Abstract: A handling device for handling drill string components (8, 8?,8?) in a rock drilling rig (1), wherein the handling device includes a gripper unit (11) for gripping drill string components (8, 8?,8?) to be put into and be brought out from the rock drilling rig, and wherein the gripper unit (11) includes grippers (12,13,14) operational for gripping components positioned in a gripping position, which defines a grip position axis (G). The gripper unit (11) is supported swingable between: a) a first position, wherein the gripper unit is positioned for engagement with an end portion of a first drill string component (8?) and an end portion of a second drill string component (8?) in and aligned with said active drill string position (A), and b) a second position, wherein a gripper unit (11) is positioned for engagement with an end portion of a drill string component in a delivering position for drill string components that are to be brought into respectively taken away from said active drill string position (A).

Abstract: Provided are coated oil and gas well production devices and methods of making and using such coated devices. In one form, the coated device includes one or more cylindrical bodies, hardbanding on at least a portion of the exposed outer surface, exposed inner surface, or a combination of both exposed outer or inner surface of the one or more cylindrical bodies, and a coating on at least a portion of the inner surface, the outer surface, or a combination thereof of the one or more cylindrical bodies. The coating includes one or more ultra-low friction layers, and one or more buttering layers interposed between the hardbanding and the ultra-low friction coating. The coated oil and gas well production devices may provide for reduced friction, wear, erosion, corrosion, and deposits for well construction, completion and production of oil and gas.

Abstract: A spoolable signal conduction and connection line for a downhole environment including a length of signal conduction and connection line suitable for the downhole environment; and one or more connectors depending from the line along a length of the line, the connectors capable of making a signal bearing connection for the downhole environment.

Abstract: The present invention relates to a completion assembly for running into a borehole in a formation through a well head or blowout preventer, comprising a casing string having a first end and a second end, and a drill pipe having a first end and a second end and extending through the well head or the blowout preventer and being releasably connected at the first end with the casing string. Furthermore, the invention relates to a completion method for completing a casing string. Moreover, the invention relates to a completion kit for making a completion assembly according to the present invention.

Abstract: Provided are coated sleeved oil and gas well production devices and methods of making and using such coated sleeved devices. In one form, the coated sleeved oil and gas well production device includes one or more cylindrical bodies, one or more sleeves proximal to the outer diameter or inner diameter of the one or more cylindrical bodies, hardbanding on at least a portion of the exposed outer surface, exposed inner surface, or a combination of both exposed outer or inner surface of the one or more sleeves, and a coating on at least a portion of the inner sleeve surface, the outer sleeve surface, or a combination thereof of the one or more sleeves. The coating includes one or more ultra-low friction layers, and one or more buttering layers interposed between the hardbanding and the ultra-low friction coating. The coated sleeved oil and gas well production devices may provide for reduced friction, wear, erosion, corrosion, and deposits for well construction, completion and production of oil and gas.

Abstract: A system and method for building and handling oilfield tubular stands while drilling operations are simultaneously and independently occurring with one drilling deck, one derrick, and one rotary system. An offline guided path horizontal to vertical arm lifts and moves in the same plane tubulars stored horizontally on the catwalk and positions the tubulars vertically directly into a preparation hole for assembling and disassembling tubular stands while online drilling operations are simultaneously being conducted. A stand arm lifts and lowers the tubulars into and out of the adjustable preparation hole, and transports the tubulars for storage to an auxiliary tubular racking station in the upper part of the derrick. A bridge racker crane moves tubular stands from the auxiliary tubular racking station to the top drive or another tubular racking station.

Abstract: A downhole apparatus having a radially expanding portion and a support structure are described. The support structure comprises an attachment means for coupling to the apparatus and a support portion configured to be deployed from a first unexpanded condition to a second expanded condition by expansion of the apparatus. In one aspect of the invention, the downhole apparatus is expanded by exposing the swellable material to at least one predetermined fluid, and the support structure abuts the swellable material in its expanded form. A method of use and its application to a well packer, a hanging member, an anchor and a centralizing apparatus are described.

