Patent Application
20240295155
The present disclosure relates to technologies for subterranean operations and, more particularly, to bottomhole assemblies, systems and methods that can be used in wellbore sections within subterranean formations, for example to shift sleeves.
Downhole operations for shifting components along a wellbore often require specific tools, such as shifting tools, for the application of a force of the component in question. For example, valve assemblies provided with sliding valve sleeves are shifted open using a shifting tool secured thereto, and by pumping fluids down the wellbore. The hydraulic pressure applied on the shifting tool creates the required force for shifting the valve sleeve open. Known shifting tools require a section of the wellbore to be generally sealed, using packers for example, to increase the hydraulic pressure along that section. In such applications, the hydraulic pressure applied to the shifting tool is regulated by the geometry of the shifting tool and the amount of fluid being pumped downhole from the surface.
Hydraulic pressure can be used for shifting valve sleeves installed via interference fit within their valve housing. However, some applications require greater forces which some conventional tools are not configured to generate repeatedly, reliably, or at all. High force applications can be challenging and there is a general need for improvements.
According to an aspect, a bottomhole assembly for use in actuating a valve assembly disposed along a wellbore defined within a subterranean reservoir is provided. The bottomhole assembly includes an anchoring tool having a tubular housing comprising a top sub, a bottom sub and an outer wall extending between the top and bottom subs, the outer wall being provided with one or more openings. The anchoring tool also has a central mandrel connected between and securing the top and bottom subs to one another, the central mandrel being positioned within the outer wall to define an annular region therebetween. The central mandrel defines a fluid passage therethrough and is adapted to establish fluid communication between the top and bottom subs. The anchoring tool further includes an anchor assembly which has an anchor carrier slidably mounted within the annular region and an anchor pivotally connected to the anchor carrier. The anchor is operable between a disconnected position where the anchor is within the annular region, and a connected position after pivoting outwardly through the outer wall to engage internal surfaces of a casing and secure the anchor assembly relative to the wellbore. The anchoring tool also includes a piston assembly having a piston body slidably mounted within the annular region. The piston body defines a piston chamber in fluid communication with the fluid passage, the piston body being actuatable via fluid pressure to slide uphole within the annular region. The piston assembly includes a piston head coupled to the piston body and adapted to slide in an uphole direction upon actuation of the piston body to engage and operate the anchor from the disconnected position in the connected position. The bottomhole assembly also has an actuator having an inner portion coupled to the anchoring tool and comprising an actuator mandrel and an outer portion slidably mounted to the actuator mandrel and having an actuator piston assembly operable via fluid pressure to displace the outer portion downhole to generate a downhole mechanical force. The bottomhole assembly further includes a shifting tool having a shifting tool mandrel operatively connected to the actuator and a mechanical anchor connected to the shifting tool mandrel and operable to be secured to the valve assembly. The anchoring tool is operable between an unset configuration in which the anchor is in the disconnected position, a pre-set configuration in which the anchor is in the connected position, and a set configuration in which the anchor is in the connected position and the bottom sub abuts the piston body such that the anchor assembly, the piston assembly and the housing define a mechanical brace for transmission of the downhole mechanical force to the valve assembly via the shifting tool.
According to another aspect, a bottomhole assembly for use in actuating a valve assembly disposed along a wellbore defined within a subterranean reservoir is provided. The bottomhole assembly includes an anchoring tool having a tubular housing comprising a top sub, a bottom sub and an outer wall extending between the top and bottom subs, the outer wall being provided with one or more openings. The anchoring tool also has a central mandrel secured between the top and bottom subs and positioned within the outer wall to define an annular region therebetween, the central mandrel defining a fluid passage therethrough and is adapted to establish fluid communication between the top and bottom subs. The anchoring tool includes an anchor assembly having an anchor carrier slidably mounted within the annular region and an anchor pivotally connected to the anchor carrier and operable between a disconnected position where the anchor is at least partially within the annular region, and a connected position after pivoting outwardly through the opening of the outer wall to engage internal surfaces of a wellbore casing and secure the anchor assembly relative to the wellbore. The anchoring tool also includes a piston assembly having a piston body slidably mounted within the annular region, the piston body defining a piston chamber in fluid communication with the fluid passage, the piston body being actuatable via fluid pressure to slide uphole within the annular region. The piston assembly also includes a piston head coupled to the piston body and being adapted to slide in an uphole direction upon actuation of the piston body to engage and operate the anchor from the disconnected position in the connected position. The anchoring tool being operable between an unset configuration in which the anchor is in the disconnected position, a pre-set configuration in which the anchor is in the connected position, and a set configuration in which the anchor is in the connected position and the bottom sub abuts the piston body such that the anchor assembly, the piston assembly and the housing define a mechanical brace for transmission of a downhole mechanical force to the valve assembly.
According to a possible implementation, the anchor assembly includes a plurality of anchors provided about the anchor carrier, and the anchors are adapted to extend through respective openings in the outer wall of the tubular housing.
According to a possible implementation, the anchors are provided at regular intervals about the anchor carrier.
According to a possible implementation, the one or more openings are sized and adapted to enable uphole movement of the housing relative to the anchors when operating the anchoring tool from the pre-set configuration to the set configuration.
According to a possible implementation, each opening includes an opening perimeter, and wherein the anchors are spaced from the opening perimeter during the uphole movement of the housing to prevent contact between the anchors and the outer wall.
According to a possible implementation, the openings include elongate slots extending along the outer wall, and wherein each anchor is aligned with a corresponding one of the elongate slots.
According to a possible implementation, a downhole chamber is defined when the piston assembly is actuated uphole to engage the piston head with the anchor, the downhole chamber being in fluid communication with the fluid passage.
According to a possible implementation, the bottom sub is displaced into the downhole chamber to abut the piston body and define the mechanical brace.
According to a possible implementation, the piston head comprises a setting cone having an outer surface, and the anchor comprises a tapered inner surface spaced from the central mandrel, and wherein the setting cone is adapted to engage the anchor from below the tapered inner surface to urge the anchor outwardly through the opening of the outer wall.
According to a possible implementation, the piston assembly is operable at an anchoring fluid pressure adapted to displace the piston body and piston head in the uphole direction to engage the anchor.
According to a possible implementation, the piston body comprises at least one guiding stud, and wherein the central mandrel comprises at least one guiding channel, the guiding stud being adapted to engage the guiding channel to block rotational movement of the piston assembly about the central mandrel and axially guide the piston assembly along the central mandrel.
According to a possible implementation, the anchor carrier comprises at least one guiding pin, and wherein the central mandrel comprises at least one guiding groove, the guiding pin being adapted to engage the guiding groove to block rotational movement of the anchor assembly about the central mandrel and axially guide the anchor assembly along the central mandrel.
