Abstract: Methods for forming a wellbore may include placing an upper section of inside a lower section of a parent liner; positioning an upper sealing member and a lower sealing member in the wellbore to form a pressure chamber, and expanding the second liner using the pressure chamber. The sealing members move axially relative to one another and the second liner has an inner bore that is hydraulically isolated from the pressure chamber. A related apparatus may include upper and lower sealing members that cooperate to form a pressure chamber that is hydraulically isolated from an inner bore of the second liner. A work string may include the sealing members, a connector that extends through the pressure chamber and the second liner; and an expander. The expander expands the second liner in response to the axial separation of the sealing members.

Abstract: A system for performing a downhole operation including a tubular string having a locking profile non-movably located therewith. At least one member is movably mounted with the string and includes an engagement profile. A tool is runnable with the string and has at least one sub with a key. The key is selectively engagable and disengagable with the engagement profile for enabling the tool to control movement of the member with respect to the string when engaged therewith. The key is engagable with the locking profile for restricting relative movement between the string and the tool when engaged therewith. A method of performing a downhole operation is also included.

Abstract: Embodiments of the invention generally relate to tools and methods for hanging and/or expanding liner strings. In one embodiment, a method of hanging a liner assembly from a previously installed tubular in a wellbore includes running the liner assembly and a setting tool into the wellbore using a run-in string. The setting tool includes an isolation valve and the liner assembly includes a liner hanger and a liner string. The method further includes sending an instruction signal from the surface to the isolation valve, wherein the isolation valve closes in response to the instruction signal and isolates a setting pressure in the setting tool from the liner string; and increasing fluid pressure in the setting tool, thereby setting the liner hanger.

Abstract: A landing ring having at least one scallop groove formed on an interior of the ring. The landing ring interfaces with a fluted mandrel casing hanger such that the scallop groove aligns between flutes of the hanger. This alignment of the scallop groove of the landing ring with the fluted mandrel casing hanger provides sufficient clearance to allow a stabbing in of a cement tube for cement injection during cement topping operations or debris clean out down hole.

Abstract: A tool for releaseably coupling a first tubing to a second tubing in a wellbore has a tubular mandrel configured to couple to and be carried into the wellbore by the first tubing. A collet ring is in an interior of the mandrel and has a plurality of collets to engage the second tubing. A releasing piston is carried in the interior of the mandrel to change between supporting the collet ring such that the collets can release from the profile and allowing the collet ring to lock such that the collets are locked in the profile.

Abstract: A temporary support device for oil well tubes and method of use. The device comprises a holding structure to be applied to the well surface casing, a holding base resting in the well's cellar floor and sets of adjustable supporting arms connecting the holding structure and the supporting base.

Abstract: A wellhead housing has a telescoping casing hanger with an actuator mechanism to provide for direct transfer of casing and pressure loads to the housing. The transfer of casing and pressure loads occurs even in conditions where the telescoping casing hanger may be set in a high position in the wellhead housing on a load shoulder. The transfer of casing and pressure loads also occurs in conditions where the telescoping casing hanger may be set in an earlier installed casing hanger in the wellhead housing for a larger diameter casing string.

Abstract: An apparatus including a downhole tool for conveyance in a wellbore extending into a subterranean formation. The downhole tool includes a feature to physically interface a sidewall of the wellbore, and first and second setting pistons each extendable from the downhole tool opposite the feature. The downhole tool also includes a rigid member spanning and extendable with the first and second setting pistons, wherein a length of the rigid member is variable.

Abstract: An engaging device includes a body selectively slidably engagable about a first tubular runnable within a second tubular. The body is runnable past at least one profile on the second tubular in a first direction during a first running and is prevented from running past the at least one profile on subsequent runs subsequent to running by the at least one profile in a second direction.

Abstract: A system and method for verifying support hanger orientation within a wellhead housing. In an example, a profile is included at a designated location on an inner surface of the wellhead housing. When the support hanger is landed in the wellhead housing, an impression is taken of the inner surface of the wellhead housing from a reference location. Analyzing the impression can indicate the position of the support hanger within the wellhead housing. A running tool that can land the support hanger within the wellhead housing can be equipped with an impression block for taking the impression of the profile in the wellhead housing.

