Abstract: A method for controlling a wellbore pressure. The method includes disposing a tubing within a casing of a wellbore to form a tubing casing annulus. The method includes installing a tubing-packer sealing assembly within the casing to seal a downhole portion of the wellbore from an uphole portion. The tubing is disposed in the uphole portion of the wellbore. The method includes filling the tubing casing annulus in with an annulus fluid. The method includes, after filling the tubing casing annulus with the annulus fluid, injecting a volume of inert gas into the tubing casing annulus causing an equal volume of the tubing casing annulus fluid to be flowed out of the wellbore. The method includes after injecting the volume of the inert gas, sealing the annulus fluid and the inert gas in the tubing casing annulus.

Abstract: A system for mining material in a seam under an overburden layer using a geological model map of a geological formation, including a desired drilling end point at a predefined position relative to a geological boundary between the overburden layer and seam. A drill controller controls operation of a drill drilling a blast hole. A sensor pack senses, while drilling the blast hole, blast hole drilling operation parameters; and feeds the sensed parameters in real time to the drill controller. A data storage module stores a geological model of the geological formation and sensed parameters data. A processor module generates a geological model map including the desired drilling end point and locates the drill bit position relative to the geological boundary and such end point. The drill controller drills to the desired drilling end point and causes the drill to stop drilling upon reaching such end point.

Abstract: A downhole device and a method of performing an operation in a borehole. The downhole device includes an outer sleeve defining a bore therethrough, an inner sleeve disposed within the bore and axially movable with respect to the outer sleeve between a first position and a second position, the inner sleeve defining a flow passage, and a seat member in the flow passage for seating a ball when the inner sleeve is at the first position. A ball is seated at the seat member. A fluid pressure on the ball moves the inner sleeve from the first position to the second position, moves the seat member radially outward out of the flow passage when the inner sleeve is at the second position, and pushes the ball out of the flow passage.

Abstract: A method includes running a workover liner, having a workover liner top end, into the workover well, installing a crossover bottom end of a crossover to the workover liner top end, installing a crossover top end of the crossover to a tieback casing bottom end of a tieback casing, running the workover liner, crossover, and tieback casing into the workover well such that the workover liner is set within the production liner, the crossover is set above the liner hanger of the production liner, and the tieback casing is set within the production casing and extends to a surface location. The method further includes cementing the workover liner, crossover, and tieback casing with cement and leaving behind a shoe track. The cement holds the workover liner, crossover, and tieback casing in place within the workover well and prevents leakage of fluids out of the workover well.

Abstract: A system for mining material in a seam under an overburden layer using a geological model map of a geological formation, including a desired drilling end point at a predefined position relative to a geological boundary between the overburden layer and seam. A drill controller controls operation of a drill drilling a blast hole. A sensor pack senses, while drilling the blast hole, blast hole drilling operation parameters; and feeds the sensed parameters in real time to the drill controller. A data storage module stores a geological model of the geological formation and sensed parameters data. A processor module generates a geological model map including the desired drilling end point and locates the drill bit position relative to the geological boundary and such end point. The drill controller drills to the desired drilling end point and causes the drill to stop drilling upon reaching such end point.

Abstract: A screen and valve system includes a first screen portion including an inner surface and an outer surface. The inner surface defines a first conduit section. A second screen portion includes an inner surface portion and an outer surface portion. The inner surface portion defines a second conduit section. The second screen portion is mechanically joined with the first screen portion such that the first conduit section and the second conduit section form a flow path. A valve member is arranged in the flow path. The valve member includes a a first end segment, a second end segment and an inner surface defining a conduit. First end segment is arranged in the first conduit section without a mechanical connection and the second end segment is arranged in the second conduit section without a mechanical connection. A valve element is slideably arranged in the conduit.

Abstract: A rotary tool for machining a material in a downhole environment. The rotary tool includes a drive train and a lead screw connected to and rotatable by the drive train The tool also includes a linear block engaged with but not rotatable by the lead screw so as to convert the rotation of the lead screw into linear motion The tool also includes a machining tool rotatable by the lead screw and movable linearly by the linear block to machine the material. Also, the machining tool machines the material in a series of steps.

