an inactivated state. For example, when the sleeve 55 is located in the first position, the one or more valves may be in the activated state; alternatively, when the sleeve is located in the second and third positions, the one or more valves may be in the inactivated state. For example, as shown in
In an embodiment, the sleeve 55 may be longitudinally biased. For example, the sleeve 55 may be generally upwardly biased, for example, such that the sleeve 55 will experience a force sufficient to move the sleeve 55 in the upward direction (e.g., toward the first terminal end 51a) if otherwise uninhibited from such movement. For example, the sleeve 55 may be upwardly, longitudinally biased by the biasing member 57.
In an embodiment, the biasing member 57 generally comprises a suitable structure or combination of structures configured to apply a directional force and/or pressure to sleeve 55 with respect to the housing 51. Examples of suitable biasing members include a spring, a compressible fluid or gas contained within a suitable chamber, an elastomeric composition, a hydraulic piston, or the like. For example, in the embodiment of
The biasing member 57 may be configured to apply an axial force to sleeve 55 with respect to the housing 51. For example, in the embodiment of
In such an embodiment, the biasing member 57 may be generally disposed within an annular cavity 60 which may be cooperatively defined by the housing 51 and the sleeve 55. For example, in the embodiment of
In an embodiment, sleeve 55 may be configured so as to be selectively moved downwardly, for example, against the biasing force applied by the biasing member 57. For example, in an embodiment, the sleeve 55 may be configured such that the application of a fluid and/or hydraulic pressure (e.g., a hydraulic pressure exceeding a threshold pressure) to the axial flowbore 52 thereof will cause sleeve 55 to move in the downward direction (e.g., toward the second terminal end 51b). For example, in such an embodiment, sleeve 55 may be configured such that the application of fluid pressure of at least the threshold pressure to axial flowbore 52 (e.g., via, the flowbore 126) results in a net hydraulic force applied to sleeve 55 in the axially downward direction (e.g., in the direction towards the second terminal end 51b). In such an embodiment, the force applied to sleeve 55 as a result of the application of such a fluid/hydraulic pressure to the AVT 200 may be greater in the axial direction toward the second terminal end 51b (e.g., downward forces) than the sum of any forces applied in the opposite axial direction, for example, in the axial direction toward the first terminal end 51a (e.g., upward forces).
For example, in an embodiment, the sleeve 55 may be configured so as to have a differential in the surface area of the downward-facing and upward-facing surfaces of the sleeve 55 which are exposed to the axial flowbore 52, for example, so as to result in a differential between the axially upward and axially downward forces upon the application of fluid/hydraulic pressure to the axial flowbore. For example, in an embodiment, one or more of the interfaces between the housing 51 and the sleeve 55 may be sealed, for example, so as to provide such a differential in the surface area of the downward-facing and upward-facing surfaces of the sleeve 55 which are exposed to the axial flowbore 52. In the embodiment of
In an additional or alternative embodiment, the sleeve 55 may be configured such that the movement of fluid through the axial flowbore 52 (e.g., downward movement of fluid exceeding a threshold flow rate) will cause sleeve 55 to move in the downward direction (e.g., toward the second terminal end 51b). For example, in such an embodiment, the sleeve 55 may be configured such that fluid movement through the sleeve 55 in a given direction (e.g., downwardly) will apply a force to the sleeve 55 in the direction of the movement. For example, not intending to be bound by theory, the sleeve 55 may experience a force as a result of the fluid movement therethrough resulting from the frictional interaction between the moving fluid and the sleeve 55. For example, in such an embodiment, the sleeve 55 may comprise at least one surface configured so as exhibit a relatively increased coefficient of fluid movement as to fluid moving therethrough; for example, the sleeve 55 (e.g., portions of the sleeve exposed to fluid flow) may be configured to exhibit a drag coefficient sufficient to cause the movement of fluid through the AVT 200 (e.g., through the sleeve 55) to exert a force against the sleeve 55 in generally the same direction as the fluid movement (e.g., in a downward direction). In such an embodiment, the sleeve 55 may comprise one or more features (e.g., physical features) configured to alter the drag coefficient as to a fluid moving therethrough, for example, a roughened surface, various, lips, shoulders, grooves, or other profiles, or combinations thereof. In an embodiment, the force exerted against the sleeve 55, upon the movement of a fluid therethrough at a flow rate of at least threshold flow rate (e.g., resulting in a net, downward force), may be sufficient to overcome the force applied by biasing member 57 (e.g., in the upward direction).