According to a possible implementation, the anchor carrier comprises at least one guiding pin, and wherein the outer wall comprises at least one guiding groove, the guiding pin being adapted to engage the guiding groove to block rotational movement of the anchor assembly about the central mandrel and axially guide the anchor assembly along the annular region.
According to a possible implementation, the bottomhole assembly further includes a shifting tool connectable to the valve assembly, and an actuator operatively coupled between the anchoring tool and the shifting tool, the actuator being adapted to cooperate with the mechanical brace to increase the downhole mechanical force to actuate the shifting tool to shift the valve assembly between various configurations.
According to a possible implementation, the actuator is a linear actuator and comprises an inner portion coupled to the anchoring tool and adapted to cooperate with the mechanical brace, and an outer portion slidably mounted to the inner portion, wherein the actuator is operable to displace the outer portion to apply the downhole mechanical force on the shifting tool.
According to a possible implementation, the inner portion comprises an actuator sub coupled to the anchoring tool, and an actuator mandrel connected to and extending from the actuator sub, and wherein the outer portion comprises an actuator housing slidably mounted to the actuator mandrel and defining an actuator annular region therebetween.
According to a possible implementation, the actuator comprises an actuator piston assembly provided in the actuator annular region and in fluid communication with the fluid passage, the actuator piston assembly being operable via fluid pressure at a shifting fluid pressure to displace the outer portion downhole.
According to a possible implementation, the shifting fluid pressure is between about 6,000 psi and 10,000 psi, and wherein the anchoring fluid pressure is less than the shifting fluid pressure.
According to a possible implementation, the actuator piston assembly is operable at a setting fluid pressure provided between the anchoring fluid pressure and the shifting fluid pressure and being adapted to apply hydraulic pressure on the housing of the anchoring tool to push the bottom sub against the piston body, thereby operating the anchoring tool from the pre-set configuration to the set configuration.
According to a possible implementation, the anchor comprises an anchoring surface provided with one or more grips adapted to engage the casing when operating the anchor in the connected position, wherein engagement of the grips with the internal surface secures the anchor assembly relative to the wellbore.
According to a possible implementation, the bottomhole assembly further includes a flow limiter coupled between and in fluid communication with the anchoring tool and the actuator, the flow limiter being operable between an unrestricted configuration where fluid flowrate remains substantially the same through the flow limiter, and a flow-restricting configuration where fluid flowrate is reduced through the flow limiter.
According to a possible implementation, the flow limiter is hydraulically operable between the unrestricted and the flow-restricting configurations.
According to a possible implementation, the flow limiter comprises a limiter housing and a limiter mandrel extending through the limiter housing, and wherein the limiter housing is slidably mounted to the limiter mandrel.
According to a possible implementation, the limiter housing defines a fluid chamber having inner walls spaced from the limiter mandrel, and wherein the flow limiter further comprises a limiter nozzle positioned along the limiter mandrel within the fluid chamber, the limiter nozzle being provided with a nozzle opening adapted to restrict fluid flow therethrough.
According to a possible implementation, the limiter mandrel comprises fluid channels extending through a thickness of the limiter mandrel for establishing fluid communication between the limiter mandrel and the fluid chamber, and wherein the fluid channels comprise upstream fluid channels provided upstream of the limiter nozzle, and downstream fluid channels provided downstream of the limiter nozzle.
According to a possible implementation, when in the unrestricted configuration, each one of the fluid channels is in fluid communication with the fluid chamber such that fluid flowing through the limiter mandrel is adapted to flow around the limiter nozzle via the fluid channels and fluid chamber.
According to a possible implementation, when in the flow-restricting configuration, the limiter housing is adapted to slide relative to the limiter nozzle to occlude one of the downstream and upstream fluid channels thereby restricting fluid flow through the nozzle opening of the limiter nozzle.
According to a possible implementation, sliding the limiter housing comprises abutting the limiter housing against the limiter nozzle.
According to a possible implementation, sliding the limiter housing comprises positioning the limiter nozzle out of and adjacent to the fluid chamber.
According to a possible implementation, the limiter housing and the limiter nozzle engage one another to define a metal-to-metal seal therebetween.
According to a possible implementation, at least one of the limiter housing and the limiter nozzle is provided with an elastomer sealing component, and wherein the limiter housing and the limiter nozzle engage one another at the elastomer sealing component to define a seal therebetween.
According to a possible implementation, the shifting tool comprises a mechanical anchor configured to engage a valve sleeve of the valve assembly and secure the shifting tool relative to the valve sleeve.
According to a possible implementation, the downhole mechanical force is adapted to break shear fasteners securing a valve sleeve of the valve assembly within the valve assembly and enable movement of the valve sleeve.
According to another aspect, a hydraulic anchor of a stroker tool configured for mechanical connection with a valve assembly disposed along a wellbore defined within a subterranean reservoir is provided. The hydraulic anchor includes a housing comprising a top sub, a bottom sub and an outer wall extending between and securing the top and bottom subs to one another, a central mandrel secured between the top and bottom subs and positioned within the outer wall, the central mandrel defining a fluid passage therethrough and is adapted to establish fluid communication between the top and bottom subs. The hydraulic anchor has an anchor assembly provided proximate the top sub and includes an anchor carrier slidably mounted to the central mandrel and an anchor pivotally connected to the anchor carrier and being operable between a disconnected configuration where the anchor is at least partially within the annular region, and a connected position after pivoting outwardly through the elongate opening of the outer wall to engage internal surfaces of the casing and secure the anchor assembly relative to the wellbore. The hydraulic anchor also includes a piston assembly provided between the anchor assembly and the bottom sub, comprising a piston body slidably coupled to the central mandrel, the piston body having a piston chamber in fluid communication with the fluid passage, the piston body being actuatable via fluid flow to slide along the tubular mandrel. The piston assembly has a piston head coupled to the piston body and being slidably mounted to the central mandrel, the piston head being adapted to slide along the central mandrel in an uphole direction upon actuation of the piston body to engage and operate the anchor in the connected configuration. The hydraulic anchor being operable between an unset configuration in which the anchor is in the disconnected position, a pre-set configuration in which the anchor is in the connected position, and a set configuration in which the anchor is in the connected position and the bottom sub abuts the piston body such that the anchor assembly, the piston assembly and the housing define a mechanical brace for transmission of a downhole mechanical force to the valve assembly.
According to another aspect, a method of shifting a valve sleeve of a valve assembly provided along a wellbore string disposed within a wellbore defined within a subterranean reservoir using a stroker tool is provided. The method includes the steps of injecting fluid down the wellbore string to increase a fluid pressure within a hydraulic anchor of the stroker tool to an anchoring pressure adapted to have a piston assembly of the hydraulic anchor engage and secure an anchor assembly of the hydraulic anchor to the casing; increasing the fluid pressure to a setting pressure adapted to engage a housing of the hydraulic anchor with the piston assembly to set the hydraulic anchor, with the housing, the piston assembly and the anchor assembly defining a mechanical brace with the wellbore; and increasing the fluid pressure to a shifting pressure adapted to operate an actuator of the bottomhole assembly. The actuator being adapted to brace on the mechanical brace for creating a downhole mechanical force for actuating a shifting tool connected to the valve sleeve.