Abstract: A lateral liner tie back system and method includes a base sub having a tapered upper end surface. The base sub may be positioned in a main bore at a window to a lateral bore. The tapered upper end surface of the base sub may direct a junction sub from the main bore partially into the lateral bore such that an end of an existing liner positioned within the lateral bore is disposed within a central bore of the junction sub. The system may also include a tie back sub that is lowered through the junction sub into the lateral bore. The tie back sub includes threads for engaging the end of the existing liner in the lateral bore. The lateral liner tie back system may selectively direct a tool that is lowered in the main bore into the lateral bore or prevent the tool from entering the lateral bore.

Abstract: The present apparatus and method of use allows a blow out preventer to be installed as a unit with a section of casing, and does not require the blow out preventer to be removed as subsequent strings of casing are installed, thus efficiently utilizing drilling rig time. The present invention further allows a casing string to be landed and cemented in place, and then the drilling rig may move off the location, without a permanent wellhead housing attached to the well. The primary apparatus utilized in the invention is a tubular connector which suspends a string of casing during cementing, and which receives a casing plug for sealing the well when drilling operations have been completed. When completion operations commence, a permanent wellhead housing is attached to the tubular connector utilizing a unique metal to metal seal.

Abstract: Disclosed are systems and methods for providing a casing exit. One method includes introducing into a wellbore a casing section having an outer sleeve and an inner sleeve rotatably received within the outer sleeve, the outer sleeve defining an outer window and the inner sleeve defining an inner window rotationally alignable with the outer window, wherein the inner sleeve defines a first alignment portion engageable to rotate the inner sleeve, advancing the casing section to a wellbore location with the inner window rotationally misaligned with the outer window, extending a deflector tool within the casing section such that a second alignment portion provided on the deflector tool engages the first alignment portion, and rotating the deflector tool such that the inner sleeve rotates with respect to the outer sleeve and moves the casing section into an open configuration where the inner window is rotationally aligned with the outer window.

Abstract: An apparatus including a first housing defining an opening and a bearing housing disposed in the opening so that movement of at least a portion of the bearing housing within the first housing and along a first axis is permitted, the bearing housing defining first and second bearing surfaces, the first and second bearing surfaces being spaced apart along a second axis to prevent movement of the bearing housing within the first housing and along the second axis, the second axis being perpendicular to the first axis.

Abstract: Devices and methods for quickly connecting and disconnecting a conduit to a port. In a described embodiment, a quick connect coupling is described for quickly connecting and disconnecting a cement supply conduit to the port of a top drive cement swivel.

Abstract: Device for lining the wall of a wellbore as it is being drilled using a drill string having a drill bit on the lower end thereof. The device has a receptacle for a cylindrically gathered pack of flexible tubing capable of being supported around the outside of the drill string near the lower end thereof on a plurality of bearings, a radially expandable locking device attachable to one end of the flexible tubing and being capable of being expanded against the wellbore wall to lock the end of the flexible tubing in place in the wellbore, and a conduit having an inlet upstream of the receptacle and an outlet downstream of the receptacle. A pump is located in the conduit or abutting the inlet or outlet thereof, and pumps the drilling fluid so that a fluid pressure inside the liner is greater than a fluid pressure at the drill bit.

Abstract: A hydraulic workover rig including a base structure, a derrick extending from the base structure, a hydraulic lift cylinder connected to the upper end of the derrick, a lower slip assembly connected to the base structure, an upper slip assembly, and at least two snub cylinders connected to the base and the upper slip assembly. A distal end of a piston rod of the lift cylinder is connectable to a pipe string extendable through the upper and lower slip assemblies such that both a lifting force and a snubbing force may be applied simultaneously to the pipe string.

