Abstract: A wiper plug can be used in wellbore operations. The wiper plug can include a fishing neck located at a rear portion of the plug. The fishing neck can be a male or female fishing neck. A corresponding male or female fishing tool can be used to retrieve the wiper plug from a tubing string. The wiper plug can include a nose that can land on a landing tool or a female fishing neck of another wiper plug. The wiper plug can be introduced into the tubing string before or after a cement composition. The wiper plug can include a rupture disk that allows an operator at a wellhead to observe a pressure change to indicate the location of the wiper plug and fluid within the tubing string.

Abstract: A stage cementing tool for use in a wellbore comprises a mandrel having a plurality of circumferentially spaced first longitudinal slots and a plurality of circumferentially spaced second longitudinal slots. An opening sleeve is disposed in the mandrel in a first position and movable relative thereto. A setting sleeve disposed about the mandrel is connected to the opening sleeve and movable therewith. A drive sleeve disposed in the mandrel above the opening sleeve is connected to and movable with a closing sleeve disposed about the mandrel.

Abstract: A well tool device includes a housing having an axial through bore; a sleeve section axially displaceable relative to the housing; a fluid flow preventing frangible disc; and an axial fluid passage bypassing the frangible disc when the well tool device is in an initial state, thereby allowing a fluid flow between a first location above the frangible disc and a second location below the frangible disc. The sleeve section includes an axial through bore aligned with the axial through bore of the housing. The axial fluid passage is closed when the well tool device is in a intermediate state. The fluid flow preventing frangible disc is provided in the bore of the sleeve section in sealing engagement with the sleeve section. The well tool device further includes a disc supporting device for supporting the frangible disc in relation to the sleeve section. The disc supporting device is releasably connected inside the sleeve section by a releasable connection device.

Abstract: A drill string coupling and uncoupling method includes forming a well bore by conducting a drilling operation using a drill string having a first drill string segment and a second drill string segment detachably coupled to the first drill string segment; immobilizing the second drill string segment in the well bore; uncoupling the first drill string segment from the second drill string segment; at least partially retracting the first drill string segment in the well bore away from the second drill string segment; reinserting the first drill string segment in the well bore to the second drill string segment; and re-coupling the first drill string segment to the second drill string segment.

Abstract: A system for recovering hydrocarbons comprises a downhole steam generator for coupling with a packer in an injector well, an umbilical device coupled to the downhole steam generator for lifting or lowering the downhole steam generator in the injector well, a first shear point disposed between the downhole steam generator and the packer, and a second shear point disposed between the umbilical device and the downhole steam generator, wherein the first shear point has a shear strength that is different than a shear strength of the second shear point.

Abstract: A downhole chemical injection system for positioning in a well. The system includes a generally tubular mandrel having an axially extending internal passageway and an exterior. The mandrel includes an injection port in fluid communication with the internal passageway or the exterior of the mandrel. A chemical injection line is coupled to the mandrel and is operable to transport a treatment fluid from a surface installation to the mandrel. A check valve is supported by the mandrel and is in downstream fluid communication with the chemical injection line. A density barrier is fluidically positioned between the check valve and the injection port. The density barrier has an axial loop and a circumferential loop relative to the mandrel forming an omnidirectional low density fluid trap, thereby preventing migration of production fluid from the injection port to check valve regardless of the directional orientation of the well.

Abstract: According to a first aspect, a fill-up and circulation tool includes a central assembly including a mandrel, a nose assembly disposed at a terminal end of the mandrel, an outer assembly coupled to the central assembly, and a valve configured to change position between a closed position and an open position, wherein changing position between the closed position and the open position includes movement of the outer assembly relative to the central assembly.

Abstract: An internal bidirectional tubing plug for plugging a well to prevent well fluids from passing the plug in a well conduit until the internal components of the plug are pumped out of its body. The body of the plug connects to the well's tubing string. The body holds a petal assembly consisting of several petals and a tapered cork assembly located within an opening formed by the petals. Both assemblies are sandwiched between upper and lower pistons. Hydrostatic pressure on the bottom of the plug as it is lowered into the fluid filled well holds the petals within the body. The internal components of the plug are removed from the body by applying hydraulic pressure in the upper area of the plug. This causes the plug to fail at a recess provided in the cork, resulting in the two assemblies and the pistons being forced out of the body.