Abstract: An apparatus or system comprising, or a method utilizing, a pressure-tight head assembly coupling a multi-conductor wireline cable operable for downhole operations within a borehole extending into a subterranean formation. The head assembly comprises: an upper head attachment; a lower head attachment; an upper compression seal assembly; a gripper cone; and a rope socket. The upper compression seal assembly is threaded into and/or otherwise coupled to the upper head attachment in a manner causing the gripper cone to tighten onto the cable jacket.

Abstract: A telescopic tool is located intermediate a conveyance string and permits an uphole portion to be manipulated through reciprocation and rotation regardless of the fixed nature of a downhole portion. In embodiments, tools uphole of telescopic joint can be actuated by casing manipulation to aid in placement of cement. In other embodiments, such as during running into the wellbore, the tool can be selectively actuated to cause the uphole casing string to lock to, and rotate, the casing string located downhole.

Abstract: A ball-dropping sliding sleeve with a removable ball seat, comprising an outer barrel (1), an inner sliding sleeve (6) and a removable ball seat assembly; an inner ring downward facing shoulder (2) is disposed at an upper end of the outer barrel (1), a lower joint (3) is fixedly mounted in a lower end of the outer barrel (1), a sliding groove (4) is formed in the outer barrel (1) between the downward facing shoulder (2) and the lower joint (3), and at least one fracturing lateral hole (5) is distributed on a circumference of the outer barrel (1) at an upper side of the sliding groove (4). The structure of the present invention is reasonable and compact, and its usage is convenient.

Abstract: Examples describe systems and methods for a tool to remove portions of casing from a wellbore. A tool may include a bottom sub-assembly and casing that selectively detach from a sub-assembly. This may allow for tools and casing within the wellbore to be efficiently and effectively removed from the wellbore without having to cut tools down well.

Abstract: The present invention is a retrievable back pressure valve device and method of using the same that may be placed in tubing during well completion and retrieved as desired by dropping a ball down hole, which then interacts with the valve to shear the positioning points allowing for retrieval as the valve is allowed to move up the well to be removed from same.

Abstract: What is provided is a method and apparatus wherein a rotating and reciprocating swivel can be detachably connected to an annular blowout preventer thereby separating the drilling fluid or mud into upper and lower sections with the mandrel of the swivel being comprised of double box end joints and using double pin end subs to connect a plurality of such mandrel joints together.

Abstract: A valve assembly, and related system and method, with a sleeve having an inner surface with a diameter, an outer surface, and a plurality of openings extending between the inner surface and the outer surface. A split ring having one or more segments and an expandable or collapsible body with a seating surface and an outer diameter extending from the body is at least partially within the inner surface of the sleeve. The split ring and sleeve may be placed in a variable diameter housing such that contact of the outer diameter with a smaller diameter section of the housing causes the split ring to close, whereas contact with an larger diameter of the housing allows the split ring to open. In certain embodiments, a spring element, which may be the split ring itself, applies force to move the split ring from an open to closed position. A spring may be positioned around a portion of the sleeve and in an annular space at least partially defined by an annular body and the second cylindrical outer surface.

Abstract: A releasable connection for coiled tubing drilling apparatus is presented wherein the connection has an outer body configured with an inner volume, a mandrel located at least partially within the outer body and in the inner volume, a plug located with the outer body and a structural weakpoint apparatus, wherein the structural weakpoint apparatus is configured to structurally fail at a predetermined tensile load placed upon the releasable connection apparatus, wherein the structural weakpoint apparatus is configured at a lower end of the mandrel.

Abstract: A device for connecting at least one electrical data and/or supply line to electrical sockets of a wired drill pipe is disclosed. One inventive aspect of the device comprises: a collet blocking plug axially insertable into and removable from a receiver end of the drill pipe and at least one collet. The collet is configured to be interlocked with the drill pipe in a locking position and be released from the drill pipe in a release position. The collet is axially displaceable from the collet blocking plug between the locking position and the release position. The collet blocking plug is axially insertable into and removable from a receiver end of the drill pipe.

