Abstract: The disclosed embodiments include multilateral completion systems and methods to deploy multilateral completion systems. A multilateral completion system includes a main bore completion having an inductive coupler, a lateral completion having an inductive coupler, and a second lateral completion also having an inductive coupler. The multilateral completion system also includes a junction having an inductive coupler, and a second junction having an inductive coupler.

Abstract: The present application relates to a locking apparatus for locking axial ends of first and second drilling rig components in a connected state, the connected state established by sufficiently rotating the first drilling rig component relative to the second drilling rig component in a first direction. The apparatus includes a first locking means that enables the first and second drilling rig components to be locked in their connected state by causing, during rotation of the first drilling rig component in the first direction, the locking apparatus to engage with the first drilling rig component in a configuration that prevents the first drilling rig component from rotating in a direction opposite to the first direction.

Abstract: A rod handler apparatus for outer tubes and inner tubes, the rod handler apparatus has a manipulator arm adapted to be aligned with an elongated rod. An alignment jaw assembly is at a first end of the manipulator arm, the alignment jaw assembly translationally supports an inner tube and/or an outer tube in coaxial alignment with the elongated rod. A high-speed jaw assembly is at a second end of the manipulator arm, the high-speed jaw assembly adapted to support at least the inner tube, the high-speed jaw assembly operable to cause a translation of the inner tube in or out of the elongated rod. A low-speed jaw assembly is between the alignment jaw assembly and the high-speed jaw assembly, the low-speed jaw assembly adapted to support the outer tube, the low-speed jaw assembly operable to cause concurrent translation and rotation of the outer tube for screwing engagement with the elongated rod.

Abstract: A well system includes a casing string extendable into a primary wellbore from a surface rig, and a sidetrack casing assembly coupled to the casing string. The sidetrack casing assembly includes a cylindrical housing that defines a window through a sidewall of the housing, and a cover removably coupled to the housing at the window. The cover is transitionable between a closed state, in which the cover is attached to the housing and occludes the window, and an open state, in which the cover is moved to expose the window for drilling a secondary wellbore from the primary wellbore.

Abstract: A riser fluid handling system for managed pressure drilling includes a tubular portion having a lower end configured to be connected to a riser and an upper end, a spool connected to the upper end of the tubular portion, the spool having a base and a fluid conduit extending radially outward from the base and defining an axially-facing orifice. The fluid conduit is configured to provide fluid communication between the orifice and an interior of the spool. The system includes a valve connected to the fluid conduit and extending parallel to a central longitudinal axis of the tubular portion, the valve being configured to connect to a drape hose such that the drape hose extends axially therefrom and is able to swivel with respect to the spool.

Abstract: A casing running tool is provided, including one or more sensors built into the casing running tool; an electronics housing that includes one or more power sources for powering the one or more sensors; one or more circuit boards for converting sensor data for transmission and transmission means for transmitting sensor data. The one or more sensors sense tool status and operational parameters of the casing running tool. A system is also provided for detection, processing and transmission of one or parameters of tool status and operational status of a casing running tool or associated tools in a casing installation or casing while drilling operation. The system includes a casing running tool; and a processor for receiving sensor data for processing and transmitting processed data in real-time for viewing by an operator. A method is further provided for performing a casing installation or casing while drilling operation.

Abstract: A tubular handling assembly includes an elevator and a tubular compensator assembly. The tubular compensator assembly includes a housing; a lift member coupled to the housing; a support member; and an actuator for moving the housing and the lift member relative to the support member and the elevator.

Abstract: The present disclosure includes a plug for cementing a wellbore. The plug may include a cylinder. The cylinder may include at least one body including a non-conductive material with conductive filaments dispersed within the non-conductive material. The present disclosure also includes float equipment for cementing a wellbore. The float equipment may include a casing segment including an inner surface, drillable material affixed to the inner surface of the casing segment, and a check valve attached to the drillable material. The drillable material may include a non-conductive material and conductive filaments dispersed within the non-conductive material.

Abstract: A cementing pod is disclosed. The cementing pod includes a cylindrical housing with a first end and a second end, and a throughbore disposed through the cylindrical housing in a first axial direction from the first end to the second end. The cementing pod further includes a plurality of openings disposed through the cylindrical housing into the throughbore in a second axial direction, and a solid fill disposed at the second end of the cylindrical housing.