Abstract: Shunt tube flowpaths extending through swellable packers. A well system includes a packer assembly including a base pipe and an annular seal element which is swellable in response to contact with a selected fluid, and a shunt tube flowpath extending through the seal element for delivery of a slurry in a gravel packing operation. A swellable packer assembly includes a base pipe; a swellable annular seal element having a shunt tube flowpath extending through a swellable material; and a valve connected to the flowpath and positioned within the swellable material. Another well system comprises a packer assembly including a base pipe and an annular seal element which is swellable in response to contact with a selected fluid; a shunt tube flowpath extending through a swellable material of the seal element; and a connection between the flowpath and a shunt tube assembly, the connection being positioned within the swellable material.

Abstract: A well pipe provides for air sparging and soil vapor extraction for groundwater remediation at a single point of entry. An elongated well pipe is provided with a plurality of openings at an upper section and a lower section of the pipe and a packer member for separating the two sections. A conduit for delivering compressed air passes through the packer member into the lower section of the well tube for providing air sparging below the water table level in the ground and a vacuum source is connected to an upper end of the well pipe for drawing vapors from the vadose region in the ground into the pipe through the openings in the upper section of the well tube for transport on to a remediation destination. The conduit is adapted for delivery of remedial enhancing amendments into the surrounding ground through the lower section of the well pipe to further treat the contamination below the ground surface.

Abstract: In some embodiments, an apparatus and a system, as well as a method an article, may operate to move a borehole seal in space with respect to the wall of a borehole while monitoring borehole seal contact quality data, which may comprise borehole seal contact pressure data and acoustic data. Operations may further include adjusting the movement of the borehole seal based on the borehole seal contact quality data. Additional apparatus, systems, and methods are disclosed.

Abstract: A downhole system and related method, the system comprising an annulus sealing device having a flow path therethrough, a first side, a second side, and a sealing element; a latch element positioned at the first side of the annulus sealing device; at least one check valve assembly positioned at the second side of the annulus sealing device, the at least one check valve assembly having an annular seat, a seat-engaging element rotatably movable relative to the annular seat, and a biasing member urging the seat-engaging element toward the annular seat element; a rigid elongate member extending at least partially through the latch element and having a first end, a second end, and an outer surface extending between the first end and the second end; and a fluid communication path between the annular seat and through the latch element at least partially defined by the rigid elongate member.

Abstract: A downhole tool has a mandrel with packing elements. Collars between the packing elements define ports communicating with gaps between the packing elements and the mandrels. Opposing piston housings on the mandrel can move in opposing directions to compress the packing elements against the collars. Each piston housing defines a space with the mandrel and has a second port communicating with the gap. Pistons disposed in the spaces are temporarily affixed thereto. Hydraulic pressure communicated through the mandrel's bore acts against the pistons. While affixed to the piston housings, the pistons move the piston housings toward the packing elements to compress then. When the packing elements set, continued pressure breaks shear pins affixing the pistons to the piston housings so the pistons move and eventually seal fluid communication between the second ports in the pistons and the gaps.

Abstract: A downhole apparatus (10) adapted to be run on a workstring in a well bore. The apparatus has a body (12) including ports (42) and a valve (26) which is rotatable to open and close the ports to selectively allow fluid flow through the body between regions of a well bore above and below the apparatus. The valve is rotated via a gearbox (28) and motor (30) in the apparatus. A sealing arrangement between the valve and body is also described. A method of running the apparatus in a well bore and monitoring pressure above the apparatus in order to control opening and closing of the valve under predetermined conditions is presented.

Abstract: A shunt tube assembly comprises a wellbore tubular, a packing tube, a transport tube, at least one valve configured to provide selective fluid communication between an interior passageway through the transport tube and the packing tube. At least a portion of the transport tube is disposed within the packing tube.

Abstract: A treatment system including a first tubular having at least one port therein. A valve member is disposed with the first tubular and operatively arranged to control fluid flow through the at least one port. A second tubular is disposed radially within the first tubular and terminates at an end opening into an interior passage of the first tubular for enabling a treatment media to be supplied through the second tubular into the first tubular, and through the at least one port when the at least one port is open. A seal assembly is disposed between the first and second tubulars for fluidly sealing an annulus formed between the first and second tubulars from the end of the second tubular. A tool is disposed with the second tubular for controlling operation of the valve member.

Abstract: A downhole retrievable dual directional isolation tool is provided. The down hole tool comprises a mandrel, a compressor concentric with the mandrel, and a packing element disposed around the mandrel, wherein a body section of the packing element is asymmetrical.

