Abstract: The present disclosure describes a cable head for a wireline tool that includes a housing that comprises an outlet opening for a wireline and an interface configured to connect the housing to the wireline tool; a spool rotatably mounted in the housing; an anchoring point configured for mechanical attachment to an end of the wireline; and a drive configured to rotate the spool and thereby wrap a portion of the wireline around the spool to and retract the wireline into the housing. A wireline tool and a method of retrieving a lost wireline tool are also described.

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: An assembly and a method for maintaining and inspecting a wellbore are described. The assembly includes a body. Multiple magnetic wheel sub-assemblies are adjustably coupled to the body. The magnetic wheel sub-assemblies position the body within the wellbore and reposition relative to the body in response to a wellbore narrowing or a wellbore widening. The assembly includes a tool connection coupled to the body. The tool connection couples a well tool to the body. The assembly includes a control sub-assembly to control the magnetic wheel sub-assemblies and operate the well tool within the wellbore. The assembly includes a power sub-assembly to supply power to the control sub-assembly and the well tool. The assembly includes a backup retrieval mechanism coupled to the body. The backup retrieval mechanism couples to a retrieval tool.

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: Techniques for separating cuttings from liquid include circulating a drilling fluid that comprises a liquid and formation cuttings to a scree of a screen assembly that includes screen sections; vibrating the screen assembly during circulation of the drilling fluid; while vibrating the screen assembly, separating the liquid from the plurality of formation cuttings; while vibrating the screen assembly, separating a first portion of the formation cuttings of a first size from the drilling fluid with a first screen section; rotating the screen assembly; subsequent to rotating the screen assembly and while vibrating the screen assembly, separating a second portion of the formation cuttings of a second size different than the first size from the drilling fluid with a second screen section; directing the separated liquid through the screen assembly to a liquid outlet; and directing at least one of the first or second portions of the formation cuttings to a cuttings outlet formed in the screen.

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: A fluid pit safety system is disclosed to prevent drowning incidents in a fluid pit filled with a fluid. The system comprises a plurality of sensors spatially disposed adjacent the fluid pit, a perimeter detection sub-system defining a perimeter arranged around an edge of the fluid pit, and a rescue device arranged in the fluid pit. The plurality of sensors are configured to detect a change in fluid height in the fluid pit. The perimeter detection sub-system is configured to detect a disruption in the perimeter. The rescue device is configured to move towards a surface of the fluid in the fluid pit in response to the plurality of sensors detecting the change in the fluid height in the fluid pit and the perimeter detection sub-system detecting the disruption in the perimeter.

Abstract: A bell nipple includes a downhole end configured to sealingly couple to an uphole-end of a blow-out preventer. An uphole end of the bell nipple includes a first set of threads along an inner surface of the bell nipple. A thread saver is configured to be received by the uphole end. The thread saver is configured to protect the first set of threads from impact. An extension sub is configured to be received by the uphole end. The extension sub includes a downhole end with a second set of threads configured to engage with the first set of threads. An uphole end of the extension sub includes a third set of threads configured receive a well tool.

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: A downhole sealant injection system includes a first casing configured to be positioned in a wellbore and a second casing configured to be positioned in the wellbore within the first casing. Cement at least partially fills an annulus between the interior of the first casing and the exterior of the second casing. A first sealant injection tool is configured to be attached to the exterior of the second casing, and is positioned at a downhole location and within an annulus between the interior of the first casing and the exterior of the second casing. The sealant injection tool includes a plurality of nozzles configured to inject sealant into voids within the cement in the annulus between the interior of the first casing and the exterior of the second casing.

Abstract: Downhole flow control valves include a valve assembly, driven gear, drive gear, and motor. The valve assembly includes an outer sleeve and inner sleeve. The outer sleeve has openings and a fixed guide. The inner sleeve is disposed within the outer sleeve and includes an outer surface and an axially abutting surface defining a stair-stepped pathway. The fixed guide abuts against the axially abutting surface. The abutment of the fixed guide against the axially abutting surface of the inner sleeve causes the inner sleeve to translate axially between an open position and a closed position relative to the outer sleeve when rotated through operation of the motor, drive gear and driven gear. Systems for controlling fluid flow from lateral branches of a multilateral wellbore include at least a plurality of the downhole flow control valves and a downhole electrical power source for generating electrical power to operate the motor.

Abstract: A drilling fluid shaker screen system includes a screen assembly that includes a screen including a plurality of screen sections. A first screen section includes a first screen mesh size and a second screen section includes a second screen mesh size different than the first screen mesh size. The drilling fluid shaker screen system further includes a rotation assembly mounted to the screen assembly. The rotation assembly includes one or more rollers moveable to rotate the screen assembly about an axis of rotation. The drilling fluid shaker screen system further includes a motor assembly coupled to the screen assembly and configured to vibrate the screen assembly. A housing includes a cuttings outlet that is fluidly coupled to a cuttings inlet formed in the screen and a liquid outlet separate from the cuttings outlet that is fluidly coupled to the plurality of screen sections.

Abstract: Downhole flow control valves include a valve assembly, driven gear, drive gear, and motor. The valve assembly includes an outer sleeve and inner sleeve. The outer sleeve has openings and a fixed guide. The inner sleeve is disposed within the outer sleeve and includes an outer surface and an axially abutting surface defining a stair-stepped pathway. The fixed guide abuts against the axially abutting surface. The abutment of the fixed guide against the axially abutting surface of the inner sleeve causes the inner sleeve to translate axially between an open position and a closed position relative to the outer sleeve when rotated through operation of the motor, drive gear and driven gear. Systems for controlling fluid flow from lateral branches of a multilateral wellbore include at least a plurality of the downhole flow control valves and a downhole electrical power source for generating electrical power to operate the motor.

Abstract: A method for identifying a drill string washout during wellbore drilling includes operating a drill bit in a wellbore. The drill bit is disposed at a downhole end of a drill string. The method further includes circulating a washout detection composition through the drill string and back to a surface of the wellbore. The washout detection composition includes a carrier fluid and a detecting material that includes strings, wires, fibers, or combinations of these. The method further includes removing the drill string from the wellbore, and determining a location of the drill string washout by inspecting the drill string. The drill string washout is characterized by at least one washout opening in the drill string. The location of the at least one washout opening is identified by at least a portion of the detecting material extending through the at least one washout opening in the drill string so that the detecting material is visible from an exterior of the drill string.

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: A downhole welding tool includes a tool body and a welding device coupled to the tool body. The welding device includes a carrier arm reversibly pivotable between a collapsed configuration of the welding device in which the carrier arm is oriented parallel to the tool body and an extended configuration of the welding device in which the carrier arm projects outward from the tool body at an acute angle relative to the tool body, as well as a consumable welding tip secured to the carrier arm. The downhole welding tool also includes a rotatable actuator coupled to the tool body adjacent the welding device and configured to adjust the carrier arm between the collapsed configuration and the extended configuration.