Abstract: A cementing string assembly for cementing a liner in a wellbore includes a drill pipe, a liner hanger running tool attached to the drill pipe, a liner releasably secured to the liner hanger running tool, an upper wiper plug disposed within the liner and releasably secured to the liner hanger running tool or to the liner, and a lower wiper plug disposed within the liner and releasably secured to the liner downhole of the upper wiper plug. The lower wiper plug is detached from the upper wiper plug. The lower wiper plug is releasably secured to an inner surface of the liner by a wiper plug hanging collar and is releasable from the liner independent of the upper wiper plug and without exerting forces on the upper wiper plug. The cementing string assembly prevent premature and unintentional release of the upper wiper plug while releasing the lower wiper plug.

Abstract: The centralizer also includes a body defining a central bore and a plurality of cavities fluidically coupled to the central bore and an exterior of the body, where the plurality of cavities are located between the central bore and an outer surface of the body. The centralizer also includes a plurality of springs with each housed in one of the plurality of cavities. The centralizer also includes a plurality of pistons with each housed in one of the plurality of cavities and abutting a respective spring in that cavity. The centralizer also includes a centralizer pad pivotally connected to each of the plurality of pistons and extending radially from a longitudinal axis of the body in response to bias from the plurality of springs.

Abstract: The centralizer also includes a body defining a central bore and a plurality of cavities fluidically coupled to the central bore and an exterior of the body, where the plurality of cavities are located between the central bore and an outer surface of the body. The centralizer also includes a plurality of springs with each housed in one of the plurality of cavities. The centralizer also includes a plurality of pistons with each housed in one of the plurality of cavities and abutting a respective spring in that cavity. The centralizer also includes a centralizer pad pivotally connected to each of the plurality of pistons and extending radially from a longitudinal axis of the body in response to bias from the plurality of springs.

Abstract: A system includes an integrated liner hanger assembly that includes a liner hanger, a packer, and a cement retainer sub. The cement retainer sub includes a plurality of fluid passageways connecting a central bore of the liner hanger assembly to an annular volume downhole of the packer and uphole of the liner hanger. A running tool is configured to axially translate a sliding sleeve of the cement sub from a closed position to an open position in which flow if permitted through the passageways, and from the open position to a closed-and-locked position. In some embodiments, the system is configured such that running the assembly into the wellbore, actuating the liner hanger, actuating the packer assembly, translating the sliding sleeve from the closed and open position and from the open position to the closed-and-locked position, are completed in a single trip.

Abstract: A cross BOP swivel joint for crossing over a blowout preventer of a drilling apparatus includes a swivel housing, an internal pipe received through the swivel housing. The internal pipe includes an upper loading shoulder and a lower loading shoulder. The cross BOP swivel joint includes an upper journal bearing, lower journal bearing, and at least one central bearing between the swivel housing and the internal pipe. The central bearings are axially disposed between the journal bearings. When engaged, the BOP contacts the outer surface of the swivel housing of the cross BOP swivel joint. The journal bearings allow the internal pipe to rotate relative to the swivel housing when the BOP is engaged with the swivel housing. This allows rotation of the drill string during well control events. The central bearing provides radial support to the swivel housing to reduce inward deflection of the swivel housing.

Abstract: An apparatus includes a housing, engagement slips, a tubular, a taper tap, a pin, and a slip activation member. The housing includes a profile that defines a path including a first end and a second end. The engagement slips are attached to the housing. The tubular passes through an opening of the housing. The taper tap is rotatable and connected to the housing. The pin is connected to the tubular and received by the profile of the housing. The tubular is translatable with respect to the housing based on the pin translating along the path defined by the profile. The slip activation member is connected to the tubular. The slip activation member is configured to move each of the engagement slips radially outward with respect to the housing when the pin translates to the second end of the path.

Abstract: Systems and methods for accessing a wellbore of a subterranean well downhole of abandoned subterranean wellbore equipment include a re-entry guide secured to an uphole end of an overshot. The re-entry guide and overshot together form a re-entry tool. The overshot has an inner diameter gripping assembly sized to grip a tubing stub. The re-entry guide has an outer diameter sized to match a drift inner diameter of a casing of the subterranean well.

Abstract: Tools and methods are described for removing a packer beyond a restriction in a casing of a wellbore. A packer milling tool includes: a milling body with an outer diameter; milling blocks positioned at intervals around a circumference of the milling body, each milling block pivotably attached to the milling body and pivotable between a running position and a milling position; and a wash pipe extending from a downhole end of the milling body. The milling blocks have a rotational circumference with a rotational diameter that is less than the outer diameter of the milling body when in the running position and the rotational diameter is more than the outer diameter of the milling body and less than the inner diameter of the casing when in the milling position.

Abstract: A wellhead assembly that includes a wellhead disposed at a surface of a wellbore, a production tree fluidically coupled to the wellhead, and a telescopic adaptor assembly residing between and fluidically coupled to the wellhead and the production tree. The telescopic adaptor assembly extends or retracts to change an elevation of the production tree with respect to the wellhead and rotates to change a radial position of the production tree with respect to the wellhead. The telescopic adaptor assembly includes a flange attached to the wellhead and a first pipe rotationally coupled to the flange. The first pipe is rotational about a longitudinal axis of the first pipe. The telescopic adaptor assembly includes a second pipe attached to the production tree and is disposed concentrically inside the first pipe. The second pipe is movable along the longitudinal axis with respect to the first pipe.