Abstract: A string is equipped with a braking device to regulate its speed into the wellbore through an existing tubular. When the targeted amount of overlap with an existing tubular is accomplished the two tubulars are then joined together. The braking system can take many forms such as externally mounted mechanisms that are speed responsive to vary the braking force. The inside of the tubular can have trapped gas to provide buoyancy and reduce the dropping speed. The braking can be accomplished hydraulically through regulated flow through the tubular or by a combination of a hydraulic and mechanical device. The momentum of the dropped string can also be controlled with a swage device that at the appropriate location lands on a taper and wedges or fuses itself to the surrounding tubular to gain support from the surrounding tubular.

Abstract: A tubular component includes a limit collar disposed about the tubular component, and the limit collar comprises a body portion comprising a plurality of upsets disposed on an inner surface of the body portion, wherein the plurality of upsets define a first ring, a second ring, and at least one rib, at least one chamber formed between the inner surface of the body portion, an outer surface of the tubular component, and one or more surfaces of the first ring, the second ring, or the at least one rib, and a binder portion disposed in the at least one chamber.

Abstract: A well system can include a tubular string in a blowout preventer stack, a releasable hanger of the tubular string supported by a support surface, and the released hanger permitting the tubular string to displace further through the blowout preventer stack. A tubular string can comprise a releasable hanger including at least one inwardly retractable support, an indicator sub interconnected a distance from the hanger, and wherein the support retracts in response to a stimulus, whereby the tubular string is released for displacement. A method of measuring a distance between a support surface and a location in a blowout preventer stack can include displacing a tubular string into the blowout preventer stack, contacting a releasable hanger with the surface, indicating the distance from the surface to the location along the tubular string, and then releasing the hanger, thereby permitting the tubular string to displace further through the blowout preventer stack.

Abstract: An apparatus for separating a tubular string from a subsea well installation. The apparatus includes a heave compensator tensioning the tubular string, a subsea actuator assembly positioned within the tubular string, a subsea controller in communication with the subsea actuator assembly, a subsea safety tree positioned within the subsea well installation and a fluid delivery subsystem. An output signal generated by the subsea controller responsive to receipt of a predetermined input signal releases a piston of the subsea actuator assembly such that the tension in the tubular string shifts the piston relative to a cylinder energizing fluid in the fluid delivery subsystem to actuate the retainer valve, the shut-in valve assembly, the vent sleeve and the latch assembly, thereby safely separating the tubular string from a subsea well installation.

Abstract: An anchor system includes an anchoring device. The anchoring device is operably connected to at least one of a restriction indicator and a load isolation device each of which include a release member that releases at a selected load in order to ensure setting of the anchor at a desired location. A method is included.

Abstract: A liner hanger running tool (10) and method are provided for positioning a liner in a well bore. A tool mandrel (24) is supported from a running string, and a housing (44) surrounds the tool mandrel. A flow annulus between the mandrel and the housing allows fluid to pass upward through the running tool to a position above the liner. A hydraulic release mechanism (78, 79) is activated by fluid pressure within the mandrel to axially move a piston (50) positioned radially outward of the mandrel to release the running tool from the liner.

Abstract: A position reference system (100) for multilateral exit construction in a wellbore (32). The system (100) includes a casing string (34) having a window joint (106) and a pair of latch couplings (102, 104) interconnected therein and positioned in the wellbore (32). The first latch coupling (102) has a first inner profile operably engagable with a mating profile of a first latch assembly (114) to anchor and orient the first latch assembly (114) relative to the window joint (106). The second latch coupling (104) has a second inner profile that is different from the first inner profile of the first latch coupling (102). The second inner profile is operably engagable with a mating profile of a second latch assembly (124) to anchor and orient the second latch assembly (124) relative to the window joint (106).

