A satellite injecting apparatus for releasing satellites into a wellhead having a wellbore having a housing adapted to be supported to by the wellhead, the housing having an axial bore therethrough, and one or more satellite cartridges radially arranged around the wellbore and comprising actuators for moving the satellite cartridges towards and away from the axial bore for selectively launching satellites into the wellbore.
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 33/068 - Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells
A satellite injecting apparatus for releasing satellites into a wellhead having a wellbore having a housing adapted to be supported to by the wellhead, the housing having an axial bore therethrough, and one or more satellite cartridges radially arranged around the wellbore and comprising actuators for moving the satellite cartridges towards and away from the axial bore for selectively launching satellites into the wellbore.
A satellite launcher having a body comprising a planar surface and an axial bore; a plurality of satellite tubes, each satellite tube for releasably retaining a satellite and having an open end for facing the planar surface; a first and a second track system, each comprising: a track extending along the planar surface through the axial bore with a track opening at the axial bore, a magazine slideably attached to the track, the magazine for detachably retaining satellite tubes, and a drive system for moving the first magazine along the first track. The track of the second track system angularly offset from the track of the first track system relative to the axial bore, the second track defining a second track opening at the axial bore. When one of the satellite tubes is aligned with the axial bore, the satellite contained therein is free to drop out.
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
A satellite launcher having a body comprising a planar surface and an axial bore; a plurality of satellite tubes, each satellite tube for releasably retaining a satellite and having an open end for facing the planar surface; a first and a second track system, each comprising: a track extending along the planar surface through the axial bore with a track opening at the axial bore, a magazine slideably attached to the track, the magazine for detachably retaining satellite tubes, and a drive system for moving the first magazine along the first track. The track of the second track system angularly offset from the track of the first track system relative to the axial bore, the second track defining a second track opening at the axial bore. When one of the satellite tubes is aligned with the axial bore, the satellite contained therein is free to drop out.
An apparatus, system, and method are provided for injecting carrier sleeves into a wellbore. The injection system is capable of individually indexing a selected sleeve from a sleeve magazine into an injector bore and axially aligning the sleeve with the bore with a retaining device. The retaining device prevents a subsequent sleeve from being indexed into the bore from the magazine. The selected sleeve can be restricted from free fall using a staging mechanism, which can subsequently be opened to permit the selected sleeve to fall into a staging bore. The staging bore is then fluidly isolated from the injector bore and the wellbore, pressure in the staging bore is equalized with the wellbore, and then opened to the wellbore for injecting the sleeve into the wellbore. The sleeve can be axially aligned and radially centered with the injector bore using a tapered portion in the bore or the staging mechanism.
E21B 33/068 - Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
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 system and method is provided for maintaining a live bore throughout a manifold of a fluid flow system while providing fluid flow to two or more wellbores. At least two fluid inlet portions and at least one intermediate inlet portion located between the two fluid inlet portions deliver fluid to the live bore. The two fluid inlet portions straddle two or more outlet portions which are in communication with the two or more wellbores. One or more or all of the inlet portions or outlet portions can have multiple flow-impinging ports for reducing fluid velocity at each inlet and outlet portion. A diverter line can be provided to divert fluid from the first or second inlet portions to the intermediate inlet portions to equalize fluid flow streams in the manifold.
A system and method is provided for maintaining a live bore throughout a manifold of a fluid flow system while providing fluid flow to two or more wellbores. At least two fluid inlet portions and at least one intermediate inlet portion located between the two fluid inlet portions deliver fluid to the live bore. The two fluid inlet portions straddle two or more outlet portions which are in communication with the two or more wellbores. One or more or all of the inlet portions or outlet portions can have multiple flow-impinging ports for reducing fluid velocity at each inlet and outlet portion. A diverter line can be provided to divert fluid from the first or second inlet portions to the intermediate inlet portions to equalize fluid flow streams in the manifold.
An apparatus, system, and method are provided for injecting carrier sleeves into a wellbore. The injection system is capable of individually indexing a selected sleeve from a sleeve magazine into an injector bore and axially aligning the sleeve with the bore with a retaining device. The retaining device prevents a subsequent sleeve from being indexed into the bore from the magazine. The selected sleeve can be restricted from free fall using a staging mechanism, which can subsequently be opened to permit the selected sleeve to fall into a staging bore. The staging bore is then fluidly isolated from the injector bore and the wellbore, pressure in the staging bore is equalized with the wellbore, and then opened to the wellbore for injecting the sleeve into the wellbore. The sleeve can be axially aligned and radially centered with the injector bore using a tapered portion in the bore or the staging mechanism.
