Patent Grant
9784070
The subject matter of this application is related to commonly owned U.S. patent application Ser. No. 12/539,392, published as US 2011/0036590 A1 and entitled “System and method for servicing a wellbore,” by Jimmie Robert Williamson, et al., filed Aug. 11, 2009. The subject matter of this application is also related to commonly owned U.S. patent application Ser. No. 13/025,041 entitled “System and method for servicing a wellbore,” by Porter, et al., filed Feb. 10, 2011. The subject matter of this application is also related to commonly owned U.S. patent application Ser. No. 13/025,039 entitled “A method for individually servicing a plurality of zones of a subterranean formation,” by Howell, filed Feb. 10, 2011. Each of these applications is incorporated by reference herein, in its entirety.
Not applicable.
Not applicable.
Hydrocarbon-producing wells often are stimulated by hydraulic fracturing operations, wherein a servicing fluid such as a fracturing fluid and/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 and/or extend at least one fracture therein. Such a subterranean formation stimulation treatment may increase hydrocarbon production from the well.
Subterranean formations that contain hydrocarbons are sometimes non-homogeneous in their composition along the length of wellbores that extend into such formations. It is sometimes desirable to treat and/or otherwise manage the differing formation zones differently. In order to adequately induce the formation of fractures within such zones, it may be advantageous to introduce a stimulation fluid simultaneously via multiple stimulation assemblies. To accomplish this, it is necessary to configure multiple stimulation assemblies for the simultaneous communication of fluid via those stimulation assemblies. However prior art apparatuses, systems, and methods have failed to provide a way in which to efficiently, effectively, and reliably so-configure multiple stimulation assemblies.
Accordingly, there exists a need for improved apparatuses, systems, and methods for treating multiple zones of a wellbore.
Disclosed herein is a wellbore servicing tool comprising a housing at least partially defining an axial flowbore, the housing comprising one or more ports, a sliding sleeve, the sliding sleeve being slidably positioned within the housing and transitionable from a first position in which the sliding prevents fluid communication via a route of fluid communication from the axial flowbore to an exterior of the housing via the one or more ports, to a second position in which the sliding sleeve allows fluid communication via the route of fluid communication from the axial flowbore to an exterior of the housing via the one or more ports, and a fluid delay system configured to retain the sliding sleeve in the first position until actuated and to allow the sliding sleeve to transition from the first position to the second position at a controlled rate when actuated, wherein the fluid delay system is actuatable via a wireless signal.
Also disclosed herein is a wellbore servicing method comprising positioning a wellbore servicing system within a wellbore penetrating a subterranean formation, the wellbore servicing system comprising a first wellbore servicing tool, the first wellbore servicing tool comprising a housing at least partially defining an axial flowbore, the housing comprising one or more ports, a sliding sleeve, the sliding sleeve being slidably positioned within the housing and transitionable from a first position in which the sliding sleeve obscures fluid communication via a route of fluid communication from the axial flowbore to an exterior of the housing via the one or more ports, to a second position in which the sliding allows fluid communication via the route of fluid communication from the axial flowbore to an exterior of the housing via the one or more ports, and a fluid delay system configured to retain the sliding sleeve in the first position until actuated and to allow the sliding sleeve to transition from the first position to the second position at a controlled rate when actuated, communicating a first wireless signal to the fluid delay system of the first wellbore servicing tool, wherein receipt of the first wireless signal by the fluid delay system of the first wellbore servicing tool is effective to actuate the fluid delay system of the first wellbore servicing tool, and communicating a wellbore servicing fluid to a first zone of the subterranean formation via the one or more ports of the first wellbore servicing tool.
Further disclosed herein is a wellbore servicing method comprising positioning a wellbore servicing system within a wellbore penetrating a subterranean formation, the wellbore servicing system comprising a first wellbore servicing tool, the first wellbore servicing tool being configured in a first mode and transitionable from the first mode to a second mode and from the second mode to a third mode, the first wellbore servicing tool comprising a housing at least partially defining an axial flowbore, the housing comprising one or more ports, a sliding sleeve, the sliding sleeve being slidably positioned within the housing, and a fluid delay system, communicating a first wireless signal to the fluid delay system of the first wellbore servicing tool, wherein receipt of the first wireless signal by the fluid delay system of the first wellbore servicing tool is effective to transition the first wellbore servicing tool from the first mode to the second mode, allowing the first wellbore servicing tool to transition from the second mode to the third mode, and communicating a wellbore servicing fluid to a first zone of the subterranean formation via the one or more ports of the first wellbore servicing tool.
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. 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 of embodiments of an activatable stimulation assembly (ASA). Also disclosed herein are one or more embodiments of a wellbore servicing system comprising a one or more ASAs. Also disclosed herein are one or more embodiments of a method of servicing a wellbore employing an ASA and/or a system comprising one or more ASAs.