While one or more of the embodiments disclosed herein may refer to sleeve movement as a result of the application of a given fluid pressure and/or the communication of a fluid at a given rate, it is contemplated that a given AVT may be configured for movement via either of these, or by any other suitable method, apparatus, or system.
In an embodiment, the transition system 50 may be configured to guide the axial and/or rotational movement of the sleeve 55 relative to the housing 51. In an embodiment, the transition system 50 generally comprises a recess or slot 63 and one or more lugs 64, for example, a “J-slot,” a control groove, an indexing slot, or combinations thereof. In an embodiment, through the interaction between the slot 63 and the one or more lugs 64, the transition system 50 may be configured to guide the rotational and axial movement of sleeve 55, as will be disclosed herein. In an embodiment, recess or slot 63 may be disposed on the second outer cylindrical surface 54b of the sleeve 55 and, the lug 64 may extend inwardly from the first inner cylindrical surface 61a of the housing 51 (e.g., a pin disposed within a bore within the housing 51). In an alternative embodiment, a slot like slot 63 may be similarly disposed within the housing and may interact with a lug like lug 64 extending outwardly from the sleeve. In an embodiment, the slot 63 may be characterized as a continuous slot. For example, the slot 63 may comprise a continuous J-slot. As used herein, a continuous slot refers to a slot, such as a groove or depression having a depth beneath the outer surface 54 of the sleeve 55 and extending entirely about (i.e., 360 degrees) the circumference of sleeve 55, though not necessarily in a single straight path. For example, as will be discussed herein, a continuous J-slot refers to a design configured to receive one or more protrusions or lugs (e.g. lug 64) coupled to and/or integrated within a component (e.g., housing 51), so as to guide the axial and/or rotational movement of that component through the J-slot, for example due to the physical interaction between the lug and the upper and lower shoulders of the slot.
Referring to
In an embodiment, the slot 63 and lug 64 may be configured so as to interact to guide the sleeve 55, upon the application of various forces sufficient to move the sleeve 55 longitudinally being applied thereto (e.g., alternating downward and upward forces, as disclosed herein), from the first position to second position, from the second position to the third position, from the third position again to the second position, from the second position again to the first position, and then to repeat the cycle. For example, in an embodiment, the slot 63 and lug 64 may interact such that when the sleeve 55 is in the first position, the lug 64 may be generally disposed in one of the long lower notches 63f. In an embodiment, the slot 63 and lug 64 may also interact such that, upon the application of a downward force to the sleeve 55 sufficient to overcome upward forces applied to the sleeve 55, the lug 64 will move through the slot 63 from the long lower notch 63f to one of the upper notches 63d, for example, causing the sleeve 55 to move radially along with the downward movement thereof and, thereby, causing the sleeve 55 to arrive in the second position. Thereafter, upon relieving the downward force applied to the sleeve 55 such that the upward forces applied to the sleeve 55 overcome the downward forces applied thereto, the lug 64 will move through the slot 63 from the upper notch 63d to one of the short lower notches 63e, for example, causing the sleeve 55 to move radially along with the upward movement thereof and, thereby, causing the sleeve 55 to arrive in the third position. Thereafter, upon another application of a downward force to the sleeve 55 sufficient to overcome upward forces applied to the sleeve 55, the lug 64 will move through the slot 63 from the short lower notch 63e to another of the upper notches 63d, for example, causing the sleeve 55 to move radially along with the downward movement thereof and, thereby, causing the sleeve 55 to return to the second position. Thereafter, upon again relieving the downward force applied to the sleeve 55 such that the upward forces applied to the sleeve 55 overcome the downward forces applied thereto, the lug 64 will move through the slot 63 from the upper notch 63d to another of the long lower notches 63f, for example, causing the sleeve 55 to move radially along with the upward movement thereof and, thereby, causing the sleeve 55 to return to the first position. It is understood that the sleeve 55 is free to rotate within the housing 51, for example, so as to allow the lug 64 to cycle (e.g., move both radially and longitudinally) with respect to the slot 63.