E21B 33/068 - Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
E21B 33/124 - Units with longitudinally-spaced plugs for isolating the intermediate space
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 apparatus, system, and method are provided for injecting carrier sleeves into a wellbore. The injection system is capable of individually indexing a selected sleeve from a sleeve magazine into an injector bore and axially aligning the sleeve with the bore with a retaining device. The retaining device prevents a subsequent sleeve from being indexed into the bore from the magazine. The selected sleeve can be restricted from free fall using a staging mechanism, which can subsequently be opened to permit the selected sleeve to fall into a staging bore. The staging bore is then fluidly isolated from the injector bore and the wellbore, pressure in the staging bore is equalized with the wellbore, and then opened to the wellbore for injecting the sleeve into the wellbore. The sleeve can be axially aligned and radially centered with the injector bore using a tapered portion in the bore or the staging mechanism.
Method, apparatus and a system is provided for injecting carrier sleeves into a wellbore. A selected carrier sleeve is aligned in an injector bore restricted therein from free fall and preventing a subsequent sleeve from indexing into the bore from a magazine of sleeves. The sleeve can be restricted from free fall from the bore using an annular restrictor. The selected sleeve is forcibly displaced from the injector bore into a staging bore, as part of an contiguous axial bore, that is isolated from the wellbore. The staging bore is fluidly isolated from the injector bore. The pressure in the staging bore is equalized with the wellbore and then opened to the wellbore for launching the sleeve. The staging bore can be isolated from the injection bore by valve or isolation mandrel sealably moveable within the axial bore.
A system and method is provided for maintaining a live bore throughout a manifold while alternating between fluid flow to a stimulated wellbore and to an inactive or resting wellbore. At least two fluid inlets deliver fluid to the live bore, the fluid inlets straddling the two or more fluid outlets connected to the respective wellbores. One or more or all of the inlets or outlets can have multiple flow-impinging ports for reducing fluid velocity through each port. In another embodiment a method flushing system is provided for freeze protection for piping for a resting wellbore. Further, high fluid flow swivel connections between the manifold and wellheads simplify installation and reduce operational stresses.
A system and method are provided for storing and dry launching one or more balls into a wellbore having reduced ball drop height and ball drop stages relative to existing systems and methods. Balls are individually stored in cartridges of a ball launcher in communication with the wellbore via an axial bore, and are isolated from fluids and pressure in the axial bore by seals located on the cartridge. A selected ball can be injected into the wellbore by isolating the axial bore from the wellbore, establishing a launching pressure in the axial bore, actuating the cartridge of the selected ball to a launch position to stage the ball in the axial bore, retracting the cartridge to a sealing position, establishing a release pressure in the axial bore, and then re-establishing communication between the axial bore and wellbore to allow the ball to be injected.
A debris catcher and system is provided for removing debris from fluids such as in wellbore stimulation operations. A generally tubular housing axially supports a tubular screen inside a housing bore. Debris-laden fluid flows from an intake end of the housing axially into the bore of the screen and exits screen openings radially into an axially elongated flow annulus formed between a tubular wall of the screen body and the housing bore. Debris is retained in the upstream portion of screen body and clean fluid, in the annulus, returns downstream of the screen for exit out a discharge end of the housing. The screen is removably installable to the housing.
Method, apparatus and a system is provided for dry launching balls. One releases a ball from the stored balls, stages the ball in a staging or launching block for exposure to fluids and then injects the dropped ball into the wellbore. Fluid in the isolated staging block is removed by pump or by drainage, minimizing risk of fluid reaching stored dry balls thereabove. This method can then be repeated for subsequent balls to be dropped into the wellbore. Further, a system for reducing the fall energy of a dropped ball comprises providing one or more impact energy dampeners along a ball drop path including providing an angled sidewall of the path bore, one more elements to periodically engage a dropped ball, or to provide a liquid sump to receive a dropped ball.
Fracturing headers and connected conduits are fit with one or more fluid screening and wear minimizing inserts. Tubular screen inserts are provided to screen a flow of fracturing fluid through manifolds prior to, or at, the fracturing header. Each tubular screen insert has a tubular wall having an insert bore, an endwall and an open inlet. A plurality of openings, about the tubular wall, provide fluid communication between the bore and an annular area outside the wall. Oriented in a flow conduit with the closed endwall upstream, the insert excludes and sheds debris therefrom. Oriented with the closed endwall downstream, the insert receives and stores debris. Pairs of inserts, retained in opposing inlet ports, serve to screen fluid and deflect erosive flow from tools such as coil tubing extending therethrough. A fracturing block fit with opposing inlet ports can also be fit with an outlet port for flowback operations.