According to a possible implementation, the valve sleeve is secured along the wellbore via shear connectors, and wherein the downhole mechanical force is adapted to break the shear connectors.
According to another aspect, a stroker tool for deployment within a wellbore defined within a subterranean reservoir and provided with a valve assembly is provided. The stroker tool includes an anchoring tool having a tubular housing comprising a top sub, a bottom sub and an outer wall extending between and securing the top and bottom subs to one another, a central mandrel secured between the top and bottom subs and positioned within the outer wall to define an annular region therebetween. The anchoring tool further includes an anchor assembly slidably mounted within the annular region and operable between a retracted position where the anchor assembly is within the annular region, and an extended position where the anchor assembly is secured to a casing of the wellbore. The anchoring tool further includes a piston assembly slidably mounted within the annular region and operable via fluid pressure to slide uphole within the annular region to engage and operate the anchor assembly from the retracted position to the extended position. The stroker tool also has an actuator comprising an inner portion coupled to the anchoring tool and comprising an actuator mandrel; and an outer portion slidably mounted to the actuator mandrel and comprising an actuator piston assembly operable via fluid pressure to displace the outer portion downhole to generate a downhole mechanical force. The stroker tool also includes a shifting tool comprising a shifting tool mandrel operatively connected to the actuator and a mechanical anchor connected to the shifting tool mandrel and operable to be secured to the valve assembly. The shifting tool being actuatable via operation of the actuator to transmit the downhole mechanical force to the valve assembly for moving the valve assembly in an open configuration. The stroker tool includes a flow limiter comprising a limiter housing coupled between the anchoring tool and the actuator; and a limiter mandrel extending through the limiter housing, where the limiter housing is slidably mounted to the limiter mandrel. The flow limiter being operable between an unrestricted configuration where fluid flowrate remains substantially the same through the flow limiter, and a flow-restricting configuration where fluid flowrate is reduced through the flow limiter and into the actuator.
According to a possible implementation, the flow limiter is hydraulically operable between the unrestricted and the flow-restricting configurations.
According to a possible implementation, the limiter housing defines a fluid chamber having inner walls spaced from the limiter mandrel, and wherein the flow limiter further comprises a limiter nozzle positioned along the limiter mandrel within the fluid chamber, the limiter nozzle being provided with a nozzle opening adapted to restrict fluid flow therethrough.
According to a possible implementation, the limiter mandrel comprises fluid channels extending through a thickness of the limiter mandrel for establishing fluid communication between the limiter mandrel and the fluid chamber, and wherein the fluid channels comprise upstream fluid channels provided upstream of the limiter nozzle, and downstream fluid channels provided downstream of the limiter nozzle.
According to a possible implementation, when in the unrestricted configuration, each one of the fluid channels is in fluid communication with the fluid chamber such that fluid flowing through the limiter mandrel is adapted to flow around the limiter nozzle via the fluid channels and fluid chamber.
According to a possible implementation, when in the flow-restricting configuration, the limiter housing is adapted to slide uphole to occlude the downstream fluid channels thereby restricting fluid flow through the nozzle opening of the limiter nozzle.
According to a possible implementation, sliding the limiter housing uphole comprises abutting the limiter housing against the limiter nozzle.
According to another aspect, a high force stroker tool for integration within a wellbore string disposed along a wellbore defined within a subterranean reservoir is provided. The high force stroker tool includes a hydraulic anchor hydraulically operable to deploy slips securable to the wellbore and to define a mechanical brace, and a shifting tool operatively coupled to the hydraulic anchor and comprising a mechanical anchor securable to a movable component, the shifting tool being mechanically operable to move the movable component; and an actuator coupled between the hydraulic anchor and the shifting tool, the actuator being hydraulically operable to brace against the mechanical brace and create a downhole mechanical force adapted to mechanically operate the shifting tool.
According to a possible implementation, the high force stroker tool of claim further comprises a pressure switch operable to restrict a flowrate of fluid into the actuator.
According to another aspect, a bottomhole assembly for deployment within a wellbore defined within a subterranean reservoir and provided with a valve assembly is provided. The bottomhole assembly includes an anchoring tool having a tubular housing comprising an uphole end, a downhole end and an outer wall provided with one or more openings, a central mandrel secured between the uphole end and the downhole end, and positioned within the outer wall to define an annular region therebetween, the central mandrel defining a fluid passage therethrough. The anchoring tool includes an anchor assembly having an anchor carrier slidably mounted within the annular region; and an anchor pivotally connected to the anchor carrier and being operable between a disconnected position where the anchor is at least partially within the annular region, and a connected position after pivoting outwardly through the opening of the outer wall to engage one of a casing of the wellbore and the valve assembly, and secure the anchor assembly relative to the wellbore. The anchoring tool has a piston assembly provided with a piston body slidably mounted within the annular region, the piston body defining a piston chamber in fluid communication with the fluid passage, the piston body being actuatable via fluid pressure to slide toward the anchor assembly within the annular region, and further includes a piston head coupled to the piston body and being adapted to slide toward the anchor assembly upon actuation of the piston body to engage and operate the anchor from the disconnected position in the connected position. The anchoring tool being operable between an unset configuration in which the anchor is in the disconnected position, a pre-set configuration in which the anchor is in the connected position, and a set configuration in which the anchor is in the connected position and the bottom sub abuts the piston body such that the anchor assembly, the piston assembly and the housing define a mechanical brace for transmission of a mechanical force to the valve assembly.
According to a possible implementation, the valve assembly comprises a movable valve sleeve shiftable between a closed position and an open position, and wherein the mechanical force is transmitted to the valve assembly to move the valve sleeve from the closed position to the open position.
According to a possible implementation, the valve assembly comprises a movable valve sleeve shiftable between a closed position and an open position, and wherein the mechanical force is transmitted to the valve assembly to move the valve sleeve from the open position to the closed position.
According to a possible implementation, the anchoring tool is adapted to be positioned within the valve assembly where the anchor assembly is operable to have the anchor be secured to the valve sleeve when in the connected position.
According to a possible implementation, the piston body and the piston head slide in an uphole direction toward the anchor assembly.