Abstract: The present invention relates to a an inflow assembly (1) for controlling fluid flow between a hydrocarbon reservoir (2) and a production casing in a well, comprising a first tubular (4) having an axial extension and at least one inlet (5) and a first wall (6) with at least a first axial channel (7) extending in the first wall from the inlet, a second tubular (8) having a first (9) and a second end (10) and at least one outlet (11), the second tubular being rotatable within the first tubular and having a second wall (12) with at least a second axial channel extending in the second wall from the first end to the outlet. The invention further relates to an assembly for controlling fluid flow between a hydrocarbon reservoir and a production casing in a well. Finally, the present invention relates to a downhole completion comprising a casing string and one or more of the inflow assembly/assemblies according the invention.

Abstract: The invention concerns a unit for a down hole well tool comprising a tool unit comprising at least one first fluid conduit and a return fluid conduit in use forming a well annulus space between the tool unit and the well bore. The tool unit is arranged with at least one piston provided for dividing the well annulus space into at least two well annulus spaces. The communication of fluid between the adjacent well annulus spaces at each side of the piston is controlled by the relative movement between the first fluid conduit and a control element.

Abstract: A bridge plug can be deployed downhole and retrieved using a retrieval tool disposed on jointed or coiled tubing or on another bridge plug. Internally, the bridge plug has a sleeve that is movable on a stem of the plug's tailpiece. When in a first position, the sleeve prevents fluid communication through ports in the stem so that circulated fluid from the retrieval tool can be used to clear debris from the plug during retrieval. When the retrieval tool engages the sleeve in the plug, pulling up on the tool moves the sleeve to an intermediate position in which fluid pressure is equalized across the plug. Further pulling up on the tool locks the sleeve in a further position on the stem so that circulated fluid from the retrieval tool will pass directly to the stem's ports. Movement of the sleeve by the retrieval tool also releases the engaged slips and packing element on the bridge plug's mandrel.

Abstract: A flow back plug, a bridge plug, a ball drop plug and plug with a disintegratable check therein are made from a common subassembly including, in some embodiments, a mandrel, a slips/seal section, a setting assembly and a mule shoe. In other embodiments, the common components are a mandrel, a slips/seal section and a mule shoe. To make the flow back plug, a ball check is placed in the mule shoe. To make the bridge plug, an obstruction is inserted in the mule shoe. To make the ball drop plug, the mule shoe is left unobstructed so any ball dropped in a well seats in a tapered inlet to the mandrel. To make a plug with a disintegratable check, a ball dropped in the well is of a type that disintegrated in frac liquids. The setting assembly includes a setting rod connected to a setting device in the mandrel passage. When the plug is expanded into sealing engagement with a production string, the setting rod pulls out of the setting device leaving a passage through the mandrel and through the setting device.

Abstract: An embodiment of an assembly for setting an inflatable packer within a wellbore comprises a coiled tubing, an inflatable packer to be set in a wellbore, a back pressure valve, and a drain valve operable to allow fluid flow therepast and prevent inadvertent inflation of the inflatable packer.

Abstract: An apparatus and assembly create a seal in a wellbore around a cable or line. The assembly includes a longitudinal body and a swellable portion which comprises a material selected to increase in volume on exposure to at least one triggering fluid. The swellable portion has a formation open to the longitudinal surface of the body which provides a pathway for a cable or line to extend through the swellable portion, and an insert of swellable material. The insert may partly or fully enclose or encapsulate the cable or line. a formation which is open to an outer longitudinal surface of the body.

Abstract: A tubing string assembly for fluid treatment of a wellbore includes substantially pressure holding closures spaced along the tubing string, which each close at least one port through the tubing string wall. The closures are openable by a sleeve drivable through the tubing string inner bore.

Abstract: An apparatus having a body including a plurality of packers and a plurality of ports between the packers. The packers and ports are spaced along a longitudinal axis of the body. The apparatus also includes a control module to obtain a density of a formation fluid and, based on the density, determine a direction to pump fluid from an interval defined by the packers.