Referring to
As depicted in
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. In alternative operating environments, portions or substantially all of the wellbore 114 may be vertical, deviated, horizontal, and/or curved.
In the embodiment of
In the embodiment of
In the embodiment of
In an embodiment, each of the ASAs (cumulatively and non-specifically referred to as ASA 200 in the embodiment illustrated in
In one of more of the embodiments disclosed herein, the ASA may be transitionable from a “first” mode or configuration to a “second” mode or configuration and from the second mode or configuration to a “third” mode or configuration.
In an embodiment, when the ASA is in the first mode, also referred to as a “locked-deactivated,” “run-in,” or “installation,” mode or configuration, the ASA may be configured such that the sliding sleeve is retained in the first position by the delay system. As such, in the first mode, the ASA may be configured to not permit fluid communication via the ports. The locked-deactivated mode may be referred to as such, for example, because the sliding sleeve is selectively locked in position relative to the housing.
In an embodiment, when the ASA is in the second mode, also referred to as an “unlocked-deactivated,” or “delay” mode or configuration, the ASA may be configured such that relative movement between the sliding sleeve and the housing may be delayed insofar as (1) such relative movement occurs but occurs at a reduced and/or controlled rate, (2) such relative movement is delayed until the occurrence of a selected condition, or (3) combinations thereof. As such, in the second mode, the ASA may be configured to not permit and/or to not fully permit fluid communication via the ports. The unlocked-deactivated or delay mode may be referred to as such, for example, because the sliding sleeve is not locked relative to the housing, but the sliding sleeve is not in the second position, and thus the ASA remains deactivated, except as allowed by the fluid delay system.
In an embodiment, when the ASA is in the third mode, also referred to as an “activated” or “fully-open mode,” the ASA may be configured such that the sliding sleeve has transitioned to the second position. As such, in the third mode, the ASA may be configured to permit fluid communication via the ports.
At least two embodiments of an ASA are disclosed herein below. A first embodiment of such an ASA (e.g., ASA 200) is disclosed with respect to
In an embodiment, the housing 220/320 may be characterized as a generally tubular body defining an axial flowbore 221/321 having a longitudinal axis. The axial flowbore 221/321 may be in fluid communication with the axial flowbore 113 defined by the casing string 120. For example, a fluid communicated via the axial flowbore 113 of the work string 112 will flow into and the axial flowbore 221/321.
In an embodiment, the housing 220/320 may be configured for connection to and or incorporation within a casing string such as liner 118. For example, the housing 220/320 may comprise a suitable means of connection to the liner 118 (e.g., to a liner member such as a joint). For example, in an embodiment, the terminal ends of the housing 220/320 comprise one or more internally or externally threaded surfaces, as may be suitably employed in making a threaded connection to the liner 118. Alternatively, an ASA may be incorporated within a casing string (or, alternatively, any other suitable tubular string, such as a casing string or work string) by any suitable connection, such as, for example, via one or more quick-connector type connections. Suitable connections to a casing string member will be known to those of skill in the art viewing this disclosure.
In an embodiment, the housing 220/320 may comprise a unitary structure; alternatively, the housing 220/320 may be comprise two or more operably connected components (e.g., two or more coupled sub-components, such as by a threaded connection). Alternatively, a housing like housing 220/320 may comprise any suitable structure, such suitable structures will be appreciated by those of skill in the art with the aid of this disclosure.
In an embodiment, the housing 220/320 may comprise one or more ports (e.g., ports 225 in the embodiment of
In an embodiment, the housing 220/320 comprises a sliding sleeve recess. For example, in the embodiment of
In an embodiment, the sliding sleeve 240/340 generally comprises a cylindrical or tubular structure. In the embodiment of
In an embodiment, the sliding sleeve 240/340 may comprise a single component piece. In an alternative embodiment, a sliding sleeve like the sliding sleeve 240/340 may comprise two or more operably connected or coupled component pieces (e.g., a collar welded about a tubular sleeve).