As such, in an embodiment, AVT 200 may be configured to transition from the first mode to the second mode, from the second mode to the third mode, from the third mode to the fourth mode, and from the fourth mode back to the first mode (e.g., by alternatingly applying pressure to the AVT 200 and allowing the pressure applied to the AVT 200 to dissipate). In an embodiment, for example, where the slot 63 is a continuous slot, the AVT 200 may be cycled, as disclosed herein, an unlimited number of cycles.
One or more of embodiments of an AVT (e.g., such as AVT 200) and/or a wellbore servicing system (e.g., such as wellbore servicing system 100) comprising such an AVT 200 having been disclosed, one or more embodiments of a wellbore servicing method employing such a wellbore servicing system 100 and/or such an AVT 200 are also disclosed herein. In an embodiment, a wellbore servicing method may generally comprise the steps of positioning a work string (e.g., such as work string 112) having an AVT 200 incorporated therein within a wellbore (such as wellbore 114), communicating a fluid through the work string 112, and repositioning the work string 112. As will be disclosed herein, the AVT 200 may control fluid movement through the work string 112 during the wellbore servicing method. For example, as will be disclosed herein, during the step of positioning the work string 112 within the wellbore 114 and/or the step of repositioning the work string 112, the AVT 200 may be configured to prohibit fluid communication out of the wellbore 114 through the work string 112 (e.g., upward fluid communication through the work string 112). Also, for example, during the step of communicating the fluid through the work string 112, the AVT 200 may be configured to allow fluid communication through the work string 112 in both directions (e.g., upward and downward fluid communication) as will disclosed herein.
In an embodiment, the wellbore servicing method may further comprise re-positioning the work string 112 and, a second time, communicating a fluid through the work string 112, as will be disclosed herein.
In an embodiment, positioning the work string 112 comprising the AVT 200 may comprise forming and/or assembling the components of the work string 112, for example, as the work string 112 is run into the wellbore 114. For example, referring to the embodiment of
In an embodiment, the work string 112 may be run into the wellbore 114 with the AVT 200 configured in the first mode, for example, with the sleeve 55 in the first position as disclosed herein and as illustrated in the embodiment of
In an embodiment, the work string 112 may be run into the wellbore 114 to a desired depth. For example, the work string 112 may be run in such that the wellbore servicing tool 150 is positioned proximate to one or more desired subterranean formation zones to be treated (e.g., a first formation zone).
In an embodiment, communicating a fluid through the work string 112 may comprise communicating a fluid from the surface 104 (e.g., from a wellbore servicing equipment component located at the surface 104) through the work string 112 into the formation 102 (for example, forward circulating a fluid through the work string 112 and the AVT 200). In an embodiment, the fluid may be communicated (e.g., pumped, for example, via the operation of one or more wellbore servicing equipment components, such as one or more high-pressure pumps). In an embodiment, the fluid communicated (e.g., forward-circulated) through the work string 112 (e.g., and the AVT 200) may comprise a wellbore servicing fluid. Nonlimiting examples of a suitable wellbore servicing fluid include but are not limited to a fracturing fluid (such as a proppant-laden fluid, a foamed fluid, or the like), a perforating or hydrajetting fluid, an acidizing fluid, the like, or combinations thereof. The wellbore servicing fluid may be communicated at a suitable rate and pressure for a suitable duration. For example, the wellbore servicing fluid may be communicated at a rate and/or pressure sufficient to initiate or extend a fluid pathway (e.g., a perforation or fracture) within the subterranean formation 102 and/or a zone thereof. Additionally, in an embodiment, a second fluid (e.g., a component fluid) may be communicated into the wellbore 114 via a second flow path substantially contemporaneously with the communication of fluid through the work string 112. For example, the second flow path may comprise an annular space surrounding the work string 112. The contemporaneous communication via multiple flow paths is disclosed in U.S. application Ser. No. 13/442,411 to East, et al., which is disclosed herein by reference in its entirety.