Abstract: Apparatus and method for penetrating cement (300) surrounding a tubular (200) cemented to a formation (400). The apparatus comprises a bore (10) through the tubular wall (200), and an intermediate fluid channel (102) in an insert (100) within the bore. An inner sleeve (120) may be disposed on the interior surface of the tubular wall (200). The inner sleeve (120) is movable between a closed position wherein fluid connection between the interior of the tubular and the bore is prevented, and an open position wherein fluid connection between the interior of the tubular and the bore is allowed. An abrasive and/or etching fluid is supplied through the channel (102) to remove cement and/or the insert (100) or piston assembly.

Abstract: A swelling element on a packer has a trough formed on a longitudinal axis. The control line or cable or conduit that needs to run along the string where the packer is mounted is first wrapped in a preferably non-swelling underlayment that can be a loose scroll or have its seam sealed. A swelling cover is placed over the underlayment using a seam that can be longitudinal or spiral to allow rapid deployment. The covering assembly for the control line or conduit is placed in the slot of the swelling element of the packer. The line or cable continues out opposed ends and can be secured to the tubular string with clamps. The control line can be covered with a swelling material and forced into a groove that runs the length of the packer swelling element.

Abstract: A dual packer for at least partially defining a production zone in a wellbore, the dual packer including a packer body having an up-hole side and a down-hole side. A first through bore and a second through bore each extend through the packer body from the up-hole side to the down-hole side. A first piping extends from the down-hole side of the first through bore and includes a perforated sub adjacent the down-hole side of the packer body. A second piping extends from the down-hole side of the second through bore and is communicably connected to the first piping down-hole of the first perforated sub.

Abstract: A circulation valve includes: an outer tubular sleeve telescopically mounted at its end over a tubular mandrel; a fluid passage between sleeve and the mandrel, the fluid passage providing fluid communication between the inner bore of the valve and its outer surface; a dual knife seal assembly to control flow out of the fluid flow path through the fluid passage, the dual knife seal assembly including a first annular knife seal edge and land that seal up when the sleeve and mandrel are in a fully axially compressed position and a second annular knife seal edge and land that seal up when the sleeve and mandrel are pulled into a fully in tension position; and, a J-slot position indexing mechanism including a slot and a key to guide movement of the sleeve and the mandrel between the fully in tension position and the fully compressed position. The circulation valve is employed in a wellbore treatment assembly and methods.

Abstract: A vortex-controlled variable flow resistance device ideal for use in a backpressure tool for advancing drill string in extended reach downhole operations, especially in horizontal wells. The shape, frequency and duration of the pressure waves generated by the device are controlled by the growth and decay of vortices in the vortex chamber(s) of a flow path. The flow path includes a switch, such as a bi-stable fluidic switch, for reversing the direction of the flow in the vortex chamber. The flow path may include multiple vortex chambers, and the device may include multiple flow paths, through which flow may be parallel or sequential. This device generates backpressures of short duration and slower frequencies approaching the resonant frequency of the drill string, which maximizes axial motion in the drill sting and weight on the bit. Additionally, fluid pulses produced by the tool enhance debris removal ahead of the bit.

Abstract: A vortex-controlled variable flow resistance device ideal for use in a backpressure tool for advancing drill string in extended reach downhole operations. The characteristics of the pressure waves generated by the device are controlled by the growth and decay of vortices in the vortex chamber(s) of a flow path. The flow path includes a switch, such as a bi-stable fluidic switch, for reversing the direction of the flow in the vortex chamber. The flow path may include multiple vortex chambers, and the device may include multiple flow paths. A hardened insert in the outlet of the vortex chamber resists erosion. This device generates backpressures of short duration and slower frequencies approaching the resonant frequency of the drill string, which maximizes axial motion in the drill sting and weight on the bit. Additionally, fluid pulses produced by the tool enhance debris removal ahead of the bit.

Abstract: A configurable insert for a downhole tool. The configurable insert can have a body having a bore formed therethrough, at least one shear groove disposed on the body, wherein the body separates at the shear groove when exposed to a predetermined force, applied by a threadably engaged component therewith, at least one shoulder disposed within the bore, the shoulder formed by a transition between a larger inner diameter and a smaller inner diameter of the bore, wherein the shoulder is adapted to receive one or more impediments at least partially within the bore, and one or more threads disposed on an outer surface of the body for connecting the body to a downhole tool.

Abstract: A downhole plug can include a housing having an aperture disposed generally through the center of the housing. A stopper can be disposed in the aperture and adapted to block fluid flow therethrough. The stopper can have a composition of at least two different materials. One or more covers can be at least partially disposed on the stopper, wherein and the stopper can be at least partially encapsulated by the one or more covers. A flow control device can be disposed adjacent the stopper to selectively introduce fluid to at least a portion of the stopper.