In an embodiment, the sliding sleeve 240/340 may be slidably and concentrically positioned within the housing 220/320. In the embodiment of
In an embodiment, the sliding sleeve 240/340, the sliding sleeve recess 224/324, or both may comprise one or more seals at one or more of the interfaces between the sliding sleeve 240/340 and the recessed bore surface 224/324. In such an embodiment, the sliding sleeve 240/340 and/or the housing 220/320 may further comprise one or more radial or concentric recesses or grooves configured to receive one or more suitable fluid seals, for example, to restrict fluid movement via the interface between one or more surfaces of the sliding sleeve 240/340 and the sliding sleeve recess 224/324. For example, in the embodiment of
In an embodiment, a sliding sleeve may be configured to allow or disallow fluid communication between the axial flowbore 221 of the housing and the exterior of the housing, dependent upon the position of the sliding sleeve relative to the housing. For example, in the embodiment of
Additionally or alternatively, in an embodiment, a sliding sleeve comprises one or more ports suitable for the communication of fluid from the axial flowbore of the housing to an exterior of the housing when so-configured. For example, in the embodiment of
In an embodiment, the sliding sleeve 240/340 may be slidably movable between a first position and a second position with respect to the housing 220/320. Referring again to
In an embodiment, the sliding sleeve 240 and/or 340 may be held in the second position by suitable retaining mechanism. For example, in an embodiment, the sliding sleeve may be retained in the second position by a snap-ring, alternatively, by a C-ring, a biased pin, ratchet teeth, or combinations thereof. In such an embodiment, the snap-ring (or the like) may be carried in a suitable slot, groove, channel, bore, or recess in the sliding sleeve, alternatively, in the housing, and may expand into and be received by a suitable slot groove, channel, bore, or recess in the housing, or, alternatively, in the sliding sleeve.
In an embodiment, the sliding sleeve 240/340 may be configured to allow or disallow fluid communication between the axial flowbore 221/321 of the housing 220/320 and the exterior of the housing 220/320, dependent upon the position of the sliding sleeve 240/340 relative to the housing 220/320. For example, in the embodiment of
Additionally or alternatively, in the embodiment of
In an embodiment, the sliding sleeve 240/340 may be biased in the direction of the second position, for example, such that the sliding sleeve 240/340 will move in the direction of the second position if not otherwise retained and/or if not inhibited from such movement (for example, by the fluid delay system, as will be disclosed herein). For example, in the embodiment of
In an embodiment, the fluid delay system 260/360 generally comprises a fluid reservoir, an actuatable valve assembly (AVA), and a fluid selectively retained within the fluid reservoir by the AVA.
In the embodiment, the housing and the sliding sleeve may cooperatively define a fluid reservoir. For example, in the embodiment of
In an embodiment, the fluid reservoir may be characterized as having variable volume dependent upon the position of the sliding sleeve relative to the housing. For example, referring to
In an embodiment, the fluid chamber may be of any suitable size, as will be appreciated by one of skill in the art viewing this disclosure. For example, in an embodiment, a fluid chamber like fluid reservoir 262 or fluid reservoir 362 may be sized according to the position of the ASA of which it is a part in relation to one or more other, similar ASAs. For example, in an embodiment, the furthest uphole of ASA may comprise a fluid reservoir of a first volume (e.g., the relatively largest volume), the second furthest uphole ASA may comprise a fluid reservoir of a second volume (e.g., the second relatively largest volume), the third furthest uphole ASA may comprise a fluid reservoir of a third volume (e.g., the third relatively largest volume), etc. For example, the first volume may be greater than the second volume and the second volume may be greater than the third volume.
In an embodiment, the AVA generally comprises one or more devices, assemblies, or combinations thereof, configured to selectively allow the fluid either, to be retained or to escape from the fluid reservoir. Referring to
In an embodiment of
In an embodiment, the valve 265/365 may be selectively actuatable responsive to a signal. For example, in the embodiment of
In an additional embodiment, the AVA, the signal receiver 268/368, the valve 265/365, or combinations thereof, may further comprise a power source (e.g., a battery), a power generation device, or combinations thereof. In such an embodiment, the power source and/or power generation device may supply power to the AVA, the signal receiver 268/368, the valve 265/365, or combinations thereof, for example, for the purpose of operating the signal receiver 268/368, operating the valve 265/365, or combinations thereof. In an embodiment, such a power generation device may comprise a generator, such as a turbo-generator configured to convert fluid movement into electrical power; alternatively, a thermoelectric generator, which may be configured to convert differences in temperature into electrical power. In such embodiments, such a power generation device may be carried with, attached, incorporated within or otherwise suitable coupled to an ASA and/or a component thereof. Suitable power generation devices, such as a turbo-generator and a thermoelectric generator are disclosed in U.S. Pat. No. 8,162,050 to Roddy, et al., which is incorporated herein by reference in its entirety. An example of a power source and/or a power generation device is a Galvanic Cell. In an embodiment, the power source and/or power generation device may be sufficient to power actuation of the AVA, for example, in the range of from about 0.5 to about 10 watts, alternatively, from about 0.5 to about 1.0 watt.