Abstract: A packoff is located within a wellhead housing and a casing hanger. The packoff has an internal ratchet ring that engages a threaded profile on the exterior of the casing hanger thereby allowing installation of the packoff to be achieved by simply stabbing the packoff over the protruding neck of the casing hanger. This ratchet ring significantly reduces the rotation required during installation, decreasing potential for damage to seals. The casing hanger has an external lock ring that is inwardly biased. During installation of the packoff, the packoff acts to activate the lock ring to thereby force it outward. The lock ring is forced outward and into a recess formed in the interior of the wellhead housing. The lock ring and the ratchet ring locks the packoff and casing hanger into place with the wellhead housing without the need of external lockdown screws, thereby minimizing leak paths.

Abstract: In some embodiments, apparatus useful for preventing the premature setting of upper slips of a downhole tool in a well bore prior to reaching the desired setting location in the well bore includes at least one locking mechanism and at least one sleeve. The locking mechanism is configured in a first position to prevent the upper slips from engaging the well bore wall before being positioned at the desired setting location in the well bore and is moveable into a second position that allows the upper slips to be moved into engagement with the well bore wall. A sleeve is moveable axially in the direction of the lower end of the downhole tool and configured to move the locking mechanism from its first to its second positions and also to move the upper slips axially relative to the downhole tool into engagement with the well bore wall.

Abstract: A technique facilitates connection and disconnection of an upper completion with respect to a lower completion. An overall completion system comprises the upper completion releasably engaged with the lower completion. The upper completion and the lower completion may comprise hydraulic line segments and electrical line segments which are coupled via at least one hydraulic wet connect and at least one inductive coupler, respectively. The hydraulic line segments may comprise hydraulic control line segments, chemical injection line segments, or a variety of other types of hydraulic line segments that may be selectively engaged and disengaged by the at least one hydraulic wet connect.

Abstract: An apparatus for, and method of, lowering items from a drilling rig to a well located below it through the use of a landing string comprised of drill pipe having an enlarged diameter section with a shoulder, in combination with upper and lower holders having wedge members with shoulders that engage and support the drill pipe at the shoulder of the enlarged diameter section, the shoulder of the drill pipe and the shoulders of the wedge members being rotatable with respect to each other.

Abstract: A wellhead assembly including a wellhead housing. The wellhead housing comprises a throughbore having a recessed sealing area and a tubing hanger positioned in the throughbore. A seal is positioned between the wellhead housing and the tubing hanger, the seal being positioned so as to form a gap between the seal and the wellhead housing. The wellhead assembly can further include a seal energizer capable of moving relative to the seal in a manner that forces the seal against the wellhead housing to bridge the gap. A method of installing a tubing hanger into a throughbore of a wellhead housing is also disclosed.

Abstract: An apparatus (100) for installing a liner string (102) in a wellbore casing (40). The apparatus (100) includes a tubular mandrel subassembly (110), a load transfer subassembly (140) and an expander cone subassembly (142). The load transfer subassembly (140) is carried on the tubular mandrel subassembly (110) and is operable to apply a force in the downhole direction to the liner string (102). The expander cone subassembly (142) is carried on the tubular mandrel subassembly (110) and is operable to radially expand at least a portion of the liner string (102) into contact with the wellbore casing (40) when axially moved through the liner string (102). In operation, decoupling of the load transfer subassembly (140) from the tubular mandrel subassembly (110) enables release of the apparatus (100) from the liner string (102).

Abstract: A shifting tool and method of shifting a downhole device that requires only a minimal profile or no profile to engage and move the movable portion of the tool. The invention comprises a ported housing assembly and at least one friction pad alignable with said at least one port and radially movable through the port between a first pad position and a second pad position. In the second pad position, the friction pad extends outside said outer diameter of said housing assembly to engage the targeted downhole device. A mandrel positioned through the ported housing has a first section with a first outer diameter and a second section with a second outer diameter, said second outer diameter being greater than said first outer diameter. The mandrel is movable between a first mandrel position and a second mandrel position. In the second mandrel position, the second outer diameter supports the friction pads in the second pad position.