According to another aspect, a bottomhole assembly for deployment within a wellbore defined within a subterranean reservoir and provided with a casing lining an interior surface of the wellbore and at least one downhole component is provided. The bottomhole assembly includes an anchoring tool having a tubular housing comprising a top sub, a bottom sub and an outer wall extending between the top and bottom subs, the outer wall being provided with one or more openings; a central mandrel connected between and securing the top and bottom subs to one another, the central mandrel being positioned within the outer wall to define an annular region therebetween, the central mandrel defining a fluid passage therethrough and is adapted to establish fluid communication between the top and bottom subs. The anchoring tool also includes an anchor assembly having an anchor carrier slidably mounted within the annular region; and an anchor pivotally connected to the anchor carrier and being operable between a disconnected position where the anchor is within the annular region, and a connected position after pivoting outwardly through the elongate opening of the outer wall to engage one of the casing and the downhole component, and secure the anchor assembly relative to the wellbore. The anchoring tool also includes a piston assembly having a piston body slidably mounted within the annular region, the piston body defining a piston chamber in fluid communication with the fluid passage, the piston body being actuatable via fluid pressure to slide within the annular region and toward the anchor assembly, and a piston head coupled to the piston body and being adapted to slide within the annular region and toward the anchor assembly upon actuation of the piston body to engage and operate the anchor from the disconnected position in the connected position. The bottomhole assembly has an actuator operatively coupled to the anchoring tool and including an inner portion comprising an actuator mandrel; and an outer portion slidably mounted to the actuator mandrel and comprising an actuator piston assembly operable via fluid pressure to displace the outer portion along the actuator mandrel to generate a mechanical force. The bottomhole assembly also includes a shifting tool including a shifting tool mandrel operatively connected to the actuator; and a mechanical anchor connected to the shifting tool mandrel and operable to be secured to one of the casing and the downhole component. The anchoring tool being operable between an unset configuration in which the anchor is in the disconnected position, a pre-set configuration in which the anchor is in the connected position, and a set configuration in which the anchor is in the connected position and the bottom sub abuts the piston body such that the anchor assembly, the piston assembly and the housing define a mechanical brace for transmission of the mechanical force to the downhole component.
According to a possible implementation, the inner portion is connected to the anchoring tool, and wherein the outer portion is connected to the shifting tool.
According to a possible implementation, the anchoring tool is positioned uphole of the actuator, and wherein the shifting tool is positioned downhole of the actuator.
According to a possible implementation, the downhole component comprises a valve assembly provided with a movable valve sleeve, and wherein the mechanical force is transmitted to the valve assembly to move the valve sleeve.
According to a possible implementation, the shifting tool is adapted to be positioned within the valve assembly such that the mechanical anchor is operable to be secured to the valve sleeve.
According to a possible implementation, the mechanical force is transmitted to the valve assembly via the mechanical anchor, and wherein the shifting tool is adapted to urge the valve sleeve in a downhole direction to move the valve sleeve from a closed position into an open position.
According to a possible implementation, the anchoring tool is adapted to be positioned within the valve assembly such that the anchor assembly is operable to have the anchor be secured to the valve sleeve when in the connected position.
According to a possible implementation, the mechanical force is transmitted to the valve assembly via the anchor of the anchor assembly, and wherein the anchoring tool is adapted to urge the valve sleeve in an uphole direction to move the valve sleeve from an open position into a closed position.
As will be explained below in relation to various implementations, the present disclosure describes apparatuses, systems and methods for various operations, such as the operation of equipment disposed downhole in a wellbore.
In some implementations, the present disclosure describes a bottomhole assembly for integration within a wellbore string disposed along a wellbore extending into the subterranean reservoir. The bottomhole assembly can be deployed downhole in a run-in configuration, and is converted to an operational configuration that uses hydraulic pressure to generate a mechanical force in order to effect a downhole operation. For example, when the downhole operation involves opening or closing a downhole valve assembly by shifting a slidable valve sleeve, the bottomhole assembly can include a stroker tool, which includes a shifting tool for interacting with the valve sleeve, an actuator operatively coupled to the shifting tool to provide the mechanical force to operate the shifting tool, and a hydraulic anchor connected to the actuator and securable to the wellbore to maintain the position of the bottomhole assembly during the sleeve shifting operation. The hydraulic anchor and the actuator are hydraulically operable and cooperate with one another to create a mechanical force adapted to actuate the shifting tool and shift the valve sleeve, for example, to establish fluid communication between the wellbore string and the reservoir. In some implementations, the hydraulic anchor and actuator are operable at high fluid pressures which is converted, via operation of the actuator, in a high mechanical force, for shifting downhole components.
It should be noted that, throughout the present disclosure, the expression “mechanical force” generally corresponds to a high force (e.g., high mechanical force) generated by the actuator of the bottomhole assembly. Common shifting tools are hydraulically operated, with the applied load being controlled by the injection rate of fluid from the surface. In these implementations, the shifting tool is operable via fluid pressure to generate a shifting force between about 4000 psi and 8000 psi, which can be sufficient to shift components secured downhole via interference fit, for example. In other words, known shifting tools can be hydraulically operated to generate the shifting force. In the present disclosure, the bottomhole assembly includes a high force stroker tool configured to use hydraulic pressure (e.g., between about 1000 psi and about 15,000 psi) to operate the actuator, which generates a high mechanical force between about 50,000 lbf and about 150,000 lbf to actuate the shifting tool. These high forces can be used to shift components secured downhole via shear connectors, for example, or components which have become stuck along the wellbore.
As will be described further below, the hydraulic anchor can be operated in various configurations, including an unset configuration where the components of the hydraulic anchor are spaced from the wellbore, thereby enabling downhole deployment of the stroker tool. Once downhole, the hydraulic anchor can be operated in a pre-set configuration where an anchor assembly of the hydraulic anchor engages the wellbore, thereby securing a portion of the hydraulic anchor relative to the wellbore. It should be noted that the wellbore includes a casing lining the inner surface of the wellbore, and that the expression “engaging the wellbore” refers to engagement with the casing or other tubular lining in the wellbore. The casing can be adapted to contribute to the stabilization of the reservoir after the wellbore has been drilled, e.g., by contributing to the prevention of the collapse of the walls of the wellbore. Then, the hydraulic anchor can be operated in a set configuration, where the housing of the hydraulic anchor abuts against the secured portion and defines therewith a mechanical brace for other components of the stroker tool to brace against. As will be described below, a first portion of the actuator is adapted to brace against the mechanical brace, and a second portion of the actuator is hydraulically operable to longitudinally extend along the wellbore. The actuator is thus operable to expand between the hydraulic anchor and the shifting tool, with the mechanical brace preventing uphole expansion of the actuator, thereby restricting the expansion (e.g., extending) downhole. The second portion is coupled to the shifting tool such that the expansion of the actuator creates a driving force, i.e., the high mechanical force, for urging the shifting tool downhole, which transfers the mechanical force to the valve sleeve, thus shifting the valve sleeve in an open position, for example.