In an embodiment, the AVA may be configured to allow the fluid to escape from the fluid reservoir 262/362 at a controlled and/or predetermined rate. For example, in the embodiment of
In an additional embodiment, an orifice like orifice 264/364 may be sized according to the position of the ASA of which it is a part in relation to one or more other similar orifices of other ASAs. For example, in an ASA cluster comprising multiple ASAs, the furthest uphole of these ASA may comprise an orifice sized to allow a first flow-rate (e.g., the relatively slowest flow-rate), the second furthest uphole ASA may comprise an orifice sized to allow a second flow-rate (e.g., the second relatively slowest flow-rate), the third furthest uphole ASA may comprise an orifice sized to allow a third flow-rate (e.g., the third relatively slowest flow-rate), etc. For example, the first flow-rate may be less than the second flow-rate and the second flow-rate may be less than the third flow-rate. In an embodiment, an orifice like orifice 264/364 may further comprise a fluid metering device received at least partially therein. In such an embodiment, the fluid metering device may comprise a fluid restrictor, for example a precision microhydraulics fluid restrictor or micro-dispensing valve of the type produced by The Lee Company of Westbrook, Conn. However, it will be appreciated that in alternative embodiments any other suitable fluid metering device may be used. For example, any suitable electro-fluid device may be used to selectively pump and/or restrict passage of fluid through the device (e.g., a micro-pump, configured to displace fluid from reservoir 262/362 to reduce the amount of fluid therein).
In an embodiment, the wellbore servicing system 100 further comprises a signaling member. In such an embodiment, the signaling member generally comprises any suitable device capable of sending, emitting, or returning a signal capable of being received by the signal receiver 268/368, as disclosed herein. In various embodiments, the signaling member may generally be characterized as an active signaling device, for example, a device to actively emits a given signal. Alternatively, the signaling member may generally be characterized as a passive signaling device, for example, a device that, by its presence, allows a signal to be evoked. For example, suitable signaling members may include, but are not limited to, radio-frequency identification (RFID) tags, radio transmitters, microelectromechanical systems (MEMS), a magnetic device, acoustic signal transmitting devices, radiation and/or radioactivity-emitters, magnetic or electromagnetic emitters, the like or combinations thereof. In various embodiments, the signaling member may be configured suitably for communication into a wellbore. For example, in an embodiment, a signaling member may be configured as a ball, a dart, a tag, a chip, or the like that may be conveyed (e.g., pumped) through the wellbore to a given ASA with which the signal receiver 268/368 is associated. As similarly noted above, the signaling member may comprise an interrogation unit, a communication unit, or combinations thereof.
In an embodiment, for example, referring again to
In an embodiment, the fluid reservoir 262/362 may be filled, substantially filled, or partially filled with a suitable fluid. In an embodiment, the fluid may be characterized as having a suitable rheology. In an embodiment, the fluid may be characterized as substantially incompressible. In an embodiment, the fluid may be characterized as having a suitable bulk modulus, for example, a relatively high bulk modulus. For example, in an embodiment, the fluid may be characterized as having a bulk modulus in the range of from about 1.8 105 psi, lbf/in2 to about 2.8 105 psi, lbf/in2 from about 1.9 105 psi, lbf/in2 to about 2.6 105 psi, lbf/in2, alternatively, from about 2.0 105 psi, lbf/in2 to about 2.4 105 psi, lbf/in2. In an additional embodiment, the fluid may be characterized as having a relatively low coefficient of thermal expansion. For example, in an embodiment, the fluid may be characterized as having a coefficient of thermal expansion in the range of from about 0.0004 cc/cc/° C. to about 0.0015 cc/cc/° C., alternatively, from about 0.0006 cc/cc/° C. to about 0.0013 cc/cc/° C., alternatively, from about 0.0007 cc/cc/° C. to about 0.0011 cc/cc/° C. In another additional embodiment, the fluid may be characterized as having a stable fluid viscosity across a relatively wide temperature range (e.g., a working range), for example, across a temperature range from about 50° F. to about 400° F., alternatively, from about 60° F. to about 350° F., alternatively, from about 70° F. to about 300° F. In another embodiment, the fluid may be characterized as having a viscosity in the range of from about 50 centistokes to about 500 centistokes. Examples of a suitable fluid include, but are not limited to oils, such as synthetic fluids, hydrocarbons, or combinations thereof. Particular examples of a suitable fluid include silicon oil, paraffin oil, petroleum-based oils, brake fluid (glycol-ether-based fluids, mineral-based oils, and/or silicon-based fluids), transmission fluid, synthetic fluids, or combinations thereof.