Abstract: In one embodiment, a tubular gripping assembly for use with a top drive to handle a tubular includes a tubular gripping tool having a mandrel and gripping elements operatively coupled to the mandrel; and a link assembly attached to the mandrel, wherein a load of the link assembly is transferred to the mandrel. In another embodiment, the tubular gripping assembly includes a swivel having selectively actuatable seals. In yet another embodiment, the tubular gripping assembly includes a thread compensator to facilitate tubular make-up. In yet another embodiment, the tubular gripping assembly includes a wedge lock release apparatus to facilitate the release of gripping elements from the tubular.

Abstract: A method and apparatus for conducting earth borehole operations comprising a CT system comprising a first carrier with a reel of CT and a CT injector, a second carrier comprising a top drive rig having a mast, and a lifter operative to move the CT injector from the first carrier to an operative or near operative position with respect to the mast on the second carrier.

Abstract: A system and method for positioning a tool within a wellbore, wherein the interior surface of a positioning apparatus includes one or more pluralities of grooves, each defining a selected profile. A tool is lowered into the positioning apparatus, having a blade in communication therewith. The blade includes a plurality of protruding members, which define a profile complementary to at least one of the selected profiles formed by one of the pluralities of positioning apparatus grooves. A biasing member, in communication with the blade, can continually bias the blade toward the interior surface of the positioning apparatus to cause the profile of the blade to engage within the corresponding complementary profile of the positioning apparatus. Positioning a tool in this manner is advantageous for locating cutting tools at a precise location to sever a joint, perforate casing or stack multiple tool operations at a fixed, targeted point within a wellbore.

Abstract: A technique enables anchoring of a tool in a wellbore. The technique provides traction against a well component without creating high stress concentrations that weaken the well component. An anchoring device comprises anchoring members that are selectively movable to an expanded configuration for anchoring the tool. The anchoring members have traction surfaces able to selectively engage a smooth anchoring surface of the well component at any desired location along the well component. Each traction surface is formed to facilitate traction while minimizing stress concentration.

Abstract: Methods and apparatus are provided to place a conductor pipe and a casing in a subsea environment. In one embodiment, a conductor pipe is jetted or drilled into the subsea floor. Thereafter, a casing drilling assembly comprising a drill casing and a drilling assembly is connected to the drill pipe using a crossover. The drilling assembly urged into the seafloor until a casing latch on the drilling assembly is engaged with a casing profile of the conductor pipe. During drilling, instrumentation in the drilling assembly may be used to measure geophysical data. The measured data may be used to optimize the drilling process. After the drill casing is engaged with the conductor pipe, cementing may be performed to set the drill casing.

Abstract: An adjustable mudline suspension system, including a tubing hanger having an exterior profile, a clamp having an inner profile to mate with the exterior profile of the tubing hanger, a biasing element to bias the clamp radially inward into an engaged position where the inner and exterior profiles are mated, and a piston to bias the clamp radially outward into a disengaged position where the inner and exterior profiles are not mated when hydraulically actuated. The weight of the tubing hanger is supported by the adjustable mudline suspension system when the interior profile of the clamp mates with the exterior profile of the hanger.

Abstract: A magnet assembly can be attached to, or placed in the vicinity of, a conventional bell nipple to generate a magnetic field within the central bore of the bell nipple. The magnetic field catches falling metal objects and prevents such objects from passing beyond the bell nipple and entering the subterranean portions of a wellbore. An optional diverter assembly slows the velocity of falling metal objects before reaching the magnet assembly, while also wiping the outer surface of pipe or other items lowered into a wellbore.

Abstract: Methods, systems, and devices related to downhole wellbore operations such as drilling and completing wells in an earth formation include a laser device.

Abstract: Systems and methods are provided that may include employing a lockscrew to provide radial and axial force in connecting tubular members in a mineral extraction system. The lockscrew may be angled relative to the tubular members, at an angle that is greater than 0 degrees and less than 90 degrees. Further, the lockscrew may have an end portion which mates with a slot in a locking segment, and the lockscrew and locking segment may be moved from an unlocked to a locked position. In a locked position, the lockscrew exerts force axially downward and radially inward to push the locking segment against a tubular member, locking the member in place. The interconnection between the lockscrew and the locking segment may enable easier installation and may utilize parts which may be easier to manufacture. Furthermore, the angle of the lockscrew may provide improved support for tubular members.