Abstract: Provided are drill stem assemblies with ultra-low friction coatings for subterraneous drilling operations. In one form, the coated drill stem assemblies for subterraneous rotary drilling operations include a body assembly with an exposed outer surface including a drill string coupled to a bottom hole assembly, a coiled tubing coupled to a bottom hole assembly, or a casing string coupled to a bottom hole assembly and an ultra-low friction coating on at least a portion of the exposed outer surface of the body assembly, hardbanding on at least a portion of the exposed outer surface of the body assembly, an ultra-low friction coating on at least a portion of the hardbanding, wherein the ultra-low friction coating comprises one or more ultra-low friction layers, and one or more buttering layers interposed between the hardbanding and the ultra-low friction coating.

Abstract: An apparatus for centering a first tubular with respect to a second tubular at a wellhead in which the apparatus has a frame, a gripping member extending outwardly of the frame and suitable for gripping the first tubular, and a guide member connected to the frame and extending outwardly therefrom. The guide member is positioned below the gripping member. The guide member has a slot therein suitable for receiving a portion of the second tubular therein. The slot of the guide member has a center vertically aligned with a center of the gripping member. The guide member is pivotally connected to the frame.

Abstract: The present invention relates to expansion tools used to centralize a casing-casing annulus in a wellbore. One embodiment provides a method for centralizing an inner casing within an outer casing that includes introducing an expansion tool into the inner casing. The expansion tool has an elongate body having a first force multiplier case coupled to an expansion tool case. A piston arranged within the first force multiplier case is actuated to move the piston axially in a first direction within the first force multiplier case. The piston engages a ram arranged within the expansion tool, and causes the radial expansion of one or more lug assemblies arranged within the expansion tool case. The inner casing is then plastically deformed with the one or more lug assemblies as they expand radially.

Abstract: Apparatus and method for completing a wellbore including providing a packer having an inner mandrel, alternate flow channels along the inner mandrel, and a sealing element external to the inner mandrel, including connecting packer to tubular body, then running the packer and connected tubular body into the wellbore. In one aspect, the packer and connected tubular body may be placed along an open-hole portion of the wellbore. Tubular body may be a sand screen, with the sand screen comprising a base pipe, a surrounding filter medium, and alternate flow channels. The method includes setting a packer and injecting a gravel slurry into an annular region formed between the tubular body and the surrounding wellbore, and then further injecting the gravel slurry through the alternate flow channels to allow the gravel slurry to at least partially bypass sealing element of the packer.

Abstract: Systems, apparatus, and methods for longitudinally moving or running a tubular, with the system including an elevator suspended from a rig. The elevator includes a body defining a bore to receive a tubular and wedges defining channels therebetween, with the wedges being configured to engage the tubular. The system may also include a spider including a body defining a bore to receive the tubular and wedges defining channels therebetween. The wedges of the spider may be configured to engage the tubular, and the wedges of the elevator may be configured to slide axially at least partially in the channels of the spider. The wedges of the spider may be configured to slide axially at least partially in the channels of the elevator.

Abstract: A safety joint for use in a subterranean well can include separable portions which, when separated, disconnect sections of a tubular string. Elongation of the safety joint can be permitted while longitudinal compression of the safety joint is prevented. A method of activating a safety joint in a subterranean well can include providing the safety joint with portions having end connectors which interconnect the safety joint between sections of a tubular string, permitting elongation of the safety joint, thereby facilitating disconnection of the tubular string sections, and then preventing longitudinal compression of the safety joint. Another safety joint can include separable portions, and a locking device which permits relative displacement between a generally tubular mandrel and a component of the safety joint in one direction, and prevents relative displacement between the mandrel and the component in an opposite direction.