Abstract: A production string for use in a wellbore is disclosed that in a non-limiting embodiment includes a lower section that includes a first tubular having a first connection device at a top end thereof, and an upper section that includes a second tubular that sealingly slides against the first tubular, a second connection device associated with the second tubular configured to engage with the first connection device, and an expansion joint above the second tubular.

Abstract: A method of traversing a travel joint with a line can include, after the travel joint has been installed in a well, activating a connector which provides sealed fluid communication between sections of the line on respective opposite sides of the travel joint. A travel joint system for use with a subterranean well can include a travel joint comprising a releasing device which permits relative displacement between sections of the travel joint, and a connector which provides fluid communication between sections of a line.

Abstract: A method of use of a quick connect liner latch system assembly (QCLL). The QCLL latches each joint of a slick line deployed liner together quickly. This system can set an anchor in an existing well bore at a shallow depth and run a new liner in the well with a wire line unit using the QCLL system. The QCLL has two main sections that are locked together to form the full QCLL. The upper and lowers sections are locked together using a body lock ring. The units are not threaded together. The QCLL it has a latch with an inside diameter (ID) that is large enough to accommodate a standard liner wiper plug for the weight of the liner being run into the well.

Abstract: Downhole tools, such as MWD modules (or components), may be coupled together with a coupler (or coupling device) having a shaft housing with slidable electrical connectors disposed at each end. The electrical connectors may each be supported in connector housings disposed with springs or other movable devices. In a first position, the electrical connectors may extend past the ends of the shaft housing. The slidable connector housings allow the electrical connections to be made before the sleeves connecting (or mechanically connecting) the MWD modules with the coupler are begun to be threadedly attached with the coupler. Each of the connector housings may have a key configuration on their exposed end. The shaft housing may also have key configurations on its ends. The key configurations of the connector housings and the shaft housing may be configured to mate with compatible ends of MWD modules.

Abstract: A method of forming a wellbore includes providing a drilling assembly comprising one or more lengths of casing and an axially retracting assembly having a first tubular; a second tubular at least partially disposed in the first tubular and axially fixed thereto; and a support member disposed in the second tubular and movable from a first axial position to a second axial position relative to the second tubular, wherein, in the first axial position, the support member maintains the second tubular axially fixed to the first tubular, and in the second axial position, allows the second tubular to move relative to the first tubular; and an earth removal member disposed below the axially retracting assembly. The method also includes rotating the earth removal member to form the wellbore; moving the support member to the second axial position; and reducing a length of the axially retracting assembly.

Abstract: A damping assembly including a damping device including a body, a piston assembly having a piston rod disposed within the body, a biasing member biasing the piston rod to a position within the body, and a damping block connected to and movable with the piston rod; and, a connector associated with a downhole tool and connectable to the damping device; and wherein the damping device reduces effects of shocks experienced by the downhole tool via the damping block. Also included is a method of reducing impact of shocks on a downhole tool during tripping.

Abstract: A shock absorbing system has a nose assembly that is formed to inwardly collapse on impact and is guided by a sleeve that can slide with the nose as the nose collapses or can extend for a portion of the length of the nose while being held fixed. In the latter instance the nose can have a leading end that has a biasing member in a resilient material so that on impact some of the shock is taken up by compression of the biasing member with subsequent extension of the biasing member retracting the resilient covering so that it is less likely to bind in the surrounding tubular. The leading end of the sleeve or the resilient material encasing the biasing member also soften the blow to a closed ball when the tool is dropped so that the ball surface is less likely to mar.

Abstract: Apparatuses and methods for controlling the connection speed of downhole connectors in a subterranean well are disclosed. An apparatus includes a first assembly having a first downhole connector and a first communication medium that is positionable in the well. A second assembly includes a second downhole connector and a second communication medium and has an outer portion and an inner portion that are selectively axially shiftable relative to one another. A lock assembly including at least one lug initially couples the outer and inner portions of the second assembly together such that, upon engagement of the first assembly with the second assembly downhole, the lug is radially shifted releasing the lock assembly to allow axial shifting of the outer portion of the second assembly relative to the inner portion of the second assembly, thereby operatively connecting the first and second downhole connectors to enable communication between the communication media.