In an embodiment, the fluid delay system 260/360 may be effective to retain the sliding sleeve 240/340 in the first position and to allow movement of the sliding sleeve 240/340 from the first position to the second position at a controlled rate (e.g., over a desired period of time). For example, referring to
One or more embodiments of an ASA 200 and a wellbore servicing system 100 comprising one or more ASAs like ASA 200 or ASA 300 (e.g., ASAs 200A-200F) having been disclosed, one or more embodiments of a wellbore servicing method employing such a wellbore servicing system 100 and/or such an ASA 200/300 are also disclosed herein. In an embodiment, a wellbore servicing method may generally comprise the steps of positioning a wellbore servicing system comprising one or more ASAs within a wellbore such that each of the ASAs is proximate to a zone of a subterranean formation, optionally, isolating adjacent zones of the subterranean formation, transitioning the sliding sleeve within an ASA from its first position to its second position, and communicating a servicing fluid to the zone proximate to the ASA via the ASA.
In an embodiment, the process of transitioning a sliding sleeve within an ASA from its first position to its second position and communicating a servicing fluid to the zone proximate to the ASA via that ASA, as will be disclosed herein, may be performed, for as many ASAs as may be incorporated within the wellbore servicing system or some portion thereof.
In an embodiment, one or more ASAs may be incorporated within a work string or casing string, for example, like casing string 120, and may be positioned within a wellbore like wellbore 114. For example, in the embodiment of
In an embodiment, once the liner 118 comprising the ASAs (e.g., ASAs 200a-200c) has been positioned within the wellbore 114, adjacent zones may be isolated and/or the liner 118 may be secured within the formation. For example, in the embodiment of
In an embodiment, the zones of the subterranean formation (e.g., 2, 4, 6, 8, 10, and/or 12) may be serviced working from the zone that is furthest down-hole (e.g., in the embodiment of
In an embodiment where the wellbore is serviced working from the furthest down-hole formation zone progressively upward, once the liner (or other suitable string) comprising the ASAs has been positioned within the wellbore and, optionally, once adjacent zones of the subterranean formation (e.g., 2, 4, 6, 8, 10, and/or 12) have been isolated, the first ASA 200A may be prepared for the communication of a fluid to the proximate and/or adjacent zone. In such an embodiment, the sliding sleeve 240 or 340 within the ASA (e.g., ASA 200A) proximate and/or substantially adjacent to the first zone to be serviced (e.g., formation zone 2), is transitioned from its first position to its second position. In an embodiment, transitioning the sliding sleeve 240 or 340 within the ASA 200 or 300 to its second position may comprise introducing a signaling member (e.g., a ball or dart) configured to send a signal that ASA 200/300 (e.g., ASA 200A) into the liner 118 and forward-circulating (e.g., pumping) the signaling member into sufficient proximity with the ASA 200/300 (e.g., ASA 200A), particularly, the signal receiver 268/368 of the ASA 200/300 so as to cause the valve 265/365 to be actuated (e.g., opened). In an embodiment, the signaling member may be effective to actuate (e.g., open) the valve of only one of the ASAs (e.g., ASA 200A), for example, via a matching signal type or identifier between a given one or more ASAs and a given signaling member. In such an embodiment, the signaling member may be communicated via the axial flowbore of one or more other ASAs (e.g., ASAs 200B-200F) en route to the intended ASA (e.g., ASA 200A) without altering the mode or configuration of such other ASAs. In an alternative embodiment, the signaling member may be effective to actuate (e.g., open) the valve of multiple of the ASAs (e.g., ASA 200A and ASA 200B, or others). In such an embodiment, the signaling member may actuate (e.g., open) the valve of multiple ASAs when communicated via the axial flowbore of such ASAs.
In the embodiment of
As fluid escapes from the fluid reservoir 262/362, the sliding sleeve 240/340 is allowed to continue to move toward the second position. As such, the rate at which the sliding sleeve 240/340 may move from the first position to the second position is at least partially dependent upon the rate at which fluid is allowed to escape and/or dissipate from the fluid reservoir 262/362 via orifice 264/365. For example, because the rate at which the sliding sleeve transitions from the first position to the second position may be controlled, as disclosed herein, the time duration necessary to transition the from the first position to the second position may be varied.
For example, in an embodiment, the ASA 200A (e.g., like ASA 200 or ASA 300) may be configured such that the sliding sleeve 240/340 will transition from the first position to the second position at a rate such that the ports 225/325 remain obscured (e.g., from fluid communication) for a predetermined, desired amount of time (e.g., beginning upon being transitioned from the first mode or configuration to the second mode or configuration by actuation of the valve 265/365). For example, the duration of time may depend upon the rate at which the fluid is emitted from the fluid reservoir, the volume of fluid within the fluid reservoir, the volume of the fluid reservoir, the force applied to the fluid reservoir, or combinations thereof. In an embodiment, an ASA may be configured to fully transition to from the first mode to the third mode (e.g., the fully-open mode) within a predetermined, desired time range, for example, about 15 minutes, alternatively, about 30 minutes, alternatively about 45 minutes, alternatively, about 1 hour, alternatively, about 1.5 hours, alternatively, about 2 hours, alternatively, about 2.5 hours, alternatively, about 3 hours, alternatively, about 3.5 hours, alternatively, about 4 hours, alternatively, about 5 hours, alternatively, any other suitable duration of time. In an embodiment where multiple ASAs are transitioned from the first mode to the second mode by a common signaling member, the ASAs may be configured such that no ASA will transition from the second mode to the third mode until all ASAs intended to be transitioned from the first mode to the second mode by that signaling member have been transitioned from the first mode to the second mode.