Abstract: A swelling element on a packer has a trough formed on a longitudinal axis. The control line or cable or conduit that needs to run along the string where the packer is mounted is first wrapped in a preferably non-swelling underlayment that can be a loose scroll or have its seam sealed. A swelling cover is placed over the underlayment using a seam that can be longitudinal or spiral to allow rapid deployment. The covering assembly for the control line or conduit is placed in the slot of the swelling element of the packer. The line or cable continues out opposed ends and can be secured to the tubular string with clamps. The control line can be covered with a swelling material and forced into a groove that runs the length of the packer swelling element.

Abstract: The application discloses a safety valve including a flapper valve and a packer assembly to be installed in a bore to isolate a first zone from a second zone. Preferably, the safety valve includes a hydraulic conduit bypassing the flapper valve to allow communication therethrough when the valve is closed. Furthermore, the safety valve preferably allows unobstructed passage of tools and fluids therethrough when the flapper valve is open. The application discloses a method to install a safety valve in an existing string of tubing by deploying a packer assembly having an integral safety valve.

Abstract: A swelling element on a packer has a trough formed on a longitudinal axis. The control line or cable or conduit that needs to run along the string where the packer is mounted is first wrapped in a preferably non-swelling underlayment that can be a loose scroll or have its seam sealed. A swelling cover is placed over the underlayment using a seam that can be longitudinal or spiral to allow rapid deployment. The covering assembly for the control line or conduit is placed in the slot of the swelling element of the packer. The line or cable continues out opposed ends and can be secured to the tubular string with clamps. The control line can be covered with a swelling material and forced into a groove that runs the length of the packer swelling element.

Abstract: An apparatus for providing electrical power through a downhole packer comprises a riser nipple engagingly insertable in a passage in the packer; a sleeve surrounding a portion of the riser nipple and slidingly moveable between a cable assembly position and an operational position enabling connection of a cable extending through the packer and the sleeve to an electrical connector; and a retaining nut engageable with the riser nipple capturing the sleeve in the operational position when the retaining nut is engaged with the riser nipple.

Abstract: A dual packer for at least partially defining a production zone in a wellbore, the dual packer including a packer body having an up-hole side and a down-hole side. A first through bore and a second through bore each extend through the packer body from the up-hole side to the down-hole side. A first piping extends from the down-hole side of the first through bore and includes a perforated sub adjacent the down-hole side of the packer body. A second piping extends from the down-hole side of the second through bore and is communicably connected to the first piping down-hole of the first perforated sub.

Abstract: An adjustable depth air sparging well system having a fixed depth or secondary air injection point and an adjustable depth or primary air injection point for injecting compressed air into saturated or groundwater regions of the soil's subsurface to remove volatile contaminants from the soil's subsurface. At least one flow-through air sparge packer which is slidably mounted within the well casing of the air sparging well system allows a user to adjust the depth at which the adjustable depth air injection point is set. The flow through air sparge packer is available in one, two and one half and five foot lengths.

Abstract: An multiple point adjustable depth air sparging well system having a multiple air injection points for injecting compressed air into saturated or groundwater regions of the soil's subsurface to remove volatile contaminants from the soil's subsurface. At plurality of flow-through air sparge packer which are slidably mounted flow-through packers within the well casing of the air sparging well system allows a user to adjust the depths of the air injection points. Each packer has attached thereto a pressure regulator which provides compressed air to one of the multiple air injection points.

Abstract: An apparatus and assembly create a seal in a wellbore around a cable or line. The assembly includes a longitudinal body and a swellable portion which comprises a material selected to increase in volume on exposure to at least one triggering fluid. The swellable portion has a formation open to the longitudinal surface of the body which provides a pathway for a cable or line to extend through the swellable portion, and an insert of swellable material. The insert may partly or fully enclose or encapsulate the cable or line. a formation which is open to an outer longitudinal surface of the body.

Abstract: The present disclosure relates to one or more apparatuses and methods to determine fluid movement within a formation. The apparatus includes a first packer configured to selectively engage a wall of a borehole of the formation, an outlet disposed adjacent to the first packer, wherein the outlet is configured to pump a first fluid therefrom and into the formation, and a detecting tool configured to detect the first fluid within the formation. Movement of the first fluid may be determined based upon the detection of the first fluid within the formation.

