A method for remotely signalling a downhole assembly comprising one or more downhole tools includes operating a choke arrangement configured to control production fluid flow from a wellbore to produce a first pressure signature in the fluid flow, the first pressure signature defining a trigger signal for the one or more downhole tools of the downhole assembly. The first pressure signature comprises at least a first pressure signal and a second pressure signal in the production fluid flow in the downhole assembly. Operating the choke arrangement to produce a second pressure signature in the production fluid flow in the downhole assembly at a predetermined time period following the first pressure signature, the second pressure signature defining a command signal for initiating operation of a predetermined one or more of the downhole tools of the downhole assembly.
E21B 47/18 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the well fluid
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
An anchoring apparatus for use in a wellbore, comprises at least one movable wall engaging member for engaging a wall of a wellbore, wherein the at least one movable wall engaging member is movable from a retracted position to an expanded position to engage the wall, and from the expanded position to a retracted position to disengage the wall. Provision of one or more wall engaging members being movable from an expanded position to a retracted position allows the anchoring apparatus to be retrieved from the wellbore, and in particular, from an open hole.
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
3.
METHOD AND SYSTEM FOR REMOTELY SIGNALLING A DOWNHOLE ASSEMBLY COMPRISING ONE OR MORE DOWNHOLE TOOL
A method for remotely signalling a downhole assembly comprising one or more downhole tools includes operating a choke arrangement configured to control production fluid flow from a wellbore to produce a first pressure signature in the fluid flow, the first pressure signature defining a trigger signal for the one or more downhole tools of the downhole assembly. The first pressure signature comprises at least a first pressure signal and a second pressure signal in the production fluid flow in the downhole assembly. Operating the choke arrangement to produce a second pressure signature in the production fluid flow in the downhole assembly at a predetermined time period following the first pressure signature, the second pressure signature defining a command signal for initiating operation of a predetermined one or more of the downhole tools of the downhole assembly.
E21B 47/18 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the well fluid
E21B 47/11 - Locating fluid leaks, intrusions or movements using tracersLocating fluid leaks, intrusions or movements using radioactivity
4.
METHOD AND SYSTEM FOR REMOTELY SIGNALLING A DOWNHOLE ASSEMBLY COMPRISING ONE OR MORE DOWNHOLE TOOL
A method for remotely signalling a downhole assembly comprising one or more downhole tools includes operating a choke arrangement configured to control production fluid flow from a wellbore to produce a first pressure signature in the fluid flow, the first pressure signature defining a trigger signal for the one or more downhole tools of the downhole assembly. The first pressure signature comprises at least a first pressure signal and a second pressure signal in the production fluid flow in the downhole assembly. Operating the choke arrangement to produce a second pressure signature in the production fluid flow in the downhole assembly at a predetermined time period following the first pressure signature, the second pressure signature defining a command signal for initiating operation of a predetermined one or more of the downhole tools of the downhole assembly.
E21B 47/18 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the well fluid
A screen assembly, such as a downhole/sand screen assembly, comprising first and second screen portions or screens longitudinally coupled together, wherein there is provided a fluid flow path between the first and second screen portions or screen. Optionally, the first and second sleeves are coupled or connected by a centraliser or further sleeve or screen, and/or optionally by or via first and second support ring.
A downhole apparatus comprises a housing, a seat mounted in the housing and configured to receive an object such that the object may engage and axially move the seat to operate the downhole apparatus, and a moveable barrier located on one axial side of the seat such that when an object is engaged with the seat a volume is defined between the object and the moveable barrier, wherein the moveable barrier permits said volume to be moved within the apparatus to allow the object to axially move the seat.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 33/129 - PackersPlugs with mechanical slips for hooking into the casing
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
Downhole apparatus is provided for location in a fluid-filled bore, such as a well bore. The apparatus comprises a tubular body comprising a plurality of cylindrical chambers for containing a compressible substance, and pistons mounted in the chambers. A lock arrangement is provided and has a locking configuration for retaining the pistons in the chambers and an unlocked configuration in which bore fluid pressure may translate the pistons through the chambers.
E21B 34/08 - Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
E21B 23/06 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
An apparatus for use in a well borehole packing operation takes the form of a downhole packer and comprises a body and a seal member. In use, the apparatus is run into a borehole as part of a downhole completion assembly. On reaching the desired location, the apparatus is activated to urge the seal member into sealing engagement with the borehole, and thereby isolate an annular region between the apparatus and the borehole. A conduit is disposed within the body and is offset from a central longitudinal axis of the apparatus, the conduit configured to transport a borehole packing material, such as gravel slurry, through the apparatus.
A completion system apparatus having a body comprising a throughbore and lateral flow ports for providing access through a wall of the body and a valve arrangement including a first, uphole, valve assembly and a second, downhole, valve assembly. The valve arrangement is configurable between a first, open, configuration in which passage of fluid through the axial throughbore is permitted and a second, activated, configuration, the valve arrangement in the second, activated, configuration preventing passage of fluid in the first, downhole, direction so as to direct the fluid through the lateral flow ports while permitting the passage of fluid through the apparatus in a second, uphole, direction so as to permit return passage of the fluid through the apparatus. A bypass arrangement is configured to permit fluid travelling in the second direction to bypass the first valve assembly.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
A downhole apparatus comprises a piston mounted within a bore and being reconfigurable from a lock configuration to an unlock configuration in response to a pressure sequence applied within the bore. When the piston is in its lock configuration, a lock is supported by the piston such that the lock partially extends into the bore and engages a lock profile of the piston to restrict movement of the piston in a first direction towards its unlock configuration. In response to a first event of the pressure sequence, the piston is moveable in a second direction to desupport the lock and permit the lock to be wholly received into the bore and allow the piston to move in the second direction towards its unlock configuration in response to a subsequent event of the pressure sequence.