Abstract: A method includes monitoring fluid production at a passive ICD installed in a base pipe in a wellbore. Responsive to monitored fluid production meeting one or more predetermined criteria, a remedial sleeve component is installed for the passive ICD. The remedial sleeve component includes: one or more ports which permit throughput of fluid into the base pipe; a closing portion which selectively opens and closes the one or more ports; and one or more sealing portions, which prevent a flow of fluid into the base pipe when the one or more ports are closed. The one or more ports are selectively opened or closed responsive to one or more additional predetermined criteria. A related system includes an actuation tool which deploys into the wellbore to actuate the closing portion to selectively open and close the one or more ports.

Abstract: A tubular gripping tool for gripping a tubular includes a housing; a mandrel disposed in the housing; a plurality of slips movable along the mandrel; and an engagement member disposed in the housing and movable relative to the mandrel, wherein the engagement member is configured to apply a force against the tubular.

Abstract: A system for remediating a bus sectioning events, such as a bus failure or controlled sectioning, comprises a plurality of nodes coupled together by a bus in a tool string used in a bottom hole assembly (BHA). Each node comprises a bus switch configured to isolate the node from a section of the bus. Upon a bus sectioning event, a first sub-tool string and a second sub-tool string are created on either side of the bus section to be isolated, each of which independently operate in parallel. Communication between the first and second sub-tool buses is established through respective nodes connected to each sub-tool bus that comprise a wireless communication transceiver configured to convey signals along the tool string. Alternatively or additionally, each of the sub-tool buses has a node with telemetry for communicating with the surface. Accordingly, each of the sub-tool busses continues independently operating normally.

Abstract: A system for covering a sensitive component in a downhole string includes a sub section in the downhole string including a longitudinal axis and a reduced diameter portion along the longitudinal axis. The system also includes a guard element, arranged over the reduced diameter portion. The system further includes a mounting system adapted to axially couple the guard element to the sub section. The mounting system includes a pocket in one of the sub section and the guard element, the pocket including a shoulder. The mounting system also includes a threaded bore in the other of the sub section and the guard element, the threaded bore oriented at least partially parallel to the longitudinal axis of the sub section. The mounting system further includes a fastener engaging the threaded bore through the pocket and axially coupling the guard element to the sub section.

Abstract: A disconnect device for use as part of a downhole assembly in an oil or gas well. In one embodiment, the device comprises a lower receptacle assembly comprising a recess profile; an upper assembly comprising: a shaft comprising a fluid passage, a collet comprising collet fingers, a piston, a cylinder assembly, a pressure chamber disposed radially between the shaft and the cylinder assembly, and a spring, wherein the piston is selectively movable into three positions.

Abstract: A system for disassembling a drill assembly including a drill bit and one or more columns interlinked with each other. The system includes a first clamping mechanism adapted to engage one of the drill bit or a first column, and a second clamping mechanism adapted to engage a second column disposed successively to the drill bit or the first column. The second clamping mechanism is turned relative to the first clamping mechanism to at least partially delink the second column from the first column or the drill bit. The system further includes a first actuator adapted to move one of the first clamping mechanism or the second clamping mechanism relative to the other to define a gap therebetween to reveal an interface between the second column and the drill bit or the first column for delinking the second column relative to the drill bit or the first column.

Abstract: A roller tool 1 that can be connected into a string for deployment into an oil or gas well includes at least two rollers or wheels 10 located on each side of the roller tool 1, with axes of rotation that are perpendicular to the axis of the roller tool 1. The roller tool further includes at least two interconnecting tubular portions, where one tubular portion 41 comprises a mandrel 45 that connects to another tubular portion 42. An annular hub 20 is fitted over the mandrel 45 and the rollers 10 are connected onto the hub 20. The tubular portions 41, 42 comprise circumferential sleeve sections 56a, 56b that partially extend over the rollers 10 and resist detachment of the rollers 10 from the roller tool 1. The roller tool 1 can aid passage of a string through a well by holding the string away from the walls of the well and reducing frictional contact.

Abstract: A flow control system for a well includes a primary safety valve and a secondary safety valve disposable within a valve body of the primary safety valve. The secondary safety valve may include a control line port for receiving control fluid pressure from the same control line as the primary safety valve. A choke in fluid communication with the control line port delays a closing of the secondary safety valve relative to a closing of the primary safety valve in response to a decrease in the control fluid pressure.