Abstract: A swelling element on a packer has a trough formed on a longitudinal axis. The control line or cable or conduit that needs to run along the string where the packer is mounted is first wrapped in a preferably non-swelling underlayment that can be a loose scroll or have its seam sealed. A swelling cover is placed over the underlayment using a seam that can be longitudinal or spiral to allow rapid deployment. The covering assembly for the control line or conduit is placed in the slot of the swelling element of the packer. The line or cable continues out opposed ends and can be secured to the tubular string with clamps. In an alternative embodiment the control line is covered with a swelling material and forced into a groove that runs the length of the packer swelling element.

Abstract: A dual packer for at least partially defining a production zone in a wellbore, the dual packer including a packer body having an up-hole side and a down-hole side. A first through bore and a second through bore each extend through the packer body from the up-hole side to the down-hole side. A first piping extends from the down-hole side of the first through bore and includes a perforated sub adjacent the down-hole side of the packer body. A second piping extends from the down-hole side of the second through bore and is communicably connected to the first piping down-hole of the first perforated sub.

Abstract: The invention concerns a unit for a down hole well tool comprising a tool unit comprising at least one first fluid conduit and a return fluid conduit in use forming a well annulus space between the tool unit and the well bore. The tool unit is arranged with at least one piston provided for dividing the well annulus space into at least two well annulus spaces. The communication of fluid between the adjacent well annulus spaces at each side of the piston is controlled by the relative movement between the first fluid conduit and a control element.

Abstract: In one aspect, a passive flow control device for controlling flow of a fluid is provided, which device in one configuration include a longitudinal member configured to receive fluid radially along a selected length of the longitudinal member, the longitudinal member including flow restrictions configured to cause a pressure drop across the radial direction of the longitudinal member. In another aspect, a method of completing a wellbore is provided, which method in one embodiment may include providing a flow control device that includes a tubular with a first set of fluid flow passages and at least one member with a second set of fluid passages placed outside the tubular, wherein the first and second set of passages are offset along a longitudinal direction and the member is configured to receive a fluid along the radial direction; placing the flow control device at a selected location a wellbore; and allowing a fluid flow between the formation and the flow control device.

Abstract: Apparatus and method are provided for diverting treatment fluids in wells. Sliding sleeves or valves are sequentially opened by dropping balls that may be of uniform size. Opening of one valve moves a collet into position such that the same size ball can be used to open a second valve. Any selected number of valves can be opened with the same size balls. Systems using the valves are also disclosed, along with methods for operating.

Abstract: A swelling element on a packer has a trough formed on a longitudinal axis. The control line or cable or conduit that needs to run along the string where the packer is mounted is first wrapped in a preferably non-swelling underlayment that can be a loose scroll or have its seam sealed. A swelling cover is placed over the underlayment using a seam that can be longitudinal or spiral to allow rapid deployment. The covering assembly for the control line or conduit is placed in the slot of the swelling element of the packer. The line or cable continues out opposed ends and can be secured to the tubular string with clamps. The control line can also be covered with a swelling material and forced into a groove that runs the length of the packer swelling element.

Abstract: Apparatus and method for a providing a completion assembly for running at an end of a completion string which provides a remotely operable tubing mounted valve used to control the flow of fluids through the tubing in hostile well conditions. The tubing mounted completion assembly has a tubular body for connection in the string below a production packer with a through bore from a first inlet and a first outlet coaxially aligned with the string; a downhole electronic actuating mechanism, a downhole hydraulic pump and a hydraulically operated ball valve member. The actuating mechanism operates the hydraulic pump to provide a hydraulic control line to control movement the valve member from a first position, where the member is open and a through bore is created between the inlet and outlet of the assembly, to a second position, where the valve seals the throughbore and, finally, back to the first position.

Abstract: Expandable apparatus for use in subterranean boreholes include a tubular body having at least one opening and at least one member positioned within the at least one opening. The member is configured to move between a retracted position and an extended position. A sleeve member including a constricted portion may be disposed in the tubular body and may selectively retain the at least one member in the retracted position. In some embodiments, the sleeve member may be biased in an initial position. Methods of moving a member of an expandable apparatus include repeating retracting and expanding of the member. Methods of triggering an expandable apparatus include forming a constriction in a fluid flow path extending through a sleeve member to move the sleeve member in a downhole direction responsive to fluid flow.