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
E21B 34/08 - Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
An apparatus comprises perforating guns, bypass, and isolator mechanism. The first gun fires upon receipt of a first pressure signal delivered from a first axial side of the first gun. The second perforating gun is mounted on a second axial side of the first perforating gun, and fires upon receipt of a second pressure signal delivered from the first axial side of the first perforating gun. The bypass extends from the first axial side of the first gun to the second gun for communicating the second pressure signal to the second gun. The isolator mechanism is configurable between a first configuration in which the bypass is isolated from receiving a pressure signal to the second perforating gun, and a second configuration in which the bypass is permitted to receive a pressure signal. The isolator mechanism is reconfigurable from the first to the second configuration after the first gun has fired.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
Some examples of the present disclosure relate to a method for washing an annulus that at least partially surrounds a casing in a well. The method comprises locating a tool inside a wellbore casing, and flowing a washing fluid from an injection aperture on the tool and into the annulus via a first casing aperture in the casing. An inflow region of the casing is created having a reduced pressure relative to the annulus, and the method involves flowing the washing fluid from the annulus and into the inflow region of the casing through a second casing aperture in the casing.
E21B 33/13 - Methods or devices for cementing, for plugging holes, crevices or the like
E21B 37/00 - Methods or apparatus for cleaning boreholes or wells
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
A downhole fluid control apparatus comprises first and second conduits for providing communication between a pressure source and a downhole device, and a valve provided within a housing and configurable between a first configuration in which the first and second conduits are in pressure communication via the valve, and a second configuration in which the first and second conduits are isolated from each other. The apparatus further comprises an actuator for operating the valve. The actuator is in pressure communication with the first and second conduits and with an ambient region external of the apparatus such that when the pressure within each of the first and second conduits is lower than the ambient pressure the valve is configured in its first configuration, and when the pressure within at least one of the first and second conduits exceeds the ambient pressure the valve is configured in its second configuration.
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
A downhole apparatus (10) comprises a landing arrangement (12) comprising a collet (18) and an actuation arrangement (14) comprising an actuation piston (22). The actuation arrangement (14) is operable to reconfigure the downhole apparatus (10) from the first configuration to a second configuration in which the landing arrangement (12) defines a radially retracted position, permitting the apparatus (10) to be run through a seat (S).
E21B 23/02 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for locking the tools or the like in landing nipples or in recesses between adjacent sections of tubing
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
15.
Apparatus and method for downhole data acquisition and or monitoring
An apparatus (10) for downhole data acquisition and/or monitoring is configured to be disposed within a completion (12) and comprises a hanger (36) configured to latch into a control line spool (38), a retrofit valve (40) for location within the subsurface safety valve (16) of the completion (12), and a sensing arrangement (42) including an optical fiber line (44). In use, the apparatus (10) is configured to be run into the completion (12) and is operable to provide data acquisition and/or monitoring capability in the well, including up or near total depth and in particular but not exclusively in the region of the well subjected to an intervention operation, such as a chemical injection operation.
E21B 34/02 - Valve arrangements for boreholes or wells in well heads
E21B 47/135 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range using light waves, e.g. infrared or ultraviolet waves
E21B 47/085 - Measuring diameters or related dimensions at the borehole using radiant means, e.g. acoustic, radioactive or electromagnetic
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
Downhole apparatus is provided for location in a fluid-filled bore, such as a well bore. The apparatus comprises a tubular body comprising a plurality of cylindrical chambers for containing a compressible substance, and pistons mounted in the chambers. A lock arrangement is provided and has a locking configuration for retaining the pistons in the chambers and an unlocked configuration in which bore fluid pressure may translate the pistons through the chambers.
E21B 34/08 - Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
E21B 34/00 - Valve arrangements for boreholes or wells
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
Downhole apparatus is provided for location in a fluid-filled bore, such as a well bore. The apparatus comprises a tubular body comprising a plurality of cylindrical chambers for containing a compressible substance, and pistons mounted in the chambers. A lock arrangement is provided and has a locking configuration for retaining the pistons in the chambers and an unlocked configuration in which bore fluid pressure may translate the pistons through the chambers.
E21B 34/08 - Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 34/00 - Valve arrangements for boreholes or wells
A completion system apparatus (10) having a body (12) comprising a throughbore (14) and lateral flow ports (16) for providing access through a wall (18) of the body (12) and a valve arrangement (20) including a first, uphole, valve assembly (22) and a second, downhole, valve assembly (24). The valve arrangement (20) is configurable between a first, open, configuration in which passage of fluid through the axial throughbore (14) is permitted and a second, activated, configuration, the valve arrangement (20) in the second, activated, configuration preventing passage of fluid in the first, downhole, direction so as to direct the fluid through the lateral flow ports (16) while permitting the passage of fluid through the apparatus (10) in a second, uphole, direction so as to permit return passage of the fluid through the apparatus (10). A bypass arrangement is configured to permit fluid travelling in the second direction to bypass the first valve assembly (22).