Fracturing headers and connected conduits are fit with one or more fluid screening and wear minimizing inserts. Tubular screen inserts are provided to screen a flow of fracturing fluid through manifolds prior to, or at, the fracturing header. Each tubular screen insert has a tubular wall having an insert bore, an endwall and an open inlet. A plurality of openings, about the tubular wall, provide fluid communication between the bore and an annular area outside the wall. Oriented in a flow conduit with the closed endwall upstream, the insert excludes and sheds debris therefrom. Oriented with the closed endwall downstream, the insert receives and stores debris. Pairs of inserts, retained in opposing inlet ports, serve to screen fluid and deflect erosive flow from tools such as coil tubing extending therethrough. A fracturing block fit with opposing inlet ports can also be fit with an outlet port for flowback operations.
A ball catcher for recovering balls from wellbore fluids containing sand during flow back operations. The ball catcher has a receiving chamber for receiving the wellbore fluids containing sand, a first flow outlet for discharging a portion of the wellbore fluids and sand contained therein, and a diverter for redirecting balls entrained within the wellbore fluids. The redirected balls and a balance of the wellbore fluids also containing sand are received in a ball-retaining chamber. A blocker fit to the ball-retaining chamber retains the recovered balls therein while the balance of the wellbore fluids and sand contained therein is discharged from a second flow outlet and directed to downstream equipment through an auxiliary flow line. The retaining chamber can be isolated allowing the balls to be removed from the ball catcher without disrupting the flow back operation.
An apparatus for successively releasing balls into a wellbore during wellbore operations is disclosed. The apparatus has a radial housing having at least one radial ball array having two or more radial bores. Each radial bore houses a ball cartridge adapted to receive and release balls and an actuator for operably aligning or misaligning the ball cartridge with an axial bore in fluid communication with the wellbore. The ball cartridge is moveable along the radial bore and is operable between an aligned position, for releasing a ball and a misaligned position for storing the ball.
An apparatus for successively releasing balls into a wellbore during wellbore operations is disclosed. The apparatus has a radial housing having at least one radial ball array having two or more radial bores. Each radial bore houses a ball cartridge adapted to receive and release balls and an actuator for operably aligning or misaligning the ball cartridge with an axial bore in fluid communication with the wellbore. The ball cartridge is moveable along the radial bore and is operable between an aligned position, for releasing a ball and a misaligned position for storing the ball.
A packoff nipple for sealing an annular space in a well pipe has a tubular body, a sealing assembly positioned around the tubular body capable of axial movement along the tubular body and a stop to restrain the sealing assembly from extruding in-to the annular space. The sealing assembly includes one or more elastomeric sealing rings having a circumferential groove formed in a downhole face. An axially moveable actuator, such as a packer cup, engages the sealing ring assembly to causes at least a portion of the sealing rings to expand radially outwardly to seal the annular space and cause the sealing ring assembly to contact the uphole stop. The sealing rings are axially compressed between the uphole stop and the actuator to further expand the sealing rings. The uphole stop may be concave to urge the sealing rings away from the well pipe to avoid extrusion or permanent deformation.
A packoff nipple is provided for sealing an annular space in a well pipe. The packoff nipple generally comprises a tubular body and a sealing assembly positioned around the tubular body and axially moveably thereon. A stop restrains the sealing assembly from extruding in to the annular space. The sealing assembly includes one or more elastomeric sealing rings having a circumferential groove formed in a downhole face. An axially moveable actuator, preferably a packer cup, engages the sealing ring assembly to causes at least an expansion portion of the sealing rings to expand radially outwardly to seal the annular space and the sealing ring assembly to contact the uphole stop. The sealing rings are axially compressed between the uphole stop and the actuator to further expand the sealing rings. Preferably the uphole stop is concave to urge the sealing rings away from the well pipe and thus further avoid extrusion. As the sealing rings are not extruded past the uphole stop or otherwise permanently deformed, the packoff nipple is reusable and thereby cost- effective.
A packoff nipple is provided for sealing an annular space in a well pipe. The packoff nipple generally comprises a tubular body and a sealing assembly positioned around the tubular body and axially moveably thereon. A stop restrains the sealing assembly from extruding in to the annular space. The sealing assembly includes one or more elastomeric sealing rings having a circumferential groove formed in a downhole face. An axially moveable actuator, preferably a packer cup, engages the sealing ring assembly to causes at least an expansion portion of the sealing rings to expand radially outwardly to seal the annular space and the sealing ring assembly to contact the uphole stop. The sealing rings are axially compressed between the uphole stop and the actuator to further expand the sealing rings. Preferably the uphole stop is concave to urge the sealing rings away from the well pipe and thus further avoid extrusion. As the sealing rings are not extruded past the uphole stop or otherwise permanently deformed, the packoff nipple is reusable and thereby cost- effective.
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