It should be understood that, as used herein, the expression “mechanical brace” can refer to an assembly of components functionally fitted together and engaging another structure to provide support. More particularly, the mechanical brace of the present disclosure relates to components of the hydraulic anchor coming into to contact with one another and with the casing of the wellbore to define the support for other components of the stroker tool to brace up against. The mechanical brace can be defined via solid contact (e.g., metal-to-metal) between the various components of the hydraulic anchor. The mechanical brace can also be defined via a combination of solid material and non-compressible fluid, such as a hydraulically pressurized chamber provided between a pair of solid components of the hydraulic anchor, for example. In other words, the mechanical brace can be a load-bearing assembly of components that contact each other and are adapted to define a load-bearing path, notably in the axial direction, between the wellbore (e.g., the casing) and the actuator of the stroker tool.
In some implementations, fluid is injected down the wellbore at a generally constant flowrate which can increase the hydraulic pressure along the stroker tool to operate the actuator. The actuator then generates the mechanical force required to actuate the shifting tool. As will be described further below, the continuous influx of pressurized fluid into the actuator can generate a generally constant pushing force, resulting in a continuously accelerating actuator until an impact occurs along the wellbore. In some implementations, the acceleration of the actuator occurs once the valve sleeve of the valve assembly is shifted in the open position (e.g., once the shear connectors securing the valve sleeve have failed/been broken). As such, the actuator can expand further and faster along the wellbore upon release, which can result in high impact loading.
In other words, the valve sleeve and/or shifting tool can be shifted to the open position and can be moved further downhole until it impacts a shoulder of the valve assembly configured to limit downhole movement of the valve sleeve. The sudden stop of the valve sleeve, in combination with the kinetic energy generated by the operation of the actuator, causes the impact loading on the bottomhole assembly. It is noted that impact loading can cause damage to various parts of the stroker tool. Therefore, in some implementations, the stroker tool can be provided with a flow limiter coupled between the hydraulic anchor and the actuator. The flow limiter is operable to restrict the flowrate of fluid into the actuator, which reduces the expansion rate of the actuator, which in turn reduces the rate at which the valve sleeve open, and thereby prevents excessive impact loading.
In example implementations, the valve sleeve is detachably secured to a valve housing of the valve assembly in a first position, such as via shear fasteners, such that a sufficient mechanical force is required to break, shear, or otherwise disconnect the valve sleeve from the valve housing. With the shear fasteners broken, the valve sleeve can be shifted—for example, shifted into the open position to establish fluid communication with the reservoir. In some implementations, the valve assembly is operable to inject fluid (e.g., a fluid for stimulating hydrocarbon production via a drive process, such as waterflooding, or via a cyclic process, such as “huff and puff”) into the reservoir, produce reservoir fluids, or a combination of both. As will be further described, the valve sleeve can also be shifted into the closed position (e.g., from the open position) to at least partially block fluid communication with the reservoir.
As will be described further below, the hydraulic anchor can define the upholemost component of the bottomhole assembly, and can thus include a housing adapted to be coupled to a conduit of the wellbore string. The hydraulic anchor can also include a mandrel connected to the housing and defining a fluid passage to enable fluid flow through the hydraulic anchor. The hydraulic anchor further includes a piston assembly hydraulically operable to slide within the housing and engage the anchor assembly for securing the anchor assembly to the casing of the wellbore. It is thus noted that the anchor assembly and the piston assembly are both independently slidably mounted within the housing. As such, the anchor assembly and the piston assembly are adapted to move relative to one another and the housing. Similarly, the housing can be adapted to move along the wellbore independently from the anchor assembly and/or the piston assembly. The housing is designed to be displaced in at least one of the uphole and downhole directions while the anchor assembly is secured to casing of the wellbore, and abut against the piston assembly. It is appreciated that the housing abuts the piston assembly, which is engaged with the anchor assembly, which is in turn secured to casing of the wellbore. In other words, the components of the hydraulic anchor are configurable to cooperate and define the mechanical brace with the wellbore (i.e., with the casing).
It is noted that the various implementations of the bottomhole assembly and corresponding components described herein can be implemented in various wellbores, formations, and for various applications such as shearing valve sleeves from within their respective valve housings. In some implementations, the wellbore can be straight, curved, or branched, and can have various wellbore sections. A wellbore section should be considered to be an axial length of a wellbore. A wellbore section can be characterized as “vertical” or “horizontal” even though the actual axial orientation can vary from true vertical or true horizontal, or can tend to undulate or corkscrew or otherwise vary. The term “horizontal”, when used to describe a wellbore section, refers to a horizontal or highly deviated wellbore section as understood in the art, such as a wellbore section having a longitudinal axis that is between 70 and 110 degrees from vertical. For simplicity, it is noted that the conduits, channels, passageways, pipes, tubes and/or other similar components referred to in the present disclosure have a cross-section that is preferably circular or annular, although it should be appreciated that other shapes are also possible.
With reference to
With reference to
In some implementations, each valve assembly 400 can include a valve sleeve slidably mounted within a valve housing for obstructing a valve port in communication with the surrounding reservoir. The valve sleeve is movable (e.g., slidable) into an open position via actuation of the shifting tool 300. In other words, fluid communication between the surface 12 and the reservoir 14 can be established by opening the valve assemblies 400 provided along the wellbore via operation of the stroker tool 25.
As seen in
Now referring to
The central mandrel 110 defines a mandrel passage 112 therethrough for allowing fluid to flow, and is adapted to establish fluid communication between the top and bottom subs. In other words, fluid can be pumped down the tubing string and into the anchoring tool 100 via the top sub 104, flow through the anchoring tool 100 via the central mandrel 110 and exit the anchoring tool 100 via the bottom sub 106.