Some examples of the present disclosure relate to a method for washing an annulus that at least partially surrounds a casing in a well. The method comprises locating a tool inside a wellbore casing, and flowing a washing fluid from an injection aperture on the tool and into the annulus via a first casing aperture in the casing. An inflow region of the casing is created having a reduced pressure relative to the annulus, and the method involves flowing the washing fluid from the annulus and into the inflow region of the casing through a second casing aperture in the casing.
Some examples of the present disclosure relate to a method for washing an annulus that at least partially surrounds a casing in a well. The method comprises locating a tool inside a wellbore casing, and flowing a washing fluid from an injection aperture on the tool and into the annulus via a first casing aperture in the casing. An inflow region of the casing is created having a reduced pressure relative to the annulus, and the method involves flowing the washing fluid from the annulus and into the inflow region of the casing through a second casing aperture in the casing.
A screen assembly, such as a downhole/sand screen assembly, comprising first and second screen portions or screens longitudinally coupled together, wherein there is provided a fluid flow path between the first and second screen portions or screen. Optionally, the first and second sleeves are coupled or connected by a centralizer or further sleeve or screen, and/or optionally by or via first and second support ring.
A downhole apparatus (10) comprises a housing (12), a seat (20) mounted in the housing (12) and configured to receive an object (22) such that the object may engage and axially move the seat (20) to operate the downhole apparatus (10), and a moveable barrier (32) located on one axial side of the seat (20) such that when an object (22) is engaged with the seat (20) a volume (34) is defined between the object (22) and the moveable barrier (32), wherein the moveable barrier permits said volume (34) to be moved within the apparatus to allow the object to axially move the seat.
A downhole apparatus (10) comprises a housing (12), a seat (20) mounted in the housing (12) and configured to receive an object (22) such that the object may engage and axially move the seat (20) to operate the downhole apparatus (10), and a moveable barrier (32) located on one axial side of the seat (20) such that when an object (22) is engaged with the seat (20) a volume (34) is defined between the object (22) and the moveable barrier (32), wherein the moveable barrier permits said volume (34) to be moved within the apparatus to allow the object to axially move the seat.
A downhole artificial lift system comprises a production string for communicating fluid from a downhole location towards surface, a pump arrangement in communication with the production string for pumping fluid along the production string towards surface, and a gas lift arrangement deployed within the production string for delivering a lift gas into the production string.
A downhole fluid control apparatus (26) comprises first and second conduits (30, 32) for providing communication between a pressure source and a downhole device, and a valve (44) provided within a housing and configurable between a first configuration in which the first and second conduits are in pressure communication via the valve, and a second configuration in which the first and second conduits are isolated from each other. The apparatus further comprises an actuator (46) for operating the valve. The actuator is in pressure communication with the first and second conduits and with an ambient region external of the apparatus such that when the pressure within each of the first and second conduits is lower than the ambient pressure the valve is configured in its first configuration, and when the pressure within at least one of the first and second conduits exceeds the ambient pressure the valve is configured in its second configuration.
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
F16K 31/122 - Operating meansReleasing devices actuated by fluid the fluid acting on a piston
F16K 7/06 - Diaphragm cut-off apparatus, e.g. with a member deformed, but not moved bodily, to close the passage with tubular diaphragm constrictable by external radial force by means of a screw-spindle, cam, or other mechanical means
F16K 27/02 - Construction of housingsUse of materials therefor of lift valves
F16K 11/06 - Multiple-way valves, e.g. mixing valvesPipe fittings incorporating such valvesArrangement of valves and flow lines specially adapted for mixing fluid with all movable sealing faces moving as one unit comprising only sliding valves
A downhole fluid control apparatus (26) comprises first and second conduits (30, 32) for providing communication between a pressure source and a downhole device, and a valve (44) provided within a housing and configurable between a first configuration in which the first and second conduits are in pressure communication via the valve, and a second configuration in which the first and second conduits are isolated from each other. The apparatus further comprises an actuator (46) for operating the valve. The actuator is in pressure communication with the first and second conduits and with an ambient region external of the apparatus such that when the pressure within each of the first and second conduits is lower than the ambient pressure the valve is configured in its first configuration, and when the pressure within at least one of the first and second conduits exceeds the ambient pressure the valve is configured in its second configuration.
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
F16K 7/06 - Diaphragm cut-off apparatus, e.g. with a member deformed, but not moved bodily, to close the passage with tubular diaphragm constrictable by external radial force by means of a screw-spindle, cam, or other mechanical means
F16K 11/06 - Multiple-way valves, e.g. mixing valvesPipe fittings incorporating such valvesArrangement of valves and flow lines specially adapted for mixing fluid with all movable sealing faces moving as one unit comprising only sliding valves
F16K 27/02 - Construction of housingsUse of materials therefor of lift valves
F16K 31/122 - Operating meansReleasing devices actuated by fluid the fluid acting on a piston
A screen assembly, such as a downhole/sand screen assembly, comprising first and second screen portions or screens longitudinally coupled together, wherein there is provided a fluid flow path between the first and second screen portions or screen. Optionally, the first and second sleeves are coupled or connected by a centralizer or further sleeve or screen, and/or optionally by or via first and second support ring.