Abstract: A downhole tool for use in a wellbore tubular string comprises a housing having a bore therethrough forming part of a fluid flowpath through the wellbore tubular string, a sliding member operable to slide with respect to the housing, a plurality of magnetic pins, and a corresponding plurality of springs. A sliding line is formed by interfacing surfaces of the sliding member and the housing, and the plurality of pins comprise a locked position and an unlocked position whereby in the locked position at least one pin spans the sliding line to prevent the sliding member from sliding with respect to the housing and in the unlocked position no pins span the sliding line. The plurality of springs biases the pins towards the locked position.

Abstract: A device for activating a downhole tool is described. The device comprises a first elongate member defining a toothed surface portion, a second elongate member defining a toothed surface portion and at least one pinion arrangement The/each pinion arrangement engages the toothed surface portions of the first and second members such that movement of one member in a first direction results in movement of the other member in a second direction, opposite the first direction.

Abstract: Porous objects, such as porous balls, may be employed within telescoping devices to control proppant flowback through a completed well during production. The telescoping devices may connect a reservoir face to a production liner without perforating. Acid-soluble plugs initially disposed within the telescoping devices may provide enough resistance to enable the telescoping devices to extend out from the production liner under hydraulic pressure. The plugs may then be dissolved in an acidic solution, which may also be used as the hydraulic extension fluid. After the plugs are substantially removed from the telescoping devices, the reservoir may be hydraulically fractured using standard fracturing processes. The porous balls may then be inserted into the telescoping devices to block proppant used in the fracturing process from flowing out of the reservoir with the production fluids.

Abstract: A movable downhole tubing string for a downhole well. The well has a wellhead and a downhole pump. The movable downhole tubing string has a movable tubing string having a surface end adjacent to the wellhead and a pump end adjacent to the downhole pump. At least one of the surface end and the pump end is telescopically received within a stationary tubing section. The stationary tubing section is stationary relative to the wellhead. There is an actuator for telescopically moving the movable tubing string relative to the stationary tubing section.

Abstract: A safety apparatus for catching a test fixture released from a shaft of a downhole tool during the uphole calibration and testing of the shaft force generation capability of the tool. The safety apparatus includes a hollow body having a distal end that will partially envelope the test fixture to catch the test fixture once the test fixture is released from the downhole tool. The safety apparatus further includes a proximal end portion that is releasably securable to the body of the tool. A method for testing and calibrating the tool is also provided.

Abstract: An apparatus and a method to seal and prevent leakage within a downhole tool are disclosed herein. The apparatus includes a first body portion having a first fluid flow path formed therethrough and a second body portion having a second fluid flow path formed therethrough. The second body portion is movable between a first position and a second position with respect to the first body portion. The apparatus further includes a stopper connected to the second body portion and disposed within the first body portion. When the second body portion is in the first position, the stopper sealingly engages the first fluid flow path, and when the second body portion is in the second position, the stopper sealingly disengages from the first fluid flow path.

Abstract: A tubular locking system comprises a first wellbore tubular, an internal locking feature disposed on an inner surface of the first wellbore tubular, a second wellbore tubular, where at least a portion of the second wellbore tubular is disposed within the first wellbore tubular, a compression sleeve coupled to the second wellbore tubular, a collet coupled to the second wellbore tubular below the compression sleeve, and a shifting sleeve disposed within the collet.

Abstract: A device has a first elongate tubular body and a second elongate tubular body coupled to the first tubular body, both adapted to reside in the wellbore. The device is changeable between the first tubular body axially fixed against movement in a first direction relative to the second tubular body and axially moveable in the first direction relative to the second elongate tubular body in response to temperature.

Abstract: A shock absorbing system has a nose assembly that is formed to inwardly collapse on impact and is guided by a sleeve that can slide with the nose as the nose collapses or can extend for a portion of the length of the nose while being held fixed. In the latter instance the nose can have a leading end that has a biasing member in a resilient material so that on impact some of the shock is taken up by compression of the biasing member with subsequent extension of the biasing member retracting the resilient covering so that it is less likely to bind in the surrounding tubular. The leading end of the sleeve or the resilient material encasing the biasing member also soften the blow to a closed ball when the tool is dropped so that the ball surface is less likely to mar.