As illustrated in
With reference to
Moreover, the anchor assembly can include guiding elements configured to guide the anchor assembly during operation thereof, i.e., during displacement of the anchor carrier along the central mandrel 110. In this implementation, and with reference to
As seen in
In some implementations, the anchor 124 is adapted to pivot in a manner such that the body portion 130 protrudes from within the annular region 115 (e.g., from within the housing 102) to engage the casing. As illustrated in
In some implementations, such as the implementation of
In some implementations, and as seen in
In some implementations, the piston assembly is operable to engage the anchor assembly 120 and operate the anchor 124 from the disconnected position to the connected configuration. More specifically, and with reference to
As seen in
In this implementation, the piston body 142 is hydraulically operated via an ingress of fluid in the piston chamber 148 to engage the anchor assembly 120. In other words, fluid flows into the piston chamber 148 to create hydraulic pressure adapted to displace the piston body 142 (e.g., slide) along the central mandrel 110. The piston head 144, being coupled to the piston body 142 via the piston cage 146, also slides along the central mandrel 110 and is adapted to engage the anchor assembly 120. In some implementations, and with reference to
Referring back to
With reference to
In some implementations, operating the anchoring tool 100 from the unset configuration 100a to the pre-set configuration 100b includes actuating the piston assembly 140 in order to move the anchor 124 in the connected position. As described above, the piston assembly 140 is hydraulically operable to engage the anchor assembly 120 for displacing the anchor 124 outwardly through the housing 102 to engage and secure the anchor 124 to the casing. As such, the pre-set configuration 100b can also be referred to as the “hydraulically set configuration” of the anchoring tool 100. It is noted that in the pre-set configuration 100b, the piston assembly 140 is physically engaged with the anchor assembly 120, which is secured to the casing. The housing is then adapted to shift (e.g., be displaced) uphole such that the bottom sub 106 abuts the piston body 142, thereby operating the anchoring tool 100 in the set configuration 100c and defining the mechanical brace 160. It should be understood that, in the set configuration 100c, also referred to as the “mechanically set configuration”, the housing 102, or a portion thereof (e.g., the bottom sub 106), physically engages the piston assembly 140 (e.g., the bottom sub 106 abuts the piston body 142), which is engaged with the anchor assembly 120 secured to the casing. It is thus noted that the housing, piston assembly 140 and anchor assembly 120 are adapted to form the mechanical brace 160, and that other components of the bottomhole assembly (e.g., the actuator) can brace against the mechanical brace 160 to generate a downhole force. It should be noted that, as used herein, the expressions “downhole force”, “uphole force”, “force in the downhole direction” and/or “force in the uphole direction” can refer to a force adapted to urge a component in the corresponding direction. For example, in some implementations, the actuator is adapted to brace against the mechanical brace 160 to generate a downhole force, or “a force adapted to displace a component connected to the actuator downhole along the wellbore”. A person skilled in the art will appreciate that a force is also applied on the mechanical brace, although that force will not generate movement since the mechanical brace is secured to the casing of the wellbore.
Still referring to
From the hydraulically set configuration 100b, the anchoring tool 100 is operable in the mechanically set configuration 100c seen in
As previously noted, when in the mechanically set configuration 100c, the housing 102, piston assembly 140 and anchor assembly 120 define the mechanical brace 160, such that other components of the stroker tool (e.g., the actuator) can brace against the mechanical brace 160 to generate a downhole force. With reference to
In this implementation, the actuator 200 comprises an inner portion 202 coupled to the anchoring tool 100, such as to the housing 102, such as to the bottom sub 106. In addition, the actuator 200 includes an outer portion 204 slidably coupled to the inner portion 202. The outer portion 204 is movable relative to the inner portion and vice versa such that the actuator 200 is operable to expand within the wellbore to generate the downhole pushing force. The inner portion 202 can include an actuator sub 206 provided at the uphole end 207 of the actuator 200, and an actuator mandrel 210 coupled to and extending from the actuator sub 206. The actuator mandrel 210 defines an actuator fluid passage 212 which is in fluid communication with the mandrel passage 112 of the anchoring tool 100. In this implementation, the actuator mandrel 210 can include two or more mandrel sections 211 coupled to one another in an end-to-end manner. As seen in
In this implementation, the outer portion 204 includes an actuator housing 208 slidably connected to the actuator mandrel 210, and a driving sub 214 connected at a downhole end 209 of the actuator 200. In some implementations, the actuator mandrel 210 is concentrically mounted within the actuator housing 208, although it is appreciated that other configurations are possible. It is noted that the inner portion 202, or a portion thereof (e.g., the actuator mandrel 210) and the outer portion 204, or a portion thereof (e.g., the actuator housing 208) define an actuator annular region 215 therebetween.
As illustrated in
The actuator 200 includes an actuating mechanism operable to move the actuator in the expanded configuration and generate the downhole mechanical force adapted to actuate the shifting tool. In this implementation, the actuating mechanism includes an actuator piston assembly 220 operatively coupled to the actuator housing 208 and slidably mounted to the actuator mandrel 210. As illustrated in
In this implementation, the piston assembly 220 includes a plurality of annular piston heads 222 spaced along the actuator mandrel 210. It should therefore be noted that each annular piston head 222 is adapted to have hydraulic pressure applied thereon which generates a greater downhole force (e.g., compared to a single annular piston head 222) for pushing the actuator housing and driving sub 214. As seen in
With reference to
As seen in
Now referring to
In this implementation, the shifting tool 300 illustratively includes a gripping portion 302 operable (via hydraulic means, mechanical means, or a combination thereof) to extend outwardly and engage an inner surface of the valve sleeve 406. Once the gripping portion 302 is engaged with the valve sleeve 406, the shifting tool 300 is at least partially secured to the valve sleeve 406. As such, applying a downhole force on the shifting tool 300, for example via operation of the actuator 200, drags the valve sleeve 406 downhole for uncovering the valve port 404. In some implementations, the valve sleeve 406 is releasably secured to the valve housing 402 via shear connectors. In such implementations, greater shifting forces are required for both shearing the shear connectors and shifting the valve sleeve open. Shifting tools are known in the art and will not be described further in this disclosure.
Referring back to
With the anchoring tool 100 in the hydraulically set configuration 100b, the pressure along the stroker tool 25 increases further. Particularly, the pressure within the annular piston chambers 226 of the actuator 200 increases to hydraulically operate the actuator 200. In some implementations, the fluid pressure within the annular piston chambers exerts a force in both the uphole direction (e.g., on the mandrel joint 213 portion of the piston chambers) and the downhole direction (e.g., on the piston head portion of the piston chambers). In other words, as the fluid pressure increases, the actuator 200 is looking to expand between the anchoring tool 100 and the shifting tool 300, and therefore applies a force in both directions.
As the fluid pressure increases, it reaches a setting fluid pressure corresponding to the pressure required to shear the shear connectors 218 securing the coupling portion of the actuator 200, and generate a force adapted to collapse the piston assembly 140 of the anchoring tool 100. In this implementation, the setting fluid pressure is greater than the anchoring fluid pressure, but less than a fluid pressure required to shift the valve sleeve via operation the actuator and shifting tool. For example, the setting fluid pressure can be between about 1000 psi and about 3000 psi, although other configurations are possible. Therefore, it is noted that the hydraulic pressure within the actuator 200 generates the force required to push the housing 102 of the anchoring tool 100 uphole to have the bottom sub 106 abut against the piston assembly 140. With the bottom sub of the housing 102 abutting the piston assembly 140, the anchoring tool 100 is operated in the mechanically set configuration 100c and defines the mechanical brace 160. As previously described, the mechanical brace 160 prevents further uphole movement of the stroker tool 25 components in order to generate greater amounts of force in the downhole direction.
With the anchoring tool 100 in the mechanically set configuration 100c, the pressure along the stroker tool 25 increases further and reaches a shifting fluid pressure corresponding to the fluid pressure required to shear the shear connectors of the valve sleeve and enable downhole movement of the outer portion 204 of the actuator, of the shifting tool 300 and of the valve sleeve. For example, the shifting fluid pressure can be between about 6000 psi and 10000 psi, such as between about 7000 psi and 9000 psi, such as about 8000 psi, although other configurations are possible. As the actuator 200 braces up against the mechanical brace 160, it is hydraulically operated in the expanded configuration where the outer portion 204 extends axially outwardly to generate the mechanical force required to actuate the shifting tool 300 and open the valve assembly 400.