An oil or gas well actuator (1) assembly comprising a fixed member (10), an actuating member (30) being moveable axially with respect to the fixed member, with open-ended recesses containing canted coil springs (40) on e.g. the fixed member and a radially extending shoulder (30s) on the actuating member which adapted to engage a canted coil spring within a recess (20). A support member (50) is adapted to cover open ends of the recesses and moves into different axial positions with respect to the recesses to uncover open ends of different recesses in the different axial positions of the support member. Expansion of a canted coil spring (40) from an open end of a recess engages with the shoulder (30s) to restrict movement of the actuating member (30) at indexed positions. When the actuating member (30) moves relative to the support member direction, the support member (50) retains its position relative to the canted coil spring.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
A downhole valve assembly comprises a sleeve concentric with a housing and movable relative to a port through the housing to control flow of fluid through the port. A sensor assembly provides indicates the relative positions of the sleeve and housing, and comprises first and second sensors on e.g. the housing which detect markers on e.g. the sleeve. The sensor outputs are produced by processing (e.g. combining, integrating, summing, subtracting or otherwise processing) the signal components of each of the first and second sensors to correct for misalignment of the sleeve with the housing. The sensor output provides position information for more than one plane, and the output signal therefore allows for correction of errors in the position information arising from misalignment of the sleeve with the housing.
A downhole apparatus comprises a piston mounted within a bore and being reconfigurable from a lock configuration to an unlock configuration in response to a pressure sequence applied within the bore. When the piston is in its lock configuration, a lock is supported by the piston such that the lock partially extends into the bore and engages a lock profile of the piston to restrict movement of the piston in a first direction towards its unlock configuration. In response to a first event of the pressure sequence, the piston is moveable in a second direction to desupport the lock and permit the lock to be wholly received into the bore and allow the piston to move in the second direction towards its unlock configuration in response to a subsequent event of the pressure sequence.
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 34/08 - Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
An antenna 200, 300, 400 and associated systems 1400, 1500 and methods of use of an antenna 200, 300, 400 in downhole communication or detection. The antenna 200, 300, 400 comprises a plurality of planar substrates and wherein at least two of the plurality of planar substrates each comprise at least one conductive coil 830A-J, and the plurality of planar substrates are spaced apart. The system comprises a downhole arrangement defining a throughbore, a primary antenna and a secondary antenna. At least one of the primary and secondary antennae comprise a plurality of planar substrates. At least two of the plurality of planar substrates each comprise at least one conductive coil. The plurality of planar substrates are spaced apart.
G01V 3/28 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with magnetic or electric fields produced or modified either by the surrounding earth formation or by the detecting device using induction coils
E21B 47/13 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range
H01Q 7/00 - Loop antennas with a substantially uniform current distribution around the loop and having a directional radiation pattern in a plane perpendicular to the plane of the loop
An antenna 200, 300, 400 and associated systems 1400, 1500 and methods of use of an antenna 200, 300, 400 in downhole communication or detection. The antenna 200, 300, 400 comprises a plurality of planar substrates and wherein at least two of the plurality of planar substrates each comprise at least one conductive coil 830A-J, and the plurality of planar substrates are spaced apart. The system comprises a downhole arrangement defining a throughbore, a primary antenna and a secondary antenna. At least one of the primary and secondary antennae comprise a plurality of planar substrates. At least two of the plurality of planar substrates each comprise at least one conductive coil. The plurality of planar substrates are spaced apart.
H01Q 1/38 - Structural form of radiating elements, e.g. cone, spiral, umbrella formed by a conductive layer on an insulating support
E21B 47/13 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range
H01Q 7/00 - Loop antennas with a substantially uniform current distribution around the loop and having a directional radiation pattern in a plane perpendicular to the plane of the loop
A subsea connector system (10) for providing a connection with a subsea well component comprises a latch assembly (14) defining a through bore and a latch member (18) mounted on the latch assembly. A mandrel (20) extends through said bore of the latch assembly, wherein the mandrel and the latch assembly are axially and rotatably moveable relative to each other in a predefined relative movement sequence to operate the latch member and configure the connector system between connected and disconnected configurations. The connector system also comprises a conveyance connector (22) for providing a connection between a conveyance member (24) and the mandrel such that a conveyance member may permit an axial movement component of the predefined movement sequence. A rotation interface (26) is mounted on one of the mandrel and the latch assembly such that a subsea manipulator may permit a rotational movement component of the predefined relative movement sequence.
E21B 29/12 - Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windowsDeforming of pipes in boreholes or wellsReconditioning of well casings while in the ground specially adapted for underwater installations
E21B 33/038 - Connectors used on well heads, e.g. for connecting blow-out preventer and riser
E21B 41/04 - Manipulators for underwater operations, e.g. temporarily connected to well heads
B66C 1/42 - Gripping members engaging only the external or internal surface of the articles
E21B 47/10 - Locating fluid leaks, intrusions or movements
E21B 19/00 - Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrickApparatus for feeding the rods or cables
A releasable connector apparatus comprises a connector mandrel (18) to be coupled to a conveyance member (14) and a connector housing (22) to be coupled with a downhole tool (10). A socket (20) is defined within the connector housing (22) for receiving the connector mandrel (18). A latch arrangement (34) is operable within the socket and comprises a latch member (64), wherein the latch arrangement is moveable relative to the connector housing between a connect position in which the latch member is locked relative to the connector mandrel to prevent removal of the connector mandrel from the socket, and a disconnect position in which the latch member is unlocked relative to the connector mandrel to permit removal of the connector mandrel from the socket. A cavity (36) is defined within the connector housing (22), wherein the cavity is sealingly isolated from the socket (20). An actuator (40) is mounted within the cavity and is coupled to the latch arrangement (34), wherein the actuator (40) is moveable relative to the housing (22) between a first position in which the latch arrangement is in its connect position, and a second position in which the latch arrangement is in its disconnect position.