In an embodiment, communicating a fluid through the work string 112, for example, forward circulating a fluid through the work string 112, may comprise transitioning the AVT 200 from the first, run-in mode to the second, fully-stroked mode. For example, in an embodiment forward-circulating the fluid (e.g., the wellbore servicing fluid) though the work string 112 (e.g., at a pressure and/or flow rate about a predetermined threshold) may apply a downward force to the sleeve 55 sufficient to overcome the upward forces applied thereto and cause the sleeve to transition from the first position (e.g., as shown in
For example, in an embodiment where the AVT 200 is activated by the communication of fluid therethrough (e.g., by pressure and/or flow rate), for example, in the embodiment of
In an embodiment, the fluid communicated through the work string 112 (e.g., through the AVT 200) may be characterized abrasive, corrosive, and/or erosive (for example, containing particulate material, such as sand). For example, in an embodiment as disclosed herein, the fluid may comprise a wellbore servicing fluid, for example a fracturing fluid comprising a proppant such as sand. In an embodiment, movement of the sleeve 55 to the second position, as disclosed herein, may protect and/or substantially protect one or more components of the AVT 200 from experiencing the potentially abrasive, corrosive, and/or erosive fluids communicated therethrough. For example, in the embodiment of
In an embodiment, when a desired amount of the servicing fluid has been communicated, for example, sufficient to create a perforation or fracture of a desired number or character, an operator may cease the communication of fluid (e.g., cease the downward communication of a wellbore servicing fluid), for example, by ceasing to pump the servicing fluid into work string 112.
In an embodiment, ceasing the communication of fluid (alternatively, decreasing the pressure at which the fluid is communicated, decreasing the rate at which the fluid is communicated, or combinations thereof) may comprise transitioning the AVT 200 from the second, fully-stroked mode to the third, reverse circulation mode. For example, in an embodiment ceasing the communication of fluid (alternatively, decreasing the pressure at which the fluid is communicated, decreasing the rate at which the fluid is communicated, or combinations thereof) may decrease the downward forces applied to the sleeve 55 such that the upward forces applied thereto (e.g., by the biasing member) overcome any such downward forces and cause the sleeve to transition from the second position (e.g., as shown in
For example, in an embodiment where the AVT 200 is activated by the communication of fluid therethrough (e.g., by pressure and/or flow rate), for example, in the embodiment of
Additionally or alternatively, communicating a fluid through the work string may comprise communicating a fluid through the work string 112 from the formation 102 and or the wellbore 114 through the work string 112 toward the surface 104 (for example, reverse-circulating a fluid through the work string). In an embodiment, for example, following the performance of a servicing operation with respect to a given zone of the subterranean formation, fluid (e.g., a wellbore servicing fluid, a formation fluid, such as water and/or hydrocarbons, or combinations thereof) may be reverse-circulated through the work string 112. In an embodiment, upon transitioning the AVT 200 to the third, reverse-circulation mode, a fluid may be reverse-circulated (communicated upward) through the work string 112 and/or the AVT 200. For example, when the AVT 200 is configured in the third mode, fluid may be communicated therethrough in either direction, for example, because the one or more valves 53 are retained in the inactivated (e.g., open) state, as disclosed herein.
Additionally, although the third circulation mode is called the reverse circulation mode, in an embodiment, fluid may be also communicated downward through the AVT 200 while the AVT 200 is maintained in the third mode (e.g., so long as such fluid is communicated at a pressure below the threshold fluid pressure and/or flow rate.
In an embodiment, repositioning the work string 112 may comprising positioning the work string 112 such that the wellbore servicing tool is positioned proximate to another formation zone (e.g., a second formation zone). In such embodiments, repositioning the work string may allow for such additional formation zones to be serviced. For example, the work string 112 may be run-in (e.g., deeper within the wellbore 114); alternatively, the work string 112 may be run out (e.g., shallower within the wellbore 114). In an alternative embodiment, repositioning the work string 112 may comprise removing the work string 112 from the wellbore 114.
In an embodiment, repositioning the work string 112 may comprise transitioning the AVT 200 from the third mode to the fourth mode and transitioning the AVT 200 from the fourth mode to the first mode, again.