With reference to
In some implementations, the shear fasteners 175 can be broken via an increase in the force applied by the actuator on the anchoring tool 100. For example, once the valve sleeve has been shifted in the open position, the force generated by the actuator, which is being applied to both the shifting tool and the anchoring tool, can be increased. At a certain force threshold, the shear fasteners 175 break to enable movement of the release mandrel 172 and engagement thereof with the piston head 144. In this implementation, the actuator pushes against the bottom sub, such that the housing 102 of the anchoring tool 100 is displaced uphole. The bottom sub abuts the piston body 142, which is connected to the release mandrel 172 via the piston cage 146. Therefore, applying a force on the housing to move it in the uphole direction generates a corresponding force on the release mandrel 172, and thus on the shear fasteners 175. Once sheared, it should be understood that the release mandrel 172 is adapted to move toward and engage the piston head 144 due to the engagement of the setting cone 150 with the anchors 124, which are secured to the casing of the wellbore.
Once the pressure is bled from within the stroker tool (e.g., after having operated the shifting tool), the anchoring tool 100 can be moved to the reset configuration, where the piston assembly 140 disengages the anchor assembly 120. More specifically, in order to move from the set configuration to the reset configuration, the release mandrel 172 is sheared from its initial position to engage the piston head 144, and the housing 102 of the anchoring tool 100 is subsequently moved downhole, e.g., when the pressure is bled from within the stroker tool, thereby relaxing the actuator and enabling the downhole movement. In this implementation, the release mechanism 170 includes a piston spring 174 provided within the annulus defined between the piston cage 146 and the central mandrel 110. The piston spring 174 is illustratively provided between the release mandrel 172 and the piston body 142, and is adapted to hold the piston body 142 in abutment with the bottom sub 106 as the housing 102 is moved downhole. The central mandrel 110 can include a mandrel shoulder 176 adapted to abut an uphole end of the piston spring 174, with a downhole end of the piston spring 174 abutting the piston body 142. As such, it is noted that moving the housing 102 downhole, which includes moving the top sub, the central mandrel and the bottom sub downhole, correspondingly pushes the piston spring 174 due to the contact with the mandrel shoulder 176, which pushes the piston body 142. Moreover, it should be noted that the piston body 142 is secured to the piston cage 146, which is in turn secured to the release mandrel 172. Therefore, pushing the piston body 142 downhole (along with the housing 102) drags the piston cage 146 and the release mandrel 172 downhole along with it. As described, the release mandrel 172 is secured to the piston head 144 (e.g., via interference fit) and thus drags the piston head 144 and the setting cone 150 downhole and away from the anchor assembly 120.
As the piston assembly 140 is spaced from the anchor assembly 120, it is noted that the garter springs 139 exert an inward force on the anchors 124, which facilitates their movement back in the retracted position (e.g., within the annular region). The overall length of the piston assembly 140 (e.g., from the setting cone 150 to the piston body 142) is illustratively reduced due to the engagement of the release mandrel 172 within the piston head 144. Therefore, the piston assembly 140 is “deactivated” and can no longer engage the anchor assembly 120, i.e., the setting cone 150 can no longer engage the anchor assembly 120 in the space below the anchor body 130. The piston spring 174 can be adapted to limit the uphole movement of the piston assembly 140 (e.g., the spring 174 can be fully compressed, thereby preventing further movement) such that reducing the length of the piston assembly prevents the setting cone 150 from reaching the anchors 124. The reset configuration can be useful once the valve assemblies are open along the wellbore, and the stroker tool is recovered to surface. For instance, “deactivating” the piston assembly 140 prevents the setting cone 150 from inadvertently engaging the anchor assembly 120, which can snag on the casing as the tool is pulled from the wellbore.
In some implementations, the mechanical force generated by the actuator 200 to shift the valve sleeve can result in high impact loading, which can damage various components of the stroker tool 25. For example, the shifting tool 300 can be adapted to abut against a shoulder of the valve assembly once the valve sleeve is shifted open. The continuous influx of pressurized fluid into the actuator 200 generates a generally constant force on the actuator piston assembly 220. It is noted that the generally constant force can continuously accelerate the outer portion until it impacts another component. In other words, the velocity, and therefore the kinetic energy, of the outer portion increases continuously as the actuator is operated. In such implementations, the combined mechanical force and kinetic energy pushing on the shifting tool 300 can cause the shifting tool to impact the valve shoulder at the same velocity as the actuator expands, resulting in an abrupt stop and high impact loading. With reference to
In this implementation, the flow limiter 500 is operable between an unrestricted configuration (seen in
As seen in
When in the restricted configuration, the limiter housing 502 is adapted to block the flow openings provided downstream of the flow nozzle 514 such that fluid flow is restricted to flowing through the nozzle opening 516 of the limiter nozzle 514 (as illustrated by the arrows in
The housing 502 can be displaced via operation of the actuator 200 at the setting fluid pressure. As previously described, when the hydraulic pressure reaches the setting fluid pressure, the actuator exerts a force in the uphole direction to position the anchoring tool 100 in the mechanically set configuration. In this implementation, and with reference to
In the above-described implementations, the shifting tool 300 can be provided with a locator 310 adapted to cooperate with the downhole component (e.g., the valve assembly 400) for identifying the location of the stroker tool 25 along to the wellbore. The locator 310 can be complementarily shaped relative to a profile defined along the wellbore, such as in the casing (e.g., in a blank sleeve), within the valve assembly or at any other location. Therefore, the stroker tool 25 can be run downhole until the locator 310 engages the profile which at least partially prevents further downhole movement of the stroker tool 25 along the wellbore. It should be noted that the location of the profile down the wellbore is typically known such that the location of the stroker tool 25 can be determined once the locator 310 engages the profile.
In this implementation, and with reference to
As seen in
It should be appreciated from the present disclosure that the various implementations of the bottomhole assembly, stroker tool and related components enable the stroker tool to be positioned at a desired location along the wellbore prior to being connected to a downhole component, such as a valve assembly via the shifting tool. The anchoring tool, or hydraulic anchor, can be hydraulically operated to create a mechanical brace for the actuator to brace up against. The actuator is similarly hydraulically operated to generate a downhole mechanical force, such as via a linear extension of a portion of the actuator. The mechanical force urges the shifting tool downhole, which shifts the valve assembly in the open configuration. Moreover, the integration of a flow limiter in the stroker tool regulates the ingress of fluid in the actuator in order to limit the speed at which the actuator expands along the wellbore and urges the shifting tool downhole. The present stroker tool facilitates the life of well management by enabling opening and/or closing specific sleeves without shifting other sleeves. The stroker tool can also be used to shift stuck sleeves which require great mechanical force to become unstuck. The stroker tool also does not require to define a closed system uphole of the tool to generate the required pressure along the annulus defined between the tubing string and the casing of the wellbore. Instead, the stroker tool uses hydraulic force to create a mechanical brace, and further uses hydraulic force and converts it into a mechanical force to enable shifting sleeves.