For example, with reference to the embodiment of
In an embodiment, the ASAs may be configured to open so as to allow fluid access first to zone 2, then zone 4, then zone 6, then zone 8, the zone 10, and then zone 12. Alternatively, other orderings may also be possible, for example, 12-10-8-6-4-2; alternatively, 2-6-4-10-8-12; alternatively, 2-6-10-4-8-12; alternatively, 2-6-10-12-8-4; alternatively, 10-6-2-4-8-12; alternatively, 10-6-2-12-8-4; or portions or combinations thereof. In addition, as noted herein, two or more zones may be treated simultaneously and/or substantially simultaneously, for example, by configured two or more ASAs to allow fluid access to the formation simultaneously or substantially simultaneously. As disclosed herein, one or more of such orders may be achieved dependent upon whether a given ASA is transitioned from the first mode to the second mode by a given signaling member and/or dependent upon the duration necessary to transition an ASA from the second mode to the third mode. As may be appreciated by one of skill in the art upon viewing this disclosure, in an embodiment where it is desired to inhibit fluid communication to a zone that has previously been treated (e.g., stimulated, such as by fracturing), fluid communication may be inhibited (e.g., the zone may be isolated) by setting a mechanical plug (e.g., a fracturing or bridge plug) or a particulate plug (e.g., a sand plug, a proppant plug, and/or temporary plug, such as a degradable/dissolvable plug).
In an embodiment, the sliding sleeve 240/340 may continue to move in the direction of its second position until reaching the second position, thereby transitioning the ASA from the second mode into the third mode, as illustrated in the embodiments of
In an embodiment, when the first ASA 200A is configured for the communication of a servicing fluid, for example, when the first ASA 200A has transitioned to the fully-open mode, as disclosed herein, a suitable wellbore servicing fluid may be communicated to the first subterranean formation zone 2 via the unobscured ports 225/325 of the first ASA 200A. Nonlimiting examples of a suitable wellbore servicing fluid include but are not limited to a fracturing fluid, 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.
In an embodiment, when a desired amount of the servicing fluid has been communicated to the first formation zone 2, an operator may cease the communication of fluid to the first formation zone 2. Optionally, the treated zone may be isolated, for example, via a mechanical plug, sand plug, or the like, placed within the flowbore between two zones (e.g., between the first and second zones, 2 and 4). The process of transitioning a sliding sleeve within an ASA from its first position to its second position and communicating a servicing fluid to the zone proximate to the ASA via that ASA may be repeated with respect the second, third, fourth, fifth, and sixth ASAs, 200B, 200C, 200D, 200E, and 200F, respectively, and the formation zones 4, 6, 8, 10, and 12, associated therewith. Additionally, in an embodiment where additional zones are present, the process may be repeated for any one or more of the additional zones and the associated ASAs.
In an embodiment, an ASA such as ASA 200 or 300, a wellbore servicing system such as wellbore servicing system 100 comprising an ASA such as ASA 200/300, a wellbore servicing method employing such a wellbore servicing system 100 and/or such an ASA 200/300, or combinations thereof may be advantageously employed in the performance of a wellbore servicing operation. For example, conventional wellbore servicing tools have utilized ball seats, baffles, or similar structures configured to engage an obturating member (e.g., a ball or dart) in order to actuate such a servicing tool. In an embodiment, an ASA may be characterized as having no reductions in diameter, alternatively, substantially no reductions in diameter, of a flowbore extending therethrough. For example, an ASA, such as ASA 200 or ASA 300 may be characterized as having a flowbore (e.g., flowbore 221 or 321) having an internal diameter that, at no point, is substantially narrower than the flowbore of a tubing string in which that ASA is incorporated (e.g., the diameter of the axial flowbore 117 of the liner 118); alternatively, a diameter, at no point, that is less than 95% of the diameter of the tubing string; alternatively, not less than 90% of the diameter; alternatively, not less than 85% of the diameter; alternatively, not less than 80% of the diameter. However, such structures configured to receive and/or engage an obturating member are subject to failure by erosion and/or degradation due to exposure to servicing fluids (e.g., proppant-laden, fracturing fluids) and, thus, may fail to operate as intended. In the embodiments disclosed herein, no such structure is present. As such, the instantly disclosed ASAs are not subject to failure due to the inoperability of such a structure. Further, the absence of such structure allows improved fluid flow through the ASAs as disclosed herein, for example, because no such structures are present to impede fluid flow.