Abstract: New locking connector assemblies and telescoping extension/retraction assemblies are disclosed that operate on the natural spring rate constraints of radial protrusions or radially constrained rings as they interact with engaging members to provide the locking force and permit the connector and extension retraction assemblies to be engage and disengaged or extended and retracted.

Abstract: A jarring tool is disclosed. The tool has a segment of sub housing containing an upper stop proximate a first end thereof. An outer latch piece is connected to an upper end of the lower shaft inside the sub housing, and an upper shaft passes through the stop and connects on a first end thereof to an inner latch piece. A cap is on a second end of the upper shaft retaining a washer stack against the upper stop. A retainer is inside the sub housing and has an first piece providing a restraining region and an open region and a second piece attached to the sub housing. The retainer retains the inner and outer latch pieces in a latched position in the restraining region until the latch pieces are displaced toward the second end of the sub housing through the retainer to the open region as a result of a tensile force on the outer latch piece.

Abstract: A downhole tubular connector comprising a first body portion and a seal provided on the first body portion, the seal being adapted to selectively provide a seal with a downhole tubular, the downhole tubular connector further comprises a seal protector, wherein one of the seal protector and seal is movable with respect to the other of the seal protector and seal, the seal protector or seal being movable from a first position, in which at least a portion of the seal is protected by a first end of the seal protector, to a second position, in which the portion of the seal is exposed. The seal protector may be disposed so as to be movable from the first position to the second position by contact of the sleeve with the downhole tubular as the downhole tubular connector is brought into engagement with the downhole tubular.

Abstract: A method and device for making lateral openings out of a wellbore in a well formation where fluid is made to flow through a motherbore tubular like a completion or production pipe and then through a needle pipe that is aimed at the formation, and where the method includes positioning a needle pipe that comprises at least one pipe section inside or outside a motherbore tubular; and arranging the at least one pipe sections to be telescopically displaceable with regard to an other pipe.

Abstract: A string of drill pipe, for example, is assembled with a severing sub in anticipation of a possible need to cut the string at some point in the operation. The severing sub includes a thin wall tube that links opposite end tool joint bosses. The tin wall tube is easily cut by a shaped charge cutter. Rotary drive torque is transmitted between the sub tool join bosses by a concentric external torque tube having a torque transmitting assembly at each boss. The torque tube connection to the upper boss has an inseparable circumferential shoulder engagement with the boss. The lower boss engagement of the torque tube is axially separable. When the thin wall tube is cut, the upper boss and torque tube is withdrawn from the well with the upper pipe string.

Abstract: A device has a first elongate tubular body and a second elongate tubular body coupled to the first tubular body, both adapted to reside in the wellbore. The device is changeable between the first tubular body axially fixed against movement in a first direction relative to the second tubular body and axially moveable in the first direction relative to the second elongate tubular body in response to temperature.

Abstract: A system and a method provide a downhole mechanical energy absorber that protects downhole tools from impact loads and shock loads that occur during run-in contacts, tool drops, perforating blasts, and other impact events. A continuous localized inelastic deformation of a tube is a primary energy absorber in a load limiting design of the downhole mechanical energy absorber.

Abstract: A downhole shifting mechanism having an inner tubular member, an outer tubular member, a piston, a first set of teeth, a sliding block, a body lock ring, a first flow path, and a second flow path is described herein. A downhole assembly can include the downhole shifting mechanism with a downhole tool connected to a second end of the downhole shifting mechanism. Also described is a method for shifting a downhole tool disposed within a wellbore.

Abstract: A system for opening a window in a casing string (42) positioned in a wellbore (32). The system includes a hydraulic pressure intensifier (116) having a housing and a piston assembly with a differential piston area. The piston assembly is longitudinally shiftable relative to the housing and is initially secured relative thereto to prevent longitudinal movement therebetween. An anchor assembly (114) is operable to longitudinally secure the hydraulic pressure intensifier (116) within the casing string (42). A window opening tool (118) operably associated with the hydraulic pressure intensifier (116) is operably engagable with the casing string (42) such that when the anchor assembly (114) is longitudinally secured within the casing string (42) and the piston assembly is unsecured relative to the housing under hydrostatic pressure, longitudinal movement of the piston assembly transmits a force to the window opening tool (118), thereby opening the window in the casing string (42).