As described above, the stroker tool is operable for opening valves disposed along the wellbore and establish fluid communication between the surface and the reservoir. Therefore, the stroker tool can be used as part of various operations, such as in a hydrocarbon-containing reservoir for injecting or producing fluids through the valve. In some implementations, the reservoir is fractured as part of a plug-and-perf operation, and fluid is injected into the reservoir as part of a waterflooding operation, CO2 flooding operation, or any other suitable injection operations. The valve assemblies can be operated to enable production of fluids as part of geothermal operations or acid solution mining operations, among other possible operational configurations of the wellbore.
The bottomhole assembly can also be used as for various other downhole operations (i.e., different operations than shifting the valve sleeve of the valve assembly). In such implementations, it is noted that the shifting can be removed, replaced and/or provided with additional components for performing different downhole operations.
The present disclosure may be embodied in other specific forms without departing from the subject matter of the claims. The described example implementations are to be considered in all respects as being only illustrative and not restrictive. For example, in the implementations described herein, the hydraulic anchor is configured to be secured to the casing of the wellbore, with the shifting tool being connected to the valve sleeve for shifting the valve sleeve open. In alternate implementations, the hydraulic anchor can be positioned within the valve assembly such that the anchor assembly can be configured to be secured to the valve sleeve. In such implementations, it is noted that the shifting tool can be connected to the casing of the wellbore, or alternatively to another valve sleeve. The actuator is operated to expand between the hydraulic anchor and the shifting tool, thereby generating a force on the one or more valve sleeves until the shear connectors break, for example. It is appreciated that the stroker tool can be used to open valve sleeves which shift open in either the uphole direction and/or the downhole direction.
It should also be noted that the stroker tool can be used to operate the valve assembly from the open configuration to the closed configuration (e.g., by closing the valve sleeve). For example, the anchoring tool can be positioned within the valve assembly to secure the anchors to the valve sleeve, and the shifting tool can be secured to the casing of the wellbore, for example, downhole of the valve assembly. Once both the anchoring tool and the shifting tool are secured, the actuator is actuated and expands between the anchoring tool and shifting tool, thus generating a pushing force on the mechanical brace which urges the valve sleeve into the closed position. In some implementations, the valve sleeve is urged in the uphole direction in order to move to the closed position. As such, it is appreciated that the shifting tool is secured to the casing downhole of the valve assembly. However, it should be noted that other configurations are possible, such as moving the valve sleeve in the downhole direction in order to close the valve assembly, for example.
In order to locate open sleeves along the wellbore, the valve assemblies can be provided with a profile shaped and adapted to cooperate with the locator of the shifting tool. For example, after shifting a valve sleeve into the open position, a second profile can be defined in the space where the valve sleeve used to be (i.e., when in the closed position). Therefore, the shifting tool can be positioned within the valve assembly by having the locator engage the second profile. The stroker tool can then be run further downhole in order to position the anchoring tool in the valve assembly for engagement therewith, and for closing the valve sleeve. It is noted that the overall length of the stroker tool, along with the lengths of each one of its components, are known. As such, after the locator of the shifting tool engages the second profile, an operator can know the distance between the locator and the anchor assembly such that the stroker tool is run further downhole by substantially said distance, thereby positioning the anchors in alignment with the valve sleeve. The anchors can then be secured to the valve sleeve, and the shifting tool can be secured to the casing of the wellbore. Then, the actuator can be operated and expands, thereby pushing the bottom sub uphole to define the mechanical brace, and generating a pushing force on the mechanical brace which urges the valve sleeve into the closed position.
It should also be noted that the stroker tool can be installed in other configurations, such as with the shifting tool being uphole of the actuator, which is in turn uphole of the hydraulic anchor. In such implementations, it is appreciated that the mechanical force required to shift the valve sleeve would be generated in the uphole direction. In yet another possible implementation, the shifting tool can be replaced by another hydraulic anchor such that the stroker tool includes a pair of hydraulic anchors at either ends, with the actuator in between the hydraulic anchors.
In some implementations, it is appreciated that the actuator can be “flipped upside down”, with the outer portion being coupled to the hydraulic anchor, and the inner portion being coupled to the shifting tool, for example. During expansion, the outer portion will be adapted to push against the mechanical brace, and the inner portion will be adapted to push against the shifting tool to generate the force required to shift the valve sleeve open. In addition, throughout the disclosure, the mechanical force is generated in the downhole direction toward the shifting tool in order to shift the valve sleeve open (i.e., also in the downhole direction). However, it is appreciated that, depending on the orientation and/or configuration of the stroker tool, the mechanical force required to shift the valve sleeve can be generated in the uphole direction, or a combination of the downhole and uphole directions.
The present disclosure intends to cover and embrace all suitable changes in technology. The scope of the present disclosure is, therefore, described by the appended claims rather than by the foregoing description. The scope of the claims should not be limited by the implementations set forth in the examples, but should be given the broadest interpretation consistent with the description as a whole.
As used herein, the terms “coupled”, “coupling”, “attached”, “connected” or variants thereof as used herein can have several different meanings depending in the context in which these terms are used. For example, the terms coupled, coupling, connected or attached can have a mechanical connotation. For example, as used herein, the terms coupled, coupling or attached can indicate that two elements or devices are directly connected to one another or connected to one another through one or more intermediate elements or devices via a mechanical element depending on the particular context.
In the above description, the same numerical references refer to similar elements. Furthermore, for the sake of simplicity and clarity, namely so as to not unduly burden the figures with several references numbers, not all figures contain references to all the components and features, and references to some components and features may be found in only one figure, and components and features of the present disclosure which are illustrated in other figures can be easily inferred therefrom. The implementations, geometrical configurations, materials mentioned and/or dimensions shown in the figures are optional, and are given for exemplification purposes only.
In addition, although the optional configurations as illustrated in the accompanying drawings comprises various components and although the optional configurations of the valve assembly as shown may consist of certain geometrical configurations as explained and illustrated herein, not all of these components and geometries are essential and thus should not be taken in their restrictive sense, i.e. should not be taken as to limit the scope of the present disclosure. It is to be understood that other suitable components and cooperations thereinbetween, as well as other suitable geometrical configurations may be used for the implementation and use of the valve assembly, and corresponding parts, as briefly explained and as can be easily inferred herefrom, without departing from the scope of the disclosure.
| Filing Document | Filing Date | Country | Kind |
|---|---|---|---|
| PCT/CA2021/051296 | 9/16/2021 | WO |
| Number | Date | Country | |
|---|---|---|---|
| 63202267 | Jun 2021 | US |