Abstract: A shoulder ring, for installation in a threaded pipe coupling between the installed pin ends of two pipes being connected by the coupling, has opposing end faces and a central opening, and may be lobate or circular in shape. The shoulder ring provides enhanced axial retention within the coupling by incorporating a thread element which engages the internal threads of the coupling to prevent or deter displacement of the ring from the coupling. Alternatively, enhanced axial retention may be provided by means of an interference or interlocking fit that is plastically induced during the ring installation process. The shoulder ring may be of lobate or circular configuration, with the axial retention of lobate embodiments being further enhanced by forces acting radially outward against the coupling due to elastic deformation of the ring during installation. Also disclosed are tools for installing the shoulder rings in a threaded coupling.

Abstract: A method for automatic handling of drilling rods includes a step of handling at least one drilling rod (30) by a handler (40) designed for simultaneously clamping and moving the drilling rod (30), and wherein the handler (40) moves the drilling rod (30) from an auxiliary retainer (200) to a main well (100). The handling step takes place automatically and is controlled by a data processing unit, and includes automatic handling of a drill head (20) fitted with a chuck susceptible to being screwed to the drilling rod (30); the automatic handling occurring among a plurality of heights (q1-q6) stored in the data processing unit.

Abstract: A tubular assembly comprises a wellbore tubular, at least one shunt tube, and a coupling assembly configured to rotatably couple the at least one shunt tube to the wellbore tubular. A method of coupling the tubular assemblies comprises coupling a first wellbore tubular to a second wellbore tubular, wherein a first shunt tube is coupled to the first wellbore tubular, rotating a second shunt tube about the second wellbore tubular that is coupled to the first wellbore tubular until the second shunt tube is substantially aligned with the first shunt tube, and coupling the first shunt tube to the second shunt tube.

Abstract: Aspects of the present invention include drill string components having a thread extending around a body. The leading end of the thread can have a configuration that resists jamming and cross-threading. In particular, the leading end of the thread can include a planar surface normal to the body. The leading end of the thread can provide an abrupt transition to full thread depth that helps reduce or eliminate cross-threading. The leading end of the thread can be oriented at an angle relative to the axis of the drill string component. When mating male and female threads are similarly structured, the mating threads slide together along an interface at the thread start face and are drawn into a fully thread-coupled condition. The thread starts may have full circumference mating with no jamming positions.

Abstract: A downhole setting tool is provided. The tool comprises a tool housing and a hollow mandrel, the mandrel being situated in the housing. The tool further comprises a piston situated between the mandrel and the tool housing and a collar situated between the mandrel and the tool housing, wherein the tool housing, the mandrel, the piston and the collar define an annulus. The tool further comprises a first valve, wherein in a closed position the first valve blocks a path of fluid communication between the interior of the mandrel and the annulus.

Abstract: The invention discloses a system (FIG. 1) and a method for lining a wellbore. The system comprises a drill string (20) for drilling the wellbore; an expandable tubular element (84) enclosing the drill string (20), wherein a lower end portion of a wall of the expandable tubular element (14) is bent radially outward and in axially reverse direction to define an expanded tubular section (10) extending around an unexpanded tubular section (8); a pushing device (42) for pushing the unexpanded tubular section (8) into the expanded tubular section (10); and a releasable drilling annulus sealing device (70) for closing an annular opening between an upper end of the expandable tubular element and the drill string.

Abstract: A method of coupling segments of a borehole conduit is disclosed. The method includes: positioning a first conduit segment at a location selected from a surface location and a downhole location, the first conduit segment having a first end and a second end, the first conduit segment including a pin connector at the first end; orienting the first conduit segment so that the first end is located uphole relative to the second end; and coupling a second conduit segment in operable communication with the first conduit segment, the second conduit segment having a box connector at an end of the second conduit segment that is configured to engage the pin connector of the first segment.

Abstract: A coiled tubing connection system is used in a well. A connector having an engagement end is used to couple a wellbore device to the end of a coiled tubing. The connector is spoolable, and the engagement end comprises engagement features that facilitate formation of a connection that is dependable and less susceptible to separation.