Abstract: A system comprises a tubular releasably coupled to a launcher. An expansion assembly is sealingly engaged with the tubular so that the expansion assembly is moved longitudinally through the tubular by applying a pressurized fluid to the launcher. The expansion assembly radially expands the tubular as it moves longitudinally therethrough. A valve is coupled to the expansion assembly and opens when fluid pressure within an unexpanded portion of the tubular exceeds fluid pressure within the launcher. An extending member is coupled to the expansion assembly and to the launcher. The extending member restricts longitudinal movement of the expansion assembly relative to the launcher once the tubular is radially expanded.

Abstract: Apparatus and methods for engaging and gripping a tubular, with the apparatus including a sleeve having a body defining an internal chamber therein, with the sleeve configured to receive the tubular through the internal chamber. The apparatus may also include a laterally translatable spider disposed at least partially in the sleeve and including a bore to receive the tubular.

Abstract: A liner top packer is configured to be secured in a liner string, such as in a liner drilling operation. The packer is actuated from within the liner or packer body. An actuator assembly includes an inner piston, an actuator housing, and an outer piston. A tubular setting tool is moved upwardly through the inner piston, and dogs on the setting tool allow for force to be applied to the inner piston, pressurizing fluid and forcing it to the outer piston to compress a pack off element. The actuator assembly is removed by upward force applied by a foot of the setting tool on the inner piston, the actuator housing, or any other component of the actuator assembly.

Abstract: A bottom hole assembly (BHA), adapted to be positioned in a casing and to isolate a portion of a wellbore, which includes a packer assembly with a first sealing element extending between first and second portions of the packer assembly. A method of setting a BHA in a casing which includes increasing a BHA pressure to activate an anchor assembly, applying a mechanical force to mechanically deform a first sealing element to thereby establish an initial seal between the first sealing element and an interior surface of the casing, and increasing a pressure in a space between the BHA and the casing and in a cavity within the BHA to increase a differential pressure across the first sealing element and thereby establish a pressure-energized seal between the first sealing element and the interior surface of the casing.

Abstract: An annular sealing element to seal between metal surfaces for use in flanges, joints, packers and the like, located in oil and gas exploration and production equipment. The sealing element has inner and outer metal deformable surfaces joined at ends, defining an interior volume which is entirely filled with a plastic deformable material. The surfaces are arranged such that on compression of the element from the ends, the element will deform in a controlled manner on a cantilever principle. The volume of filler and the interior volume remain substantially equal during compression so that delamination does not occur. Thus the sealing element provides a seal combining the flexibility of elastomer seals with the integrity of a metal to metal seal.

Abstract: In certain embodiments, a hanger running tool includes an inner sleeve and an outer sleeve. The inner sleeve has a first mating surface configured to engage a second mating surface of a hanger to couple the inner sleeve to the hanger. The outer sleeve is disposed about the inner sleeve. The outer sleeve is configured to rotate about a common longitudinal axis with respect to the inner sleeve.

Abstract: An apparatus for holding and launching down-hole actuation devices that has a body, a bottom end, a top end and a long bore between the ends. Moveable and protruding into the long bore are retainers upon which down-hole actuation devices may rest. Retainers are moved by a lockable hydraulic drive system. Additionally, a method for loading the apparatus with down-hole actuation devices and for launching said devices into a well bore is provided.

Abstract: A system and method for lining a section of a wellbore with an expandable tubular element. The system comprises an elongate drill string having a force multiplier near a lower end thereof, which is housed within the expandable tubular element. An expander for expanding the tubular element is arranged at a lower end of the force multiplier. Anchoring means are provided at the exterior of the tubular element for anchoring the tubular element in the wellbore. Pulling the expander through the expandable tubular using the force multiplier may be combined with pulling the drill string upwards. A sudden drop of the hydraulic pressure in the force multiplier drops will confirm fixation of the anchoring means in the wellbore wall.

Abstract: A velocity string installation method comprises the steps of: removing an existing safety valve from a production tubing safety valve nipple; running a velocity string into the production tubing to engage the safety valve nipple; and then running a velocity string safety valve into the velocity string and coupling the safety valve with a port at the safety valve nipple.