Abstract: A wellhead hanger assembly is provided. In one embodiment, a system includes a wellhead hanger, an inner sleeve coupled to the wellhead hanger, a running tool coupled to the inner sleeve, and an outer sleeve coupled to the running tool. The outer sleeve may be positioned to transmit torque from the running tool to the wellhead hanger, and the wellhead hanger may be in castellated engagement with the outer sleeve via a set of castellations and mating slots. Additional systems, devices, and methods are also disclosed.

Abstract: A geothermal well is provided including a first tube including at least one opening in a first depth; a second tube having a closed bottom in a second depth; and a third tube having a closed bottom in a third depth. The first tube is inside the second tube, which is inside the third tube, wherein the first tube has at least one opening in fluid communication with a first interspace between the first tube and the second tube; wherein the third depth and the first depth are smaller than the second depth. Through-holes are formed in the second tube above the bottom of the third tube, which allow fluid communication between the first interspace and a second interspace between the second tube and the third tube. A first sealing element and a heat insulating material are disposed in the first interspace above the through-holes.

Abstract: A system for transferring fluid from a pump to a manifold, the manifold having a plurality of fluid inlets. A first pump truck includes a first pump having a first fluid outlet. A first flexible pipe couples the first fluid outlet to a first fluid inlet. The first flexible pipe is self-supporting and forms an arch extending over the first pump truck. The first pump truck may include a second pump having a second fluid outlet and a second flexible pipe may couple the second fluid outlet to a second fluid inlet. A second pump truck may include third and fourth pumps having third and fourth fluid outlets, respectively, that may be coupled to third and fourth fluid inlets by third and fourth self-supporting flexible pipes.

Abstract: A system for transferring fluid from a pump to a manifold, the manifold having a plurality of fluid inlets. A first pump truck includes a first pump having a first fluid outlet. A first flexible pipe couples the first fluid outlet to a first fluid inlet. The first flexible pipe is self-supporting and forms an arch extending over the first pump truck. The first pump truck may include a second pump having a second fluid outlet and a second flexible pipe may couple the second fluid outlet to a second fluid inlet. A second pump truck may include third and fourth pumps having third and fourth fluid outlets, respectively, that may be coupled to third and fourth fluid inlets by third and fourth self-supporting flexible pipes.

Abstract: Provided is a multilateral junction (MLT), a well system, and a method for forming a well system. The MLT, in one aspect, includes a y-block having a housing with a single first bore and second and third bores extending therein, the second and third bores defining second and third centerlines. The MLT, in this aspect, further includes a mainbore leg having a first mainbore leg end coupled to the second bore and a second opposing mainbore leg end, and a lateral bore leg having a first lateral bore leg end coupled to the third bore and a second opposing lateral bore leg end. In this aspect, the mainbore leg and the lateral bore leg are twisted with respect to the second and third bore such that a first plane taken through centerlines of the second opposing mainbore leg end and the second opposing lateral bore leg end is angled.

Abstract: A method for manufacturing a connecting part includes a first portion having a threaded end that is able to be screwed to the end of a first tubular component for connecting the connecting part to said first tubular component, the method comprising a step of producing, by an additive manufacturing method, a second portion of the connecting part juxtaposed with the first portion having a threaded end. Moreover, the first portion having a threaded end is obtained by reworking the first portion on a separate tubular component of the connecting part in order to be joined to the connecting part.

Abstract: A hybrid sensing apparatus for collecting data inside a well, the apparatus including an optical cable that acquires a first set of data; and an array of discrete probes connected to each other with an electrical cable. The discrete probes are configured to acquire a second set of data. The apparatus further includes an attachment system attached to the discrete probes and configured to hold the optical cable. The attachment system is configured to expose the optical cable to directly contact the well.

Abstract: Composite structures and methods of forming composite structures are provided. A composite structure as disclosed herein incorporates one or more composite structure components, such as composite panels and composite inserts. A composite panel is formed from one or more sheets of fiber reinforced thermoplastic material. Composite inserts can include one or more composite blocks or braided sleeves. A composite block can be formed as a stacked or molded structure from trimmings or waste produced during the formation of the composite structures. A braided sleeve can include a seamless, woven sleeve formed of reinforcing fibers and thermoplastic threads. In a completed composite structure, composite inserts are at least partially disposed within a volume defined by surfaces of composite panels. The various composite structures and inserts can be given a final shape and can be fused to one another in a molding and fusing step.