A releasable connector apparatus comprises a connector mandrel (18) to be coupled to a conveyance member (14) and a connector housing (22) to be coupled with a downhole tool (10). A socket (20) is defined within the connector housing (22) for receiving the connector mandrel (18). A latch arrangement (34) is operable within the socket and comprises a latch member (64), wherein the latch arrangement is moveable relative to the connector housing between a connect position in which the latch member is locked relative to the connector mandrel to prevent removal of the connector mandrel from the socket, and a disconnect position in which the latch member is unlocked relative to the connector mandrel to permit removal of the connector mandrel from the socket. A cavity (36) is defined within the connector housing (22), wherein the cavity is sealingly isolated from the socket (20). An actuator (40) is mounted within the cavity and is coupled to the latch arrangement (34), wherein the actuator (40) is moveable relative to the housing (22) between a first position in which the latch arrangement is in its connect position, and a second position in which the latch arrangement is in its disconnect position.
An apparatus for use in a well borehole packing operation takes the form of a downhole packer and comprises a body and a seal member. In use, the apparatus is run into a borehole as part of a downhole completion assembly. On reaching the desired location, the apparatus is activated to urge the seal member into sealing engagement with the borehole, and thereby isolate an annular region between the apparatus and the borehole. A conduit is disposed within the body and is offset from a central longitudinal axis of the apparatus, the conduit configured to transport a borehole packing material, such as gravel slurry, through the apparatus.
A wellbore injection system comprises a tubing hanger mountable within a wellbore tubular, an injection conduit supported by the tubing hanger to extend into the wellbore tubular, and an injection valve mountable within the wellbore tubular and arranged in fluid communication with the injection conduit. The injection valve is removable from the wellbore tubular independently of the tubing hanger and injection conduit.
An apparatus (10) for downhole data acquisition and/or monitoring is configured to be disposed within a completion (12) and comprises a hanger (36) configured to latch into a control line spool (38), a retrofit valve (40)for location within the subsurface safety valve (16)of the completion (12), and a sensing arrangement (42) including an optical fibre line (44). In use, the apparatus (10)is configured to be run into the completion (12)and is operable to provide data acquisition and/or monitoring capability in the well, including up or near total depth and in particular but not exclusively in the region of the well subjected to an intervention operation, such as a chemical injection operation.
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
A valve assembly comprises an actuation fluid inlet, an actuation fluid outlet and a valve member moveable between a closed position in which the actuation fluid outlet is closed, and an open position in which the actuation fluid outlet is opened. A locking arrangement is provided for locking the valve member in its closed position, wherein the locking arrangement is operable in response to a first predetermined fluid pressure event associated with at least the actuation fluid inlet to release the locking arrangement to permit the valve member to be moved to its open position in response to a second subsequent predetermined fluid pressure event associated with at least the actuation fluid inlet.
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
E21B 34/00 - Valve arrangements for boreholes or wells
40.
DOWNHOLE SLIP APPARATUS FOR BOREHOLES OF SMALLER AND OF LARGER DIAMETER
A downhole slip apparatus that includes a radially extendable slip assembly (20). The radially extendable slip assembly (20) including a primary slip arrangement (40) and a secondary slip arrangement (45). The downhole slip apparatus is arranged such that during a first phase of operation the primary (40) and secondary (45) slip arrangements are radially extendable simultaneously from a retracted configuration towards and/or into a first extended configuration. The downhole slip apparatus is also arranged such that during a subsequent second phase of operation the secondary slip arrangement (45) is radially extendable relative to the primary slip arrangement (40) towards and/or into a second extended configuration.
A downhole slip apparatus that includes a radially extendable slip assembly (20). The radially extendable slip assembly (20) including a primary slip arrangement (40) and a secondary slip arrangement (45). The downhole slip apparatus is arranged such that during a first phase of operation the primary (40) and secondary (45) slip arrangements are radially extendable simultaneously from a retracted configuration towards and/or into a first extended configuration. The downhole slip apparatus is also arranged such that during a subsequent second phase of operation the secondary slip arrangement (45) is radially extendable relative to the primary slip arrangement (40) towards and/or into a second extended configuration.
A downhole slip apparatus that includes a radially extendable slip assembly. The radially extendable slip assembly including a primary slip arrangement and a secondary slip arrangement. The downhole slip apparatus is arranged such that during a first phase of operation the primary and secondary slip arrangements are radially extendable simultaneously from a retracted configuration towards and/or into a first extended configuration. The downhole slip apparatus is also arranged such that during a subsequent second phase of operation the secondary slip arrangement is radially extendable relative to the primary slip arrangement towards and/or into a second extended configuration.
An anchoring apparatus (110) for use in a wellbore, comprises at least one movable wall engaging member (120) for engaging a wall of a wellbore, wherein the at least one movable wall engaging member (120) is movable from a retracted position to an expanded position to engage the wall, and from the expanded position to a retracted position to disengage the wall. Provision of one or more wall engaging members (120) being movable from an expanded position to a retracted position allows the anchoring apparatus to be retrieved from the wellbore, and in particular, from an open hole.
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
A downhole artificial lift system (10) comprises a production string (18) for communicating fluid from a downhole location towards surface, a pump arrangement (14) in communication with the production string for pumping fluid along the production string towards surface, and a gas lift arrangement (10) deployed within the production string for delivering a lift gas into the production string.