Abstract: A downhole tool releasing mechanism which includes a collet for releasably engaging a mandrel of a downhole tool. A retaining band is circumferentially disposed about the fingers of the collet for maintaining engagement of the collet and the mandrel prior to application of a predetermined axially directed force on the releasing mechanism. Upon application of such a force the collet fingers expand, breaking the shear band, the mandrel is released and the downhole tool is disengaged.

Abstract: A stress and torque reducing tool has a plunger that reciprocates inside of a body. The tool is connected between the pump and the sucker rod string and reduces stress transmitted therebetween. The body and plunger have longitudinally extending surfaces located at the plunger upper end portion, which surfaces cooperate and limit rotation of the body with respect to the plunger. An upper fluid port is located in an upper end of the body, while one or more lower fluid ports are located in a lower end of the body.

Abstract: A drilling assembly for drilling two or more casing sections into a subterranean formation includes a first casing bit and a second casing bit, each casing bit of different diameter affixed to a respective casing section of different diameter, at least two casing bits and the two or more casing sections arranged in a telescoping relationship. The second casing bit includes a bit body having a face on which two different types of cutting elements are disposed, the first type being cutting elements for drilling at least one subterranean formation and the second type being cutting elements for drilling through the first casing bit.

Abstract: An apparatus (100) for controlling the connection speed of first and second downhole connectors (316, 146) in a subterranean well. The apparatus (100) includes a first assembly that is positionable in the well. The first assembly includes the first downhole connector (316) and a first communication medium. A second assembly includes the second downhole connector (146) and a second communication medium. The second assembly has an outer portion and an inner portion. The outer portion is selectively axially shiftable relative to an inner portion, such that upon engagement of the first assembly with the second assembly, the outer portion of the second assembly is axially shifted relative to the inner portion of the second assembly allowing the first and second downhole connectors (316, 146) to be operatively connected to each other, thereby enabling communication between the first communication medium and the second communication medium.

Abstract: A connector guard is provided to protect one or both downhole connectors during wellbore run in prior to mating downhole. The connector guard may comprise dissolvable or degradable material and include an engagement sections and a removal feature. The connector guard may be dissolved or degraded via a reactive agent or temperature either introduced downhole proximate to the guards or contained within a chamber included in or created by a connector guard. The connector guard may be further coupled by a non-reactive cover in order to control the rate of reaction of the dissolvable material. The cover may be breached prior to mating of the downhole connectors.

Abstract: An outer casing string, including a surface casing head, and associated installation method. In some embodiments, the surface casing head includes an outer tubular member insertable through a diverter of an installed conductor system, an inner tubular member at least partially disposed within and moveable relative to the outer tubular member, and a sleeve ring rotatably coupled to the inner tubular. The outer tubular member has an annular recess. The sleeve ring includes a snap ring that is displaceable between an extended position and a retracted position. In the extended position, at least a portion of the snap ring is received within the annular recess, and the outer tubular member is axially immovable relative to the inner tubular member. In the retracted position, no portion of the snap ring is received within the annular recess, and the outer tubular member is axially moveable relative to the inner tubular member.

Abstract: An apparatus (100) for controlling the connection speed of downhole connectors (316, 146) in a subterranean well. The apparatus (100) includes a first assembly that is positionable in the well. The first assembly includes a first downhole connector (316) and a first communication medium. A second assembly includes a second downhole connector (146) and a second communication medium. The second assembly has an outer portion and an inner portion. The outer portion is selectively axially shiftable relative to an inner portion, such that upon engagement of the first assembly with the second assembly, the outer portion of the second assembly is axially shifted relative to the inner portion of the second assembly allowing the first and second downhole connectors (316, 146) to be operatively connected to each other, thereby enabling communication between the first communication medium and the second communication medium.

Abstract: An apparatus that is usable with a well includes a first equipment section that includes a first inductive coupler and a second equipment section that includes a second inductive coupler. The second equipment section is adapted to be run downhole into the well after the first equipment section is run downhole into the well to engage the first equipment section. A mechanism of the apparatus indicates when the first inductive coupler is substantially aligned with the second inductive coupler.