Abstract: A transforming bridge-to-flow-through frac plug has a mandrel, a retaining sleeve, a pair of cones, a pair of slips, a packing element, and a keeper ring. The mandrel is concentrically connected within the retaining sleeve, and is constructed of a dissolvable material such that the mandrel is dissolvable through application of a solvent in order to form a big bore flow-through frac plug if removal of the frac plug by milling is not possible. The pair of cones, pair of slips, packing element, and keeper ring are positioned on the exterior of the retaining sleeve in order to secure the frac plug in place after a setting operation, even if the mandrel is dissolved in order to form the big bore flow-through frac plug.

Abstract: Aspects of the disclosure relate to elevator locking system apparatus and methods, and associated components thereof. In one implementation, a slip-type elevator assembly includes an elevator body including one or more slips configured to grip a tubular, and a first door pivotably coupled to the elevator body. The slip-type elevator assembly includes a second door pivotably coupled to the elevator body, the first door and the second door movable between an open position and a closed position. The slip-type elevator assembly also includes a locking system including a bolt movable between an unlocked position and a locked position. In the unlocked position the bolt is disposed in a first cavity formed in the first door. In the locked position a first portion of the bolt is disposed in the first cavity and a second portion of the bolt is disposed outside of the first cavity.

Abstract: A method and apparatus for patching damaged areas in a well includes a top and a bottom patching section which include an anchor/sealing member for securing the apparatus within the well. One or more extension patch sections are connected between the top and bottom patch sections. The top and bottom patch elements are placed above and below the damaged area to isolate the damaged area from the exterior flow portion of the 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: Valve systems for inserting into casings used in downhole environments are provided. The valve system includes a mandrel, a check valve assembly, and a setting system. The setting system includes a sealing element, a pair of wedges, and a pair of slips, each located on an outer surface of the mandrel. The wedges are separated from each other by the sealing element. Each wedge includes an inner surface configured to slide along the outer surface of the mandrel and an angled surface having a first set of ratchet teeth. The slips are separated from each other by the pair of wedges. Each slip includes an inner surface having a second set of ratchet teeth configured to engage the first set of ratchet teeth. Also, each slip includes an outer surface having gripping elements configured to grip an inner surface of the casing.

Abstract: A system for operation on a subsea well, the system comprising at least one storage unit configured to store tubulars; a subsea mast unit comprising at least two string handling devices configured to handle a tubular string of a plurality of connected tubulars, wherein at least one of the string handling devices is configured to move vertically relative to the other of the string handling devices, and is configured to add a vertical downforce to the tubular string; and at least one handling arrangement for moving tubulars between the at least one storage unit and one of the string handling devices simultaneously with handling of the tubular string by at least one of the string handling devices. A method of lowering a tubular string into a subsea well is also provided.

Abstract: A trailer-mounted drilling rig incorporates a dual top drive apparatus and a plurality of lifting assemblies useable for decreasing connection time of pipe segments useable during well drilling or other well operations, and methods of connecting pipe segments useable during well drilling or other operations. The plurality of lifting assemblies operatively connected to the dual top drive apparatus and a first lifting assembly is capable of moving a first top drive vertically inline with a wellbore while a second lifting assembly is capable of independently moving a second top drive vertically out of alignment with the wellbore.

Abstract: A centraliser includes a number of members extending between two collars for mounting the centraliser on a casing. The members are configured to contact a wall of the bore and centraliser the casing in the bore. The members are radially moveable between the casing and the bore wall. The members further include an intermediate portion and end portions, the end portions being relatively more flexible than the intermediate portion.

Abstract: Equipment and methods for coupling a top drive to one or more tools to facilitate data and/or signal transfer therebetween include a receiver assembly connectable to a top drive; a tool adapter connectable to a tool string, wherein a coupling between the receiver assembly and the tool adapter transfers at least one of torque and load therebetween; and a stationary data uplink comprising at least one of: a data swivel coupled to the receiver assembly; a wireless module coupled to the tool adapter; and a wireless transceiver coupled to the tool adapter. Equipment and methods include coupling a receiver assembly to a tool adapter to transfer at least one of torque and load therebetween, the tool adapter being connected to the tool string; collecting data at one or more points proximal the tool string; and communicating the data to a stationary computer while rotating the tool adapter.