A downhole artificial lift system (10) comprises a production string (18) for communicating fluid from a downhole location towards surface, a pump arrangement (14) in communication with the production string for pumping fluid along the production string towards surface, and a gas lift arrangement (10) deployed within the production string for delivering a lift gas into the production string.
A downhole pressure operated apparatus comprises a piston member mounted within a piston bore and being reconfigurable from a lock configuration to an unlock configuration in response to a pressure sequence applied within the piston bore, wherein the piston member comprises a lock profile. A lock member is arranged in a cavity which opens into the piston bore, wherein when the piston member is in its lock configuration the lock member is supported by the piston member such that the lock member partially extends into the piston bore and engages the lock profile of the piston member to restrict movement of the piston member in a first direction towards its unlock configuration. In response to a first pressure event of the pressure sequence the piston member is moveable in a second direction to desupport the lock member and permit said lock member to be wholly received into the piston bore and allow the piston member to move in the second direction towards its unlock configuration in response to a subsequent second pressure event of the pressure sequence.
A downhole pressure operated apparatus comprises a piston member mounted within a piston bore and being reconfigurable from a lock configuration to an unlock configuration in response to a pressure sequence applied within the piston bore, wherein the piston member comprises a lock profile. A lock member is arranged in a cavity which opens into the piston bore, wherein when the piston member is in its lock configuration the lock member is supported by the piston member such that the lock member partially extends into the piston bore and engages the lock profile of the piston member to restrict movement of the piston member in a first direction towards its unlock configuration. In response to a first pressure event of the pressure sequence the piston member is moveable in a second direction to desupport the lock member and permit said lock member to be wholly received into the piston bore and allow the piston member to move in the second direction towards its unlock configuration in response to a subsequent second pressure event of the pressure sequence.
A work string assembly for an oil or gas well has a first and second tubulars, and a torque limiting device connected in the work string. The torque limiting device has a body with an axial bore and two interconnected members that can disconnect to be relatively rotatable. The interconnected members can be repeatedly re-engageable when the torque levels drop below a torque threshold value, or can be connected by a frangible member that is broken when the interconnected members disconnect. A selectively actuable circulation port provided in the string adjacent to and above the torque limiting device allows the annulus between the work string and the casing to be flushed with fluid from the port.
A subsea connector system (10) for providing a connection with a subsea well component comprises a latch assembly (14) defining a through bore and a latch member (18) mounted on the latch assembly. A mandrel (20) extends through said bore of the latch assembly, wherein the mandrel and the latch assembly are axially and rotatably moveable relative to each other in a predefined relative movement sequence to operate the latch member and configure the connector system between connected and disconnected configurations. The connector system also comprises a conveyance connector (22) for providing a connection between a conveyance member (24) and the mandrel such that a conveyance member may permit an axial movement component of the predefined movement sequence. A rotation interface (26) is mounted on one of the mandrel and the latch assembly such that a subsea manipulator may permit a rotational movement component of the predefined relative movement sequence.
A subsea connector system (10) for providing a connection with a subsea well component comprises a latch assembly (14) defining a through bore and a latch member (18) mounted on the latch assembly. A mandrel (20) extends through said bore of the latch assembly, wherein the mandrel and the latch assembly are axially and rotatably moveable relative to each other in a predefined relative movement sequence to operate the latch member and configure the connector system between connected and disconnected configurations. The connector system also comprises a conveyance connector (22) for providing a connection between a conveyance member (24) and the mandrel such that a conveyance member may permit an axial movement component of the predefined movement sequence. A rotation interface (26) is mounted on one of the mandrel and the latch assembly such that a subsea manipulator may permit a rotational movement component of the predefined relative movement sequence.
E21B 29/12 - Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windowsDeforming of pipes in boreholes or wellsReconditioning of well casings while in the ground specially adapted for underwater installations
E21B 33/038 - Connectors used on well heads, e.g. for connecting blow-out preventer and riser
E21B 47/10 - Locating fluid leaks, intrusions or movements
E21B 19/00 - Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrickApparatus for feeding the rods or cables
A method for injection of a lift gas into a wellbore production string comprises determining production pressure within the production string, and autonomously controlling a variable orifice gas lift valve in accordance with the determined production pressure, wherein the variable orifice gas lift valve controls the injection flow rate of the lift gas into the production string. A valve comprises a housing defining an inlet, an outlet and a flow path therebetween, and a valve member linearly moveable within the housing between first and second positions to vary flow along the flow path, wherein the valve member is prevented from rotation relative to the housing during linear movement between the first and second positions. The valve further includes a rotary drive and a transmission arrangement interposed between the rotary drive and the valve member for converting rotation of the rotary drive to linear movement of the valve member.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
A method for injection of a lift gas into a wellbore production string comprises determining production pressure within the production string, and autonomously controlling a variable orifice gas lift valve in accordance with the determined production pressure, wherein the variable orifice gas lift valve controls the injection flow rate of the lift gas into the production string. A valve comprises a housing defining an inlet, an outlet and a flow path therebetween, and a valve member linearly moveable within the housing between first and second positions to vary flow along the flow path, wherein the valve member is prevented from rotation relative to the housing during linear movement between the first and second positions. The valve further includes a rotary drive and a transmission arrangement interposed between the rotary drive and the valve member for converting rotation of the rotary drive to linear movement of the valve member.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
A wellbore injection system comprises a tubing hanger mountable within a wellbore tubular, an injection conduit supported by the tubing hanger to extend into the wellbore tubular, and an injection valve mountable within the wellbore tubular and arranged in fluid communication with the injection conduit. The injection valve is removable from the wellbore tubular independently of the tubing hanger and injection conduit.