For example, in an embodiment where the AVT 200 is activated by the communication of fluid therethrough (e.g., by pressure and/or flow rate), for example, in the embodiment of
In an embodiment, the AVT 200 may be maintained within the fourth, re-indexing mode for so long as the downward forces applied to sleeve 55 (e.g., as a result of the application of a fluid force to the sleeve 55) is sufficient to overcome the upward forces also applied to the sleeve 55 (e.g., by the biasing member 57). In an embodiment, a fluid may be communicated through the well string 112 (e.g., downwardly through the AVT 200) while the AVT 200 is maintained in the fourth mode. For example, in such an embodiment, a second wellbore servicing fluid (e.g., a fracturing fluid, an acidizing fluid, a clean-out fluid, the like, or combinations thereof) may be communicated downwardly through the well string 112 (e.g., downwardly through the AVT 200) while the AVT 200 is maintained in the fourth mode.
Also, in an embodiment where the AVT 200 is activated by the communication of fluid therethrough (e.g., by pressure and/or flow rate), for example, in the embodiment of
In an embodiment, and as similarly disclosed herein, the work string 112 may be repositioned within the wellbore 114 with the AVT 200 or removed from the wellbore while the AVT 200 is configured in the first mode, for example, with the sleeve 55 in the first position as disclosed herein and as shown in
In an embodiment, upon repositioning the work string 112 within the wellbore 114, the process of communicating a fluid through the work string 112 (e.g., so as to perform a wellbore servicing operation with respect to various formation zones), and repositioning the work string 112 may be repeated for so many cycles as may be desired. As such, in an embodiment, the AVT 200 may be cycled (e.g., for as many cycles as may be desired) from the first mode to the second mode (e.g., to allow forward circulation, if desired), from the second mode to the third mode (e.g., to allow reverse circulation, if desired), from the third mode to the fourth mode (e.g., to again allow forward circulation, if desired), and from the fourth mode back to the first mode (e.g., to block upward fluid communication, for example, during run-in, repositioning, and/or run-out).
One of skill in the art, upon viewing this disclosure, will appreciate that an AVT (like AVT 200) may be modified (e.g., via one or modifications to the “J-slot,” as disclosed herein) so as to transition between various modes (e.g., as disclosed herein) upon any suitable combination of alternatingly applying fluid force (e.g., pressure and/or flow rate above a threshold) to the AVT 200 and allowing the force applied to the AVT 200 to dissipate (e.g., decreasing the pressure and/or flow rate to less than a threshold), as disclosed herein. Similarly, an AVT may be modified so as to similarly have a fifth, sixth, seventh, eighth, ninth, or tenth mode.
In an embodiment, an AVT (like AVT 200), a system utilizing an AVT, and/or a method utilizing such an AVT and/or system a system may be advantageously employed in the performance of a wellbore servicing operation. For example, as disclosed herein, the AVT allows for an operator to selectively block fluid communication upwardly through a work string (or other tubular, wellbore string). As such, an AVT may be employed to improve safety in a wellbore/wellsite environment, for example, by providing a means of controlling the unintended escape of fluids/pressures from a wellbore (e.g., when the AVT is so-configured, as disclosed herein). Also, whereas conventional flapper-type valves are often unprotected from abrasive, corrosive, or erosive wellbore fluids during a wellbore servicing operation (e.g., during pumping a high-pressure or high flow-rate fluid), an AVT as disclosed herein will protect flapper valves therein, for example, thereby improving the reliability with which such components operate. Further still, an AVT as disclosed herein does not require that a signaling member (e.g., a ball, dart, or other tool) be run into the wellbore to transition the AVT between modes. As such, the AVT may be quickly and efficiently transitioned between various modes, as disclosed herein, via either increasing and/or decreasing the pressure applied thereto.
The following are nonlimiting, specific embodiments in accordance with the present disclosure:
A first embodiment, which is wellbore servicing system comprising:
a work string; and
an actuatable valve tool defining an axial flowbore and incorporated within the work string,
A second embodiment, which is the wellbore servicing system of the first embodiment, wherein the actuatable valve tool is transitionable from the fourth mode the first mode.
A third embodiment, which is the wellbore servicing system of the second embodiment,
A fourth embodiment, which is the wellbore servicing system of one of the first through the third embodiments, wherein the actuatable valve tool comprises:
A fifth embodiment, which is the wellbore servicing system of the fourth embodiment, wherein the sliding sleeve is movable from a first longitudinal position to a second position, from the second longitudinal position to a third longitudinal position.