Abstract: A system and methodology facilitates conveyance of a tool, e.g. a downhole completion or completion component, via a tool string. The tool string comprises a contraction joint designed to contract if the tool incurs sufficient axial loading. The contraction joint may comprise an outer housing and a mandrel slidably received in the outer housing. The contraction joint also comprises a resettable locking member which selectively releases the mandrel with respect to the outer housing to contract the contraction joint when under sufficient axial loading.

Abstract: A technique is provided for engaging and disengaging an upper completion with a lower completion positioned in a wellbore. The upper completion comprises an upper communication line, and the lower completion comprises a lower communication line. The upper completion is mechanically latched with the lower completion and the communication lines are coupled in a manner that enables selective engagement and disengagement. A communication line union is used to connect the upper communication line and the lower communication line in a plurality of rotational orientations of the upper completion relative to the lower completion.

Abstract: An improved multi-bolt and nut torque wrench for installing and removing bolts or nuts from flanged joints or the like which includes a plurality of torque stations having a plurality of high torque wrenches for engaging the heads of the bolts or nuts during a high torque phase of removal or installation; a plurality of low-torque motors operatively engaged with the wrenches for rotating the bolts or nuts during the low torque phase of removal or installation; a source of hydraulic fluid for driving the low-torque motors during the low-torque phase, and driving the high-torque wrenches during the high torque phase; and a mechanism for switching between the two phases depending on the torque needed.

Abstract: A method to add a joint of pipe to a conductor string includes securing the conductor string with a spider, grasping an upper end of the joint of pipe with a segmented-ring elevator, engaging a plurality of slips of the elevator with an outer profile of the joint of pipe, raising the grasped joint of pipe from non-vertical to vertical, positioning the vertical joint of pipe atop the secured conductor string, attaching the joint of pipe to the conductor string, releasing the conductor string from the spider, and retaining the joint of pipe and the conductor string with the segmented-ring elevator.

Abstract: An apparatus includes a first structure having a cavity containing a first coupler portion, and a first cover to sealably cover the cavity. In addition, a second structure for engaging the first inductive structure has a cavity containing a second coupler portion. A second cover is sealably covers the cavity of the second structure.

Abstract: A radio frequency (RF) applicator may be rotated during positioning within a wellbore in a subterranean formation. The wellbore may have at least one bend therein. The RF applicator may include a series of tubular conductors, and a respective bendable tubular dielectric coupler rotationally interlocking opposing ends of adjacent ones of the series of tubular conductors to define a tubular antenna. The RF applicator may include at least one RF feed conductor extending within the tubular antenna and connected to the series of tubular conductors.

Abstract: A method of installing a wellbore junction assembly in a well can include connecting at least two tubular strings to one opposite end of a tubular string connector with similarly dimensioned oriented connections, whereby the tubular strings are interchangeably connectable to the connector by the oriented connections. A wellbore junction assembly can include at least two tubular strings and a tubular string connector having opposite ends. Each of the tubular strings may be secured to one opposite end of the connector by oriented connections, whereby each of the tubular strings has a fixed rotational orientation relative to the connector. A well system can include a tubular string connector, each of first and second tubular strings being secured to the connector, and a support which reduces bending of the second tubular string which results from deflection of the second tubular string from one wellbore section into another wellbore section.

Abstract: A system for drilling a wellbore into an earth formation comprises an expandable tubular element extending into the wellbore, wherein a lower end portion of the wall of the tubular element extends radially outward and in an axially reverse direction so as to define an expanded tubular section extending around a remaining tubular section of the tubular element. The expanded tubular section is extendable by downward movement of the remaining tubular section relative to the expanded tubular section whereby said lower end portion of the wall bends radially outward and in an axially reverse direction. A drill string extends through the remaining tubular section into the wellbore, such that a space is formed between the drill string and the remaining tubular section, and the system further comprises sealing means arranged to seal said space from an open-hole lower section of the wellbore.