Abstract: An expandable liner is used to re-complete a wellbore for a re-fracturing operation. The expandable liner may be used to cover the old perforations and provide a larger bore after expansion. The larger bore allows the new completion perforations and fracturing operation to be more easily achieved. In one embodiment, an expandable liner an expandable tubular having a threaded connection, wherein the threaded connection includes a groove configured to fail at a predetermined tension load. In another embodiment, the expandable liner may have a rib disposed around an outer diameter of the expandable tubular, wherein the rib is configured to form a seal with the outer tubular.

Abstract: Embodiments described herein provide a multi-diameter thrust device that includes one or more thrust cups. Each thrust cup of the one or more thrust cups includes a first axial end hub disposed at a first axial end of the thrust cup; a second axial end hub disposed at a second axial end of the thrust cup; and a plurality of bowsprings. Each bowspring of the plurality of bowsprings includes a first axial end portion coupled to the first axial end hub and a second axial end portion coupled to the second axial end hub. The plurality of bowsprings are disposed circumferentially about a central axis of the multi-diameter thrust device.

Abstract: A method and apparatus according to which a connection between first and second completion joints is made up. The first and second completion joints each include a base pipe and a shunt tube disposed along the base pipe. The respective base pipes of the first and second completion joints are threadably engaged to form a pin and box connection. The shunt tube of the first completion joint is coupled to the shunt tube of the second completion joint using a jumper tube. The jumper tube is supported at a position longitudinally between the respective shunt tubes of the first and second completion joints using a first support member. In some embodiments, the first support member is longitudinally slidable along the base pipe of the first or second completion joint to the position between the respective shunt tubes of the first and second completion joints.

Abstract: An intervention system is provided. The intervention system comprises a cable being configured to be lowered into a wellbore, said cable having an inner tube enclosing one or more electrical conductors, and an outer tube surrounding the inner tube. The intervention system further comprises a downhole tool being connected to a distal end of the cable and being configured to pull the cable into the wellbore.

Abstract: A sand control assembly includes a base pipe having at least one perforation, a housing, and at least one inflow control device integrated within the housing via an associated ring secured to the housing and the base pipe, the at least one inflow control device and the associated ring creating a seal. The housing is disposed around the exterior of the base pipe, and the housing is secured to a bypass ring at a first end of the housing and secured to the base pipe at a second end of the housing via a weld end ring. A longitudinal axis of the at least one inflow control device is parallel to a longitudinal axis of the base pipe.

Abstract: A wellbore assembly includes a first tube and a second tube. The first tube is disposed within a wellbore and has a first end fixed with respect to a wall of the wellbore. The second tube is coupled to a second end of the first tube. The second tube has a third end opposite the coupling and fixed with respect to the wall of the wellbore. The first tube includes a portion of reduced or increased diameter residing between the first end and the second end. The portion of reduced or increased diameter defines an internal diameter that changes, with the first tube under a compression load, to decrease a length of the first tube. The internal diameter changes, with the first tube under a tensile load, to increase a length of the first tube to accommodate changes in length of the first tube or the second tube or both.

Abstract: The disclosure relates to a carriage apparatus for carrying a tool string down a wellbore in a wireline logging, and an orientation apparatus and hole finder device for a wireline logging tool string. In some embodiments the carriage includes a protection structure which extends longitudinally around a wheel of the apparatus to thereby prevent a side of the wheel from contacting a wall of the wellbore. In some embodiments an orientation apparatus and hole finder are arranged so that the orientation apparatus orientates the hole finder device in the wellbore so that a tip of a nose section of the hole finder is elevated above a low side of the wellbore by a height and offset from and above a longitudinal axis of the tool string.

Abstract: An annular barrier for providing zonal includes a tubular metal part, and an expandable metal sleeve surrounding the tubular metal part. The expandable metal sleeve has a first end part, a second end part and an outer face, and at least one of the end parts includes at least one circumferential groove facing the outer part face, wherein the tubular metal part bulges radially outwards in relation to the axial extension, forming at least one circumferential projection engaging the groove, thus providing a connection of the expandable metal sleeve to the tubular metal part.