Abstract: An anchor tool has a body, a plurality of slips coupled to the body, each of the slips hingedly coupled to a link at a first end, each of the slips slidably retained in a channel at a second end and each of the slips operably moveable from a retracted orientation to an expanded orientation.

Abstract: An apparatus for separating a downhole tubular string into two parts. The apparatus includes a receptacle operably associated with a first part of the downhole tubular string and a mandrel operably associated with a second part of the downhole tubular string. First and second sleeves each having a profile are slidably positioned between the receptacle and the mandrel and are operable to be securably coupled to the mandrel in first and second positions relative to the mandrel. First and second rings are respectively positioned between the profiles of the first and second sleeves and the profiled surface of the receptacle. The first and second rings are operable to initially limit longitudinal movement of the receptacle relative to the mandrel, to prevent tubular string recoil during operation and to allow longitudinal movement of the receptacle relative to the mandrel after operation.

Abstract: A dual seal system and related method seal a tubing hanger. In an embodiment, a dual seal tubing hanger includes a hanger body. The dual seal tubing hanger also includes an upper body seal and an upper body seal ring. The upper body seal is disposed between the hanger body and the upper body seal ring. In addition, the dual seal tubing hanger includes a lower body seal and a lower body seal ring. The lower body seal is disposed between the lower body seal ring and the hanger body. The upper body seal and the upper body seal ring are disposed on an opposing end of the hanger body from the lower body seal and the lower body seal ring.

Abstract: To deploy a capillary string through a wellhead to a downhole safety valve, a control port and a retention port are drilled in an adapter between a casing hanger and a gate valve or elsewhere. The capillary string is connected to a first port of a capillary hanger and installed through the wellhead. The capillary hanger is landed on a tubing hanger, and a side port on the capillary hanger communicates with the control port. Because the side port's location may not align with the control port, operators may need to measure how long the capillary hanger should be. A control line connects to the control port in the wellhead's side to communicate with the capillary line, and a retention rod inserts in the retention port to support the capillary hanger.

Abstract: A downhole tool includes a body supported from a running string; and a releasing assembly for releasing from set liner hanger portions of the tool to be retrieved to the surface. The releasing assembly includes a connecting member for engaging the tool with a liner hanger, a piston hydraulically moveable in response to fluid pressure within the tool body from a lock position to a release position for releasing the connecting member, and a clutch for rotationally releasing the tool body from the liner hanger. Rotation of the running string moves a nut upward along the body so that the running string may then be picked up to disengage the tool from the liner hanger.

Abstract: A method of maintaining a location of a wellbore servicing device includes connecting a pressure activated hold-down tool (PAHT) to the wellbore servicing device, delivering the wellbore servicing device and the PAHT into a wellbore, selectively increasing a curvature of the PAHT in response to a change in a fluid pressure, and engaging the PAHT with a feature of a wellbore to prevent longitudinal movement of the wellbore servicing device. A PAHT has pressure actuated elements that selectively provide an unactuated state in which the PAHT lies substantially along a longitudinal axis and the pressure actuated elements selectively lie increasingly deviated from the longitudinal axis in response to a change in pressure applied to the PAHT. At least one of the pressure actuated elements has a tooth configured for selective resistive engagement with a feature of the wellbore.

Abstract: A downhole locator apparatus, including a tool body having a central axis defined therethrough, and at least one locator lug radially expandable from the tool body, in which the at least one locator lug is configured to be received in an annular groove formed in an inner surface of a casing string, in which the at least one locator lug is configured to move radially between a retracted position and an expanded position.

Abstract: The invention is directed to a system and method for monitoring and controlling a snubbing unit having traveling slips and stationary slips. Position sensors are associated with the slips for detecting opened and closed positions of the slips. Load sensors are associated with the slips for detecting load status of the slips. A control system receives input signals from the sensors, and confirms that either the traveling slips or the stationary slips are loaded before releasing or allowing the release the opposing set of slips, when transferring the pipe string load from the one set of slips to the other set of slips.