Abstract: Apparatus and a method for deploying a wireline tool in a borehole. The apparatus comprises a wireline cable which is connected at a first end at the surface and is releasably connected at a second end to a first end of an umbilical cable via a first connection means. A second end of the umbilical cable is releasably connected to the logging head of a wireline tool via a first latching means, wherein the logging head provides for mechanical and electrical connection between the wireline tool and the wireline cable via the umbilical cable. The umbilical cable is surrounded by umbilical pipe downhole, and the logging head also provides for mechanical and hydraulic connection between the umbilical pipe and the wireline tool. The wireline tool is releasable from connection with the umbilical cable by a release means in the first latching means, and is capable of being pulled through the first latching means and through the umbilical pipe so that it is retrievable from the borehole.

Abstract: Present embodiments are directed to a gripping device configured to cooperate with a pipe drive system or top drive to provide a sealed engagement with drillpipe elements. The gripping device includes a housing configured to extend over and at least partially around a distal end of the drillpipe element. Further, the gripping device includes a seal area positioned along an inner perimeter of the housing such that, when a seal is inserted in the seal area, the seal is arranged to engage with a face of the distal end of the drillpipe element and a face of the gripping device. Further, the gripping device includes engagement features configured to extend inwardly from the inner perimeter to facilitate coupling of the gripping device with an outer circumferential area of the drillpipe element.

Abstract: Present embodiments are directed to a gripping device configured to couple with a pipe element. A housing of the gripping device is configured to extend over and at least partially around a distal end of the pipe element. Torsional clamp devices are configured to engage an outer circumferential surface of the pipe element with frictional engagement features that extend radially inward from the housing. A sealing mechanism is configured to shift a pipe seal relative to the housing and into engagement with the distal end of the pipe element and to facilitate fluid flow through the gripping device into the pipe element.

Abstract: A drill pipe and a method of applying hardbanding thereto. A hardbanding alloy comprising iron and manganese present in the range of 67 to 87 weight percent (wt. %), niobium and chromium present in the range of 9 to 29 wt. %, and boron, carbon and silicon present in the range of 3 to 6.5 wt. % may be welded around at least a portion of a tool joint circumference. The hardbanding alloy may exhibit a hardness of 45 Rc to 70 Rc and a wear rate in the range of 0.08 grams to 1.60 grams of mass loss after 6,000 cycles as measured using ASTM G65-04, Procedure A.

Abstract: A tool is for clamping a saver sub assembly of the drive shaft of a top drive drilling machine, in which a tong, which is arranged to fixedly hold the saver sub assembly by releasable abutment against a portion of the saver sub assembly, is arranged on an upper portion of a frame which, in a position of use, is rotationally rigidly fixed to and projects from a support, the frame being provided with a through-going center opening arranged to receive a substantial portion of the saver sub assembly. A method of replacing a saver sub assembly on the drive shaft of a top drive drilling machine is described as well.

Abstract: The disclosure provides an adjustable modular skid system with a plurality of skid modules to support oil field fluid components, such as manifolds, mixing blocks, collection blocks, fracturing pumps, piping and connections, and other devices used to transport water, sand slurries, gas, oil, or other fluids in oil field applications. The skid system has vibration adjusting features. The skid modules can be coupled together through piping and relevant connections at the well site. If appropriate, the skid modules can be supported on pilings or other foundational supports. The system can be assembled remotely, started and tested, partially disassembled into the skid modules, and then installed at the well site with minimal additional effort by generally providing lines and connections between the modules. Excessive vibrations in the system can be reduced by adjusting an overall stiffness of the system to change a natural frequency of the system.

Abstract: Present embodiments are directed to a device for a top drive drilling system. The device includes a movable sleeve configured to be disposed around at least a portion of a sub. The movable sleeve is configured to be selectively disposed around a tubular by sliding axially along the sub. The device also includes a plurality of engagement features extending inwardly from an inner circumference of the movable sleeve. When the movable sleeve is disposed around the tubular, the plurality of engagement features are configured to engage the tubular when the movable sleeve is rotated in a first direction and to not engage the tubular when the movable sleeve is rotated in a second direction.