Further, in an embodiment, the ASAs as disclosed herein, may be actuated and utilized in any order desired by the operator. For example, as will be appreciated by one of skill in the art upon viewing this disclosure, whereas conventional servicing tools utilizing ball seats, baffles, or similar structures to actuate such wellbore servicing tools, thereby necessitating that a wellbore servicing operation be performed from the bottom, working upward (e.g., toe to heel), because the signaling members disclosed herein may be configured to actuate any one or more ASAs in substantially any suitable order. As such, the instantly disclosed ASAs may afford an operator the ability to simultaneously service two or more non-adjacent zones, or to service zones in almost any order, either of which would have been virtually impossible utilizing conventional wellbore servicing tools.
The following are nonlimiting, specific embodiments in accordance with the present disclosure:
A wellbore servicing tool comprising:
a housing at least partially defining an axial flowbore, the housing comprising one or more ports;
a sliding sleeve, the sliding sleeve being slidably positioned within the housing and transitionable from:
a fluid delay system configured to retain the sliding sleeve in the first position until actuated and to allow the sliding sleeve to transition from the first position to the second position at a controlled rate when actuated, wherein the fluid delay system is actuatable via a wireless signal.
The wellbore servicing tool of embodiment 1, wherein the wireless signal comprises a radio frequency, an RFID signal, a magnetic field, an acoustic signal, or combinations thereof.
The wellbore servicing tool of one of embodiments 1 through 2, wherein the wireless signal is unique to the wellbore servicing tool.
The wellbore servicing tool of one of embodiments 1 through 3, wherein the fluid delay system comprises an actuatable valve.
The wellbore servicing tool of one of embodiments 1 through 4, wherein the fluid delay system is configured to open the actuatable valve responsive to receipt of the wireless signal.
The wellbore servicing tool of one of embodiments 1 through 5, wherein the actuatable valve is in fluid communication with a fluid reservoir.
The wellbore servicing tool of one of embodiments 1 through 6, wherein the fluid delay system comprises a signal receiver.
The wellbore servicing tool of one of embodiments 1 through 7, wherein the housing has an about constant inner diameter.
A wellbore servicing method comprising:
positioning a wellbore servicing system within a wellbore penetrating a subterranean formation, the wellbore servicing system comprising a first wellbore servicing tool, the first wellbore servicing tool comprising:
communicating a first wireless signal to the fluid delay system of the first wellbore servicing tool, wherein receipt of the first wireless signal by the fluid delay system of the first wellbore servicing tool is effective to actuate the fluid delay system of the first wellbore servicing tool; and
communicating a wellbore servicing fluid to a first zone of the subterranean formation via the one or more ports of the first wellbore servicing tool.
The wellbore servicing method of embodiment 9, wherein communicating the first wireless signal to the fluid delay system of the first wellbore servicing tool comprises flowing a first signaling member via the axial flowbore of the first wellbore servicing tool.
The wellbore servicing method of embodiment 10, wherein the first signaling member is configured to provide the first wireless signal for receipt by the fluid delay system of the first wellbore servicing tool.
The wellbore servicing method of one of embodiments 10 through 11, wherein the first wireless signal comprises a radio frequency, an RFID signal, a magnetic field, an acoustic signal, or combinations thereof.
The wellbore servicing method of one of embodiments 10 through 12, wherein the wellbore servicing system further comprises a second wellbore servicing tool, the second wellbore servicing tool comprising:
The wellbore servicing method of embodiment 13, further comprising:
communicating the first wireless signal to the fluid delay system of the second wellbore servicing tool, wherein receipt of the first wireless signal by the fluid delay system of the second wellbore servicing tool is effective to actuate the fluid delay system of the second wellbore servicing tool; and
communicating a wellbore servicing fluid to a second zone of the subterranean formation via the one or more ports of the second wellbore servicing tool.
The wellbore servicing method of embodiment 13, further comprising:
communicating the first wireless signal to the fluid delay system of the second wellbore servicing tool, wherein receipt of the first wireless signal by the fluid delay system of the second wellbore servicing tool is not effective to actuate the fluid delay system of the second wellbore servicing tool.
The wellbore servicing method of embodiment 15, further comprising:
communicating a second wireless signal to the fluid delay system of the second wellbore servicing tool, wherein receipt of the second wireless signal by the fluid delay system of the second wellbore servicing tool is effective to actuate the fluid delay system of the second wellbore servicing tool; and
communicating a wellbore servicing fluid to a second zone of the subterranean formation via the one or more ports of the second wellbore servicing tool.