Abstract: A sidetrack window is cut in a cased wellbore by disposing a sidetracking assembly within the cased wellbore. A first ball is deployed into a drill string of the sidetracking assembly. The first ball leaves the drill string and lands on a ball seat of a cement retainer to block fluid outlet of the cement retainer. Then, the cement retainer is set and a second fluid outlet of the cement retainer is exposed. Cement is flowed through the drill string to the portion of the cased wellbore downstream of the cement retainer to plug the portion of the wellbore. The whipstock assembly is separated from the cement retainer. A second ball is deployed inside the drill string to land on the seat of the whipstock assembly to block a fluid outlet of the whipstock assembly. The whipstock assembly is anchored in the cased wellbore and the milling system is actuated to begin cutting the sidetrack window.

Abstract: A fluid management system for controlling fluid flow at a wellbore includes a closing element formed complementary to a drill pipe disposed within the wellbore and an activation system. The activation system is configured to move the closing element into an activated position against the drill pipe to close the wellbore around the drill pipe for preventing fluid from flowing out of the wellbore. The activation system includes an activation shaft coupled to the closing element and a rotatable drive shaft configured to cause translation of the activation shaft to push the closing element into the activated position against the drill pipe.

Abstract: A downhole tool assembly including a bridge plug and a cement retainer in tandem to be deployed into a wellbore on the same run or trip for remedial cementing of the wellbore.

Abstract: Systems and methods for accessing a wellbore of a subterranean well downhole of abandoned subterranean wellbore equipment include a re-entry guide secured to an uphole end of an overshot. The re-entry guide and overshot together form a re-entry tool. The overshot has an inner diameter gripping assembly sized to grip a tubing stub. The re-entry guide has an outer diameter sized to match a drift inner diameter of a casing of the subterranean well.

Abstract: Systems and methods for retrieving equipment from a wellbore of a subterranean well include an overshot housing having a central axis. The overshot housing is a tubular shaped member with a housing bore. An internal sleeve is located within the overshot housing. The internal sleeve is a tubular shaped member with a sleeve bore. The internal sleeve is axially moveable within the overshot housing. A catching net is located radially outward of the internal sleeve, within the overshot housing. The catching net moveable between a contracted position and an extended position. The catching net has a shorter axial length and a wider radial width in the contracted position than in the extended position. An anchoring assembly is located at a downhole end of the catching net. The anchoring assembly is actuable to releasably secure the downhole end of the catching net to the equipment.

Abstract: A pipe segment includes an outer pipe including a shaft wall, a first connector disposed at a first end of the shaft wall, and a second connector disposed at a second end of the shaft wall opposite the first end. The pipe segment further includes an electrical cable extending through the shaft wall along a length of the outer pipe between the first and second connectors and an inner pipe positioned within the outer pipe and surrounding the electrical cable, the inner pipe being movable axially with respect to the outer pipe, and the outer pipe being movable rotationally with respect to the inner pipe.

Abstract: A method of performing a logging operation at a wellbore includes providing first and second pipe segments respectively including a first internal electrical cable and a second internal electrical cable, connecting a first end of the first internal electrical cable to a wireline cable of a logging tool to form a drill pipe string, lowering the drill pipe string, including the logging tool and the first pipe segment, into the wellbore, connecting a first end of the second internal electrical cable to a second end of the first internal electrical cable to add the second pipe segment to the drill pipe string, lowering the drill pipe string, including the logging tool, the first pipe segment, and the second pipe segment, into the wellbore, and connecting a second end of the second internal electrical cable to a surface logging unit to couple the surface logging unit to the drill pipe string.

Abstract: A swivel includes a male segment, a female segment, and a lock pin. The male segment can mate with the female segment, and the lock pin can pass through the female segment and engage with the male segment to prevent relative axial movement of the male segment and the female segment while allowing relative rotational movement of the male segment and the female segment. The male segment includes a first conductive ring configured to couple to a first wire. The female segment includes a second conductive ring configured to couple to a second wire. Contact between the first and second conductive rings establishes an electrical connection between the first and second wires.

Abstract: Tools and methods are described for removing a packer beyond a restriction in a casing of a wellbore. A packer milling tool includes: a milling body with an outer diameter; milling blocks positioned at intervals around a circumference of the milling body, each milling block pivotably attached to the milling body and pivotable between a running position and a milling position; and a wash pipe extending from a downhole end of the milling body. The milling blocks have a rotational circumference with a rotational diameter that is less than the outer diameter of the milling body when in the running position and the rotational diameter is more than the outer diameter of the milling body and less than the inner diameter of the casing when in the milling position.

Abstract: A packer assembly includes a tubing string disposed in a wellbore and a packer releasably coupled to the tubing string. The packer includes a housing releasably coupled to the tubing string, a packer slip, a flexible sealing element, a piston coupled to the housing, a locking member, and a mandrel disposed inside the housing. The piston moves to activate the packer slip and the flexible sealing element to set the packer on a wall of the wellbore. The locking member engages the piston to constrain movement of the piston to keep the packer set on the wall of the wellbore. The mandrel connects to the tubing string when the tubing string is released from the housing. The locking member is collapsible to disengage the piston to unset the packer slip and the flexible sealing element responsive to shear force applied by the mandrel to the locking member.

Abstract: A downhole tool includes a streamlined housing sized to freely move through a wellbore formed from a terranean surface to a subterranean formation; an explosive material enclosed within an interior volume of the housing, the explosive material sufficient to cut at least a portion of a tubular positioned in the wellbore upon detonation; a detonator coupled to the explosive material; and a detonator control system communicably coupled to the detonator and configured to activate the detonator with a detonation signal to detonate the explosive material.