Abstract: A setting tool for setting frac plugs and the like can include a mandrel having a chamber for housing expandable gas and a gas port in fluid communication with the chamber; a firing head secured to the mandrel for igniting a power charge to generate pressurized gas within the chamber; a barrel piston housing the mandrel and connected to a sleeve for setting the frac plug; and an expansion region defined between the mandrel and the barrel piston and receiving the pressurized gas which exerts force to cause a stroke of the barrel piston over the mandrel as the expansion region expands axially. The setting tool can include various features, such as certain gas bleed systems, an enhanced shear screw assembly, a bleed port and plug assembly, a scribe line, a particular gas port configuration, a liquid escape conduit, no-shoulder barrel configuration, and/or a low-force design for frac plugs.

Abstract: A method sequence for handling tubulars into or out of a wellbore, the method comprising: moving a tubular string into or out of a wellbore via a top drive; moving tubular stands to and from a setback position and a stand handoff position via a transfer bridge racker and a setback guide arm; moving tubular stands to and from the stand handoff position and a well center position via a tubular delivery arm and a lower stabilizing arm; building stands and breaking down stands offline via a mousehole and operating a roughneck on joints between the tubular stands and the tubular string.

Abstract: The present disclosure discloses a drilling machine. The drilling machine may include a base, a mast arranged on the base, an iron roughneck, a drill floor mechanical arm, a top drive arranged on the mast, a pipe racker on a finger board, a power finger board, a power catwalk arranged on the ground, and an elevator arranged on the top drive. The drill machine and a corresponding tripping out and tripping in method may be used to vertically transport a stand between a well center and a region of at least one pipe setback efficiently, which may improve the efficiency of tripping out and tripping in, and reduce the risk of accidents in the well. In addition, the present disclosure provides a corresponding method for offline connecting and disconnecting stands during a drilling operation, which may reduce a preparation time during the drilling, improve the drilling efficiency, and reduce the cost of oilfield development.

Abstract: A method and apparatus for patching damaged areas in a well includes a top and a bottom patching section which include an anchor/sealing member for securing the apparatus within the well. One or more extension patch sections are connected between the top and bottom patch sections. The top and bottom patch elements are placed above and below the damaged area to isolate the damaged area from the exterior flow portion of the well.

Abstract: A gripper assembly for handling continuous rod. The gripper assembly may include a gripper face with a gripper profile forming a surface in the gripper face and a texture on a portion of the surface. The texture has a plurality of ridges having a yield strength sufficient to transfer a shear force to the gripper assembly at least as large as a weight of a continuous rod.

Abstract: A technique facilitates use of a frac diverter instead of a frac plug in a variety of fracturing operations. The frac diverter has a simpler and less expensive construction. Although the frac diverter may not form a seal with the surrounding casing in some applications, the frac diverter is able to sufficiently restrict flow of fracturing fluid to enable a successful fracturing operation. The frac diverter may comprise arrangements of at least one cone, at least one slip ring, and at least one corresponding sub which work in cooperation with a flow restricting element. The flow restricting element may comprise various types of rings, e.g. sealing element rings, able to sufficiently restrict flow of fracturing fluid past the frac diverter.

Abstract: A method of conducting subterranean drilling operations comprising guiding a tubular with a first guide arranged in a first configuration; coupling an umbilical line to the tubular with an engagement element; guiding the tubular with a second guide; arranging the first guide to a second configuration to permit longitudinal passage of the engagement element past the first guide; and arranging the first guide to the first configuration after the engagement element is past the first guide. A system for conducting subterranean operations comprising a first guide and a second guide disposed at different vertical elevations, wherein the first and second guides are adapted to provide continuous support to a tubular in a lateral direction when the tubular is coupled with an umbilical line.

Abstract: A tool circulates drilling fluid through and rotates a pipe string while making up or breaking out a stand of pipe. The tool includes a clad configured to grip and seal around the RCCT sub. The clad includes a body portion, an inner ring configured to selectively rotate independently, an outer ring configured to be stationary with respect to the inner ring, the outer ring having at least two annular protrusions, a first arm configured to engage with a first annular protrusion, a second arm configured to engage with a second annular protrusion, and a stinger configured to latch into the at least one side entry port and allow the sub and the drill pipe string to rotate independent of the clad. The clad is configured to avoid or prevent stuck pipe incidents.