A valve assembly (10) comprises a flow path extending from an assembly inlet (20) to an assembly outlet (22), a valve (24a / 26a) arranged within the flow path and a filter assembly arranged within the flow path between the assembly inlet and the valve. The filter assembly comprises a filter chamber defining a particle settlement region, a filter chamber inlet for facilitating inflow of a fluid into the chamber, and a filter chamber outlet for facilitating outflow of fluid from the chamber towards the valve, wherein the filter chamber outlet includes a particle filter.
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
F16K 1/00 - Lift valves, i.e. cut-off apparatus with closure members having at least a component of their opening and closing motion perpendicular to the closing faces
A tubular stabbing guide (10) used to assist in the location of a pin end connection of a tubular in a box end connection (14) of another tubular forming the upper end of a drill string held and supported from the drill floor (16) of a rig. The stabbing guide (10) has a mounting frame (22) for location on the drill floor (16) and funnel-forming members (32) mounted on the frame (22). In use, the funnel-forming members (32) are moved from a retracted location spaced from the box end connection (14) to an active location surrounding the box end connection (14), such that the funnel-forming members (32) form a funnel for guiding the pin end connection into the box end connection (14).
E21B 19/24 - Guiding or centralising devices for drilling rods or pipes
E21B 19/00 - Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrickApparatus for feeding the rods or cables
E21B 19/16 - Connecting or disconnecting pipe couplings or joints
E21B 41/00 - Equipment or details not covered by groups
E21B 29/00 - Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windowsDeforming of pipes in boreholes or wellsReconditioning of well casings while in the ground
An anchoring apparatus (110) for use in a wellbore, comprises at least one movable wall engaging member (120) for engaging a wall of a wellbore, wherein the at least one movable wall engaging member (120) is movable from a retracted position to an expanded position to engage the wall, and from the expanded position to a retracted position to disengage the wall. Provision of one or more wall engaging members (120) being movable from an expanded position to a retracted position allows the anchoring apparatus to be retrieved from the wellbore, and in particular, from an open hole.
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
An anchoring apparatus (110) for use in a wellbore, comprises at least one movable wall engaging member (120) for engaging a wall of a wellbore, wherein the at least one movable wall engaging member (120) is movable from a retracted position to an expanded position to engage the wall, and from the expanded position to a retracted position to disengage the wall. Provision of one or more wall engaging members (120) being movable from an expanded position to a retracted position allows the anchoring apparatus to be retrieved from the wellbore, and in particular, from an open hole.
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
An anchoring apparatus (110) for use in a wellbore, comprises at least one movable wall engaging member (120) for engaging a wall of a wellbore, wherein the at least one movable wall engaging member (120) is movable from a retracted position to an expanded position to engage the wall, and from the expanded position to a retracted position to disengage the wall. Provision of one or more wall engaging members (120) being movable from an expanded position to a retracted position allows the anchoring apparatus to be retrieved from the wellbore, and in particular, from an open hole.
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
A valve assembly (16) comprises an actuation fluid inlet (30), an actuation fluid outlet (40) and a valve member (82) moveable between a closed position in which the actuation fluid outlet is closed, and an open position in which the actuation fluid outlet is opened. A locking arrangement (104) is provided for locking the valve member in its closed position, wherein the locking arrangement is operable in response to a first predetermined fluid pressure event associated with at least the actuation fluid inlet to release the locking arrangement to permit the valve member to be moved to its open position in response to a second subsequent predetermined fluid pressure event associated with at least the actuation fluid inlet.
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
E21B 34/00 - Valve arrangements for boreholes or wells
A valve assembly (16) comprises an actuation fluid inlet (30), an actuation fluid outlet (40) and a valve member (82) moveable between a closed position in which the actuation fluid outlet is closed, and an open position in which the actuation fluid outlet is opened. A locking arrangement (104) is provided for locking the valve member in its closed position, wherein the locking arrangement is operable in response to a first predetermined fluid pressure event associated with at least the actuation fluid inlet to release the locking arrangement to permit the valve member to be moved to its open position in response to a second subsequent predetermined fluid pressure event associated with at least the actuation fluid inlet.
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 34/00 - Valve arrangements for boreholes or wells
A screen assembly, such as a downhole/ sand screen assembly, comprising first and second screen portions or screens longitudinally coupled together, wherein there is provided a fluid flow path between the first and second screen portions or screen. Optionally, the first and second sleeves are coupled or connected by a centraliser or further sleeve or screen, and/or optionally by or via first and second support ring.
A tubular stabbing guide (10) used to assist in the location of a pin end connection of a tubular in a box end connection (14) of another tubular forming the upper end of a drill string held and supported from the drill floor (16) of a rig. The stabbing guide (10) has a mounting frame (22) for location on the drill floor (16) and funnel-forming members (32) mounted on the frame (22). In use, the funnel-forming members (32) are moved from a retracted location spaced from the box end connection (14) to an active location surrounding the box end connection (14), such that the funnel-forming members (32) form a funnel for guiding the pin end connection into the box end connection (14).