A sixth embodiment, which is the wellbore servicing system of the fifth embodiment,
A seventh embodiment, which is the wellbore servicing system of one of fifth through the sixth embodiments, further comprising a transition system configured to control the longitudinal movement of the sliding sleeve.
An eighth embodiment, which is the wellbore servicing system of the seventh embodiment, wherein the transition system comprises:
A ninth embodiment, which is the wellbore servicing system of one of the fifth through the eighth embodiments, further comprising a biasing member, wherein the biasing member is configured to bias the sliding sleeve in the second direction.
A tenth embodiment, which is the wellbore servicing system of one of the fifth through the ninth embodiments, where the sliding sleeve comprises a differential between the surfaces exposed to the axial flowbore facing the first direction and the surfaces exposed to the axial flowbore facing the second direction.
An eleventh embodiment, which is the wellbore servicing system of one of the first through the tenth embodiments, wherein the work string comprises a coiled tubing segment, a jointed tubing segment, or combinations thereof.
A twelfth embodiment, which is the wellbore servicing system of one of the first through the eleventh embodiments, wherein the wellbore servicing system further comprises a wellbore servicing tool incorporated within the work string at a location downhole from the actuatable valve tool.
A thirteenth embodiment, which is a wellbore servicing method comprising:
disposing a wellbore servicing system comprising an actuatable valve tool in a wellbore, the actuatable valve tool generally defining an axial flowbore, wherein the actuatable valve tool is configured in a first mode, wherein in the first mode, the actuatable valve tool allows downward fluid communication via the axial flowbore and disallows upward fluid communication via the axial flowbore;
making a first application of fluid pressure of at least a pressure threshold to the axial flowbore, wherein the first application of fluid pressure transitions the actuatable valve tool to a second mode in which the actuatable valve tool allows both upward and downward fluid communication;
allowing a first dissipation of fluid pressure applied to the axial flowbore to less than the pressure threshold, wherein allowing the first dissipation of fluid pressure transitions the actuatable valve tool to a third mode in which the actuatable valve tool allows both upward and downward fluid communication;
making a second application of fluid pressure of at least the pressure threshold to the axial flowbore, wherein the second application of fluid pressure transitions the actuatable valve tool to a fourth mode in which the actuatable valve tool allows both upward and downward fluid communication;
allowing a second dissipation of fluid pressure applied to the axial flowbore to less than the pressure threshold, wherein allowing the fluid pressure applied to the axial flowbore to dissipate transitions the actuatable valve tool to the first mode.
A fourteenth embodiment, which is the wellbore servicing method of the thirteenth embodiment, wherein making the first application of fluid pressure comprises downwardly communicating a fluid via the axial flowbore.
A fifteenth embodiment, which is the wellbore servicing method of one of the thirteenth through the fourteenth embodiments, wherein allowing the first dissipation of fluid pressure comprises upwardly communicating a fluid via the axial flowbore.
A sixteenth embodiment, which is the wellbore servicing method of one of the thirteenth through the fifteenth embodiments, wherein making the second application of fluid pressure comprises downwardly communicating a fluid via the axial flowbore.
A seventeenth embodiment, which is the wellbore servicing method of one of the thirteenth through the sixteenth embodiments, wherein making the second application of fluid pressure comprises upwardly communicating a fluid via the axial flowbore.
An eighteenth embodiment, which is a wellbore servicing method comprising:
disposing a wellbore servicing system in a wellbore, the wellbore servicing system comprising a actuatable valve tool generally defining an axial flowbore, wherein during disposing the wellbore servicing system within the wellbore, the actuatable valve tool is configured so as to allow downward fluid communication via the axial flowbore and to disallow upward fluid communication via the axial flowbore;
reconfiguring the actuatable valve tool so as to allow downward and upward fluid communication via the axial flowbore, wherein reconfiguring the actuatable valve tool comprises applying a fluid pressure of at least a pressure threshold to the axial flowbore, allowing a fluid pressure applied to the axial flowbore to dissipate to less than the pressure threshold, or combinations thereof;
reconfiguring the actuatable valve tool so as to allow downward fluid communication via the axial flowbore and to disallow upward fluid communication via the axial flowbore, wherein reconfiguring the actuatable valve tool comprises applying a fluid pressure of at least a pressure threshold to the axial flowbore, allowing a fluid pressure applied to the axial flowbore to dissipate to less than the pressure threshold, or combinations thereof; and
repositioning the wellbore servicing system.