The wellbore servicing method of one of embodiments 13 through 16, wherein the first wellbore servicing tool and the second wellbore servicing tool are incorporated within a tubular string, the tubular string generally defining a tubular string axial flowbore, wherein the axial flowbore of the first wellbore servicing tool, the axial flowbore of the second wellbore servicing tool, and the tubular string axial flowbore each have a internal diameter, wherein the internal diameter of the axial flowbore of the first wellbore servicing tool and the internal diameter of the axial flowbore of the second wellbore servicing tool are substantially the same as the internal diameter of the tubular string axial flowbore.
A wellbore servicing method comprising:
positioning a wellbore servicing system within a wellbore penetrating a subterranean formation, the wellbore servicing system comprising a first wellbore servicing tool, the first wellbore servicing tool being configured in a first mode and transitionable from the first mode to a second mode and from the second mode to a third mode, the first wellbore servicing tool comprising:
communicating a first wireless signal to the fluid delay system of the first wellbore servicing tool, wherein receipt of the first wireless signal by the fluid delay system of the first wellbore servicing tool is effective to transition the first wellbore servicing tool from the first mode to the second mode;
allowing the first wellbore servicing tool to transition from the second mode to the third mode; and
communicating a wellbore servicing fluid to a first zone of the subterranean formation via the one or more ports of the first wellbore servicing tool.
The wellbore servicing method of embodiment 18,
wherein, in the first mode, the fluid delay system is configured to hold the sliding sleeve relative the housing so as to prevent fluid communication via a route of fluid communication from the axial flowbore to an exterior of the housing via the one or more ports,
wherein, in the second mode, the fluid delay system is configured to allow the sliding sleeve to move relative to the housing at a controlled rate,
wherein, in the third mode, the sliding allows fluid communication via the route of fluid communication from the axial flowbore to an exterior of the housing via the one or more ports.
The wellbore servicing method of one of embodiments 18 through 19, wherein communicating the first wireless signal to the fluid delay system of the first wellbore servicing tool comprises flowing a first signaling member via the axial flowbore of the first wellbore servicing tool.
The wellbore servicing method of embodiment 20, wherein the first signaling member is configured to provide the first wireless signal for receipt by the fluid delay system of the first wellbore servicing tool.
The wellbore servicing method of one of embodiments 18 through 21, wherein the wellbore servicing system further comprises a second wellbore servicing tool, the second wellbore servicing tool being configured in a first mode and transitionable from the first mode to a second mode and from the second mode to a third mode, the second wellbore servicing tool comprising:
The wellbore servicing method of embodiment 22, further comprising:
communicating the first wireless signal to the fluid delay system of the second wellbore servicing tool, wherein receipt of the first wireless signal by the fluid delay system of the second wellbore servicing tool is effective to transition the second wellbore servicing tool from the first mode to the second mode;
allowing the second wellbore servicing tool to transition from the second mode to the third mode; and
communicating a wellbore servicing fluid to a second zone of the subterranean formation via the one or more ports of the second wellbore servicing tool.
The wellbore servicing method of embodiment 22, further comprising:
communicating the first wireless signal to the fluid delay system of the second wellbore servicing tool, wherein receipt of the first wireless signal by the fluid delay system of the second wellbore servicing tool is not effective to transition the second wellbore servicing tool from the first mode to the second mode.
The wellbore servicing method of embodiment 24, further comprising:
communicating the second wireless signal to the fluid delay system of the second wellbore servicing tool, wherein receipt of the second wireless signal by the fluid delay system of the second wellbore servicing tool is effective to transition the second wellbore servicing tool from the first mode to the second mode;
allowing the second wellbore servicing tool to transition from the second mode to the third mode; and
communicating a wellbore servicing fluid to a second zone of the subterranean formation via the one or more ports of the second wellbore servicing tool.
At least one embodiment is disclosed and variations, combinations, and/or modifications of the embodiment(s) and/or features of the embodiment(s) made by a person having ordinary skill in the art are within the scope of the disclosure. Alternative embodiments that result from combining, integrating, and/or omitting features of the embodiment(s) are also within the scope of the disclosure. 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 means that the element is required, or alternatively, the element is not required, both alternatives being within the scope of the claim. Use of broader terms such as comprises, includes, and having should be understood to provide support for narrower terms such as consisting of, consisting essentially of, and comprised substantially of. Accordingly, the scope of protection is not limited by the description set out above but is defined by the claims that follow, that scope including all equivalents of the subject matter of the claims. Each and every claim is incorporated as further disclosure into the specification and the claims are embodiment(s) of the present invention.
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