Abstract: Present embodiments are directed a stand compensator system. The stand compensator system includes gripping device configured to engage a tubular element by coupling about an outer circumference of the tubular element. Additionally, the tubular compensator system includes a plurality of resilient roller assemblies positioned proximate an inner perimeter of the gripping device, wherein the resilient roller assemblies include rollers arranged to engage with an abutting surface of the tubular element. Further, the stand compensator system includes engagement arms coupled with the gripping device, wherein the engagement arms are configured to hold the gripping device in position above a tubular elevator and couple between rig bails extending from the tubular elevator.

Abstract: A drill pipe connector assembly capable of connecting drill pipe segments without rotation. The assembly includes the pin end of a first drill pipe stabbed within the connector end of a second drill pipe. A connector nut is threadedly connected or snap locked to the connector end of the second drill pipe. The connector nut includes a retaining shoulder cooperating with a beveled shoulder on the pin end of the first drill pipe to retain the first drill pipe. The assembly includes seals to provide pressure integrity and prevent leaking. Cooperating rotational torque transfer profiles in the first and second drill pipes enable operational rotation of the drill string.

Abstract: A work string assembly for an oil or gas well has a first and second tubulars, and a torque limiting device connected in the work string. The torque limiting device has a body with an axial bore and two interconnected members that can disconnect to be relatively rotatable. The interconnected members can be repeatedly re-engageable when the torque levels drop below a torque threshold value, or can be connected by a frangible member that is broken when the interconnected members disconnect. A selectively actuable circulation port provided in the string adjacent to and above the torque limiting device allows the annulus between the work string and the casing to be flushed with fluid from the port.

Abstract: An automatic top drive positioning system includes a top drive having a pipe handling system rotator gear, a drive motor rotationally coupled to the rotator gear and a rotational position sensor rotationally coupled to the rotator gear. A controller is configured to operate the drive motor to automatically move the rotator gear to a selected rotational orientation based on measurements from the rotational position sensor.

Abstract: A slip bowl load transfer system includes a first slip bowl assembly and a second slip bowl assembly. The first slip bowl assembly, adapted to engage and release a tubular member, includes a first slip bowl coupled to a second slip bowl. In an engaged state, the first slip bowl assembly imparts a compressive force on a portion of the tubular member between the first slip bowl and the second slip bowl. The second slip bowl assembly is adapted to engage and release the tubular member and is aligned with the first slip bowl assembly. When the second slip bowl assembly is engaging the tubular member in a second engaged state, the second slip bowl assembly is prevented from releasing the tubular member if the first slip bowl assembly is not in the engaged state.

Abstract: The tubular string to be expanded is run in on a running string. The swage assembly has a seal from the running string to the existing tubular and the top of the tubular string to be expanded also has a similar seal against the exiting tubular. Annulus pressure around the running string drives the swage assembly to support the expanded tubular to the exiting tubular and to continue expansion to the end of the tubular. Cementing then takes place followed by reconfiguring the swage assembly to engage the liner hanger seal with the result being a monobore connection in a single trip including the cementing.

Abstract: A continuous communications conduit for use in a well is disclosed. A first 101 and second 102 conduit section are threadably engaged and a weldment is formed 200. A heat shield conduit 220 can be disposed within a bore (111, 112) of a conduit section (101, 102) between a first conduit section shoulder 151 and a second conduit section shoulder 152. A first 301, second 302, and third 303 conduit section can be threadably engaged and a weldment 400 formed. An electrical conductor 300 can be disposed in a bore of the conduit sections (301, 302, 303). A heat shield conduit 320 can be disposed between a first conduit section shoulder 351 and a second conduit section shoulder 352. Optionally, an elastomeric stabilizer (410, 420) may be utilized.