A nineteenth embodiment, which is the wellbore servicing method of the eighteenth embodiment, wherein reconfiguring the actuatable valve tool so as to allow downward and upward fluid communication via the axial flowbore comprises communicating a fluid downwardly via the axial flowbore.
A twentieth embodiment, which is the wellbore servicing method of the nineteenth embodiment, wherein the fluid is communicated into a subterranean formation zone at a rate and/or pressure sufficient to initiate and/or extend a perforation and/or fracture.
A twenty-first embodiment, which is the wellbore servicing method of the nineteenth embodiment, wherein the fluid is a perforating fluid, a hydrajetting fluid, a fracturing fluid, an acidizing fluid, or combinations thereof.
A twenty-second embodiment, which is the wellbore servicing method of one of the eighteenth through the twenty-first embodiments, further comprising communicating a fluid upwardly through the axial flowbore.
A twenty-third embodiment, which is the wellbore servicing method of one of the eighteenth through the twenty-second embodiments, wherein repositioning the wellbore servicing system comprises repositioning at least a portion of the wellbore servicing system within the wellbore.
A twenty-fourth embodiment, which is the wellbore servicing method of one of the eighteenth through the twenty-third embodiments, wherein repositioning the wellbore servicing system comprises removing the wellbore servicing system from the wellbore.
A twenty-fifth embodiment, which is an actuatable valve tool comprising:
A twenty-sixth embodiment, which is the actuatable valve tool of the twenty-fifth embodiment, wherein the transition system is configured to guide the sliding sleeve from the first position to the second position, from the second position to the third position, from the third position back to the second position, and from the second position back to the first position.
While embodiments of the invention have been shown and described, modifications thereof can be made by one skilled in the art without departing from the spirit and teachings of the invention. The embodiments described herein are exemplary only, and are not intended to be limiting. Many variations and modifications of the invention disclosed herein are possible and are within the scope of the invention. Where numerical ranges or limitations are expressly stated, such express ranges or limitations should be understood to include iterative ranges or limitations of like magnitude falling within the expressly stated ranges or limitations (e.g., from about 1 to about 10 includes, 2, 3, 4, etc.; greater than 0.10 includes 0.11, 0.12, 0.13, etc.). For example, whenever a numerical range with a lower limit, Rl, and an upper limit, Ru, is disclosed, any number falling within the range is specifically disclosed. In particular, the following numbers within the range are specifically disclosed: R=Rl+k*(Ru−Rl), wherein k is a variable ranging from 1 percent to 100 percent with a 1 percent increment, i.e., k is 1 percent, 2 percent, 3 percent, 4 percent, 5 percent, . . . 50 percent, 51 percent, 52 percent, . . . , 95 percent, 96 percent, 97 percent, 98 percent, 99 percent, or 100 percent. Moreover, any numerical range defined by two R numbers as defined in the above is also specifically disclosed. Use of the term “optionally” with respect to any element of a claim is intended to mean that the subject element is required, or alternatively, is not required. Both alternatives are intended to be within the scope of the claim. Use of broader terms such as comprises, includes, having, etc. should be understood to provide support for narrower terms such as consisting of, consisting essentially of, comprised substantially of, etc.
Accordingly, the scope of protection is not limited by the description set out above but is only limited by the claims which follow, that scope including all equivalents of the subject matter of the claims. Each and every claim is incorporated into the specification as an embodiment of the present invention. Thus, the claims are a further description and are an addition to the embodiments of the present invention. The discussion of a reference in the Detailed Description of the Embodiments is not an admission that it is prior art to the present invention, especially any reference that may have a publication date after the priority date of this application. The disclosures of all patents, patent applications, and publications cited herein are hereby incorporated by reference, to the extent that they provide exemplary, procedural or other details supplementary to those set forth herein.