A downhole apparatus is described comprising a body and a sealing arrangement located on the body. The body has a longitudinal axis and the sealing arrangement comprises at least one elongated sealing member with an axis of elongation extending around the longitudinal axis. The sealing member comprises a material selected to expand on exposure to at least one predetermined fluid, such as a hydrocarbon or aqueous fluid encountered in a wellbore. A method of forming the apparatus and methods of use are described. Embodiments of the invention relate to wellbore packers.
A downhole apparatus and support assembly has a radially expanding portion comprising a swellable elastomeric material selected to increase in volume on exposure to at least one predetermined fluid, and the support assembly is operable to be deployed from a first retracted position to a second expanded condition. The support assembly comprises an inner surface arranged to face the radially expanding portion, and at least a portion of the inner surface is concave. The support assembly may be configured to direct a force from the swellable material to boost or energize a seal created between the radially expanding portion and a surrounding surface in use.
An apparatus for use in a wellbore is described, the apparatus having a tubular body and a throughbore which defines a primary fluid path through the apparatus. An expanding element is disposed around the tubular body and is configured to provide an annular barrier in a space between the tubular body and a surrounding wall. A conduit defining a secondary flow path through the apparatus is provided, and is configured to be in fluid communication with at least one alternate path, such as a shunt tube. The conduit is arranged to vary the secondary flow path along a longitudinal direction of the apparatus, for example to redirect the flow path to a radial position closer to the tool body. The conduit is configured to have a reduced effect on the operation of the expanding element, while still allowing the conduit to be coupled to alternate flow paths of adjacent apparatus.
A work string assembly for an oil or gas well has a first and second tubulars, and a torque limiting device connected in the work string. The torque limiting device has a body with an axial bore and two interconnected members that can disconnect to be relatively rotatable. The interconnected members can be repeatedly re-engageable when the torque levels drop below a torque threshold value, or can be connected by a frangible member that is broken when the interconnected members disconnect. A selectively actuable circulation port provided in the string adjacent to and above the torque limiting device allows the annulus between the work string and the casing to be flushed with fluid from the port.
A flow control apparatus for use in a wellbore comprises a screen, a first inflow control device and a second inflow control device, wherein a fluid inflow path is provided through the screen and from an outer portion to an inner portion of each inflow control device. A method of cleaning a flow control apparatus such as that described above comprises providing in a wellbore a flow control apparatus comprising at least one screen and at least one inflow control device wherein a fluid inflow path is provided through the at least one screen and from an outer portion to an inner portion of the at least one inflow control device, targeting the at least one inflow control device with a treatment fluid and delivering the treatment fluid such that the fluid flows in a reverse direction along the fluid inflow path.
A flow control apparatus for use in a wellbore comprises a screen, a first inflow control device and a second inflow control device, wherein a fluid inflow path is provided through the screen and from an outer portion to an inner portion of each inflow control device. A method of cleaning a flow control apparatus such as that described above comprises providing in a wellbore a flow control apparatus comprising at least one screen and at least one inflow control device wherein a fluid inflow path is provided through the at least one screen and from an outer portion to an inner portion of the at least one inflow control device, targeting the at least one inflow control device with a treatment fluid and delivering the treatment fluid such that the fluid flows in a reverse direction along the fluid inflow path.
A downhole apparatus has a radially expanding portion comprising a swellable elastomeric material selected to increase in volume on exposure to at least one predetermined fluid. A support assembly is operable to be deployed from a first retracted position to a second expanded condition. The support assembly comprises an inner surface arranged to face the radially expanding portion, and at least a portion of the inner surface is concave. The support assembly may be configured to direct a force from the swellable material to boost or energise a seal created between the radially expanding portion and a surrounding surface in use.
An apparatus for use in a wellbore is described, the apparatus having a tubular body and a throughbore which defines a primary fluid path through the apparatus. An expanding element is disposed around the tubular body and is configured to provide an annular barrier in a space between the tubular body and a surrounding wall. A conduit defining a secondary flow path through the apparatus is provided, and is configured to be in fluid communication with at least one alternate path, such as a shunt tube. The conduit is arranged to vary the secondary flow path along a longitudinal direction of the apparatus, for example to redirect the flow path to a radial position closer to the tool body. The conduit is configured to have a reduced effect on the operation of the expanding element, while still allowing the conduit to be coupled to alternate flow paths of adjacent apparatus.
An apparatus for use in a wellbore is described, the apparatus having a tubular body and a throughbore which defines a primary fluid path through the apparatus. An expanding element is disposed around the tubular body and is configured to provide an annular barrier in a space between the tubular body and a surrounding wall. A conduit defining a secondary flow path through the apparatus is provided, and is configured to be in fluid communication with at least one alternate path, such as a shunt tube, in an adjacent wellbore component (e.g. a sand control device). The conduit is arranged to vary the secondary flow path along a longitudinal direction of the apparatus, for example to redirect the flow path to a radial position closer to the tool body. The conduit is configured to have a reduced effect on the operation of the expanding element, while still allowing the conduit to be coupled to alternate flow paths of adjacent apparatus. The invention has particular application to swellable wellbore packer systems in gravel packing operations. An assembly, a method of use, and a wellbore installation are also described.
Tubing reaming apparatus comprises a housing adapted to be mounted to tubing to be reamed. The housing provides mounting for a reamer shaft adapted to mount a cutter within the tubing. The housing also provides mounting for a drive arrangement. A gear arrangement is provided between the drive arrangement and the reamer shaft. The housing may comprise a clamping arrangement adapted to reduce residual bend and ovality of the tubing.
patents
