Abstract: Systems and methods for positioning tubular members within a subterranean well include inner and outer tubular members extending into the well. An adjustment ring assembly is located between the inner tubular member and the outer tubular member and has an outer ring and an inner ring. The outer ring circumscribes, and is rotatable relative to, the inner ring to adjust the radial offset between a central axis of the wellhead assembly and a central axis of the inner tubular member.

Abstract: The method and apparatus for producing shock waves in a well including a device connected to the bottom of the tubing string in a borehole of the well filled by liquid and containing the upper and lower plungers movably arranged within corresponding cylinders for compressing a liquid inside the compression chamber and discharging the liquid into the borehole on upstroke thereby generating a shock wave. In addition, a length of upstroke Lstr is determined by the following expression: L str ? H 1 + ( D 1 2 - D 2 2 ) ? A sw ? L 2 Ed r 2 , where H1 is a length of a lower cylinder, L2 is a distance between lower and upper plungers, D1 is a diameter of the lower plunger, D2 is a diameter of the upper plunger, Asw is a required amplitude of a generated shock wave, E is an elasticity modulus of a sucker rod's material, dr is a diameter of the sucker rods.

Abstract: A perforating gun string may include a first perforating gun; a second perforating gun axially offset from the first perforating gun; a connector configured to interpose and couple the first and second perforating guns; and a detonation cord that passes axially through a central bore of the connector; and is connected to the first and second perforating guns. In some instances, the connector may have a body with an inner surface that defines the central bore, wherein the body has a ratio of an average diameter of the outer surface to an average diameter of the inner surface of about 1.2 to about 4.

Abstract: A method and apparatus for a drive unit of a top drive system including a first, second, and third drive gears that are operationally coupled; a motor engagable with the first drive gear; a drive stem having a load coupling and engagable with the second drive gear; and a torque shaft having a torque coupling and engagable with the third drive gear. The drive stem cannot engage with the second drive gear when the torque shaft is engaged with the third drive gear. A method of coupling a drive unit to a tool adapter includes engaging a first drive gear with a motor of the drive unit while engaging a second drive gear with a drive stem of the drive unit; coupling a load between the drive stem and a tool stem of the tool adapter; and coupling a torque between a torque shaft of the drive unit and the tool stem.

Abstract: A structure for directly leading down the optical unit (OU) from the OPPC (optical phase conductor) cable, by the OU leading-down connector (2) invented recently, is used for separating the plastic-pipe OU from the OPPC cable installed on the tower, avoiding the splicing of fibers on the tower of the old technique. Therefore it is possible to assemble the OPPC cable (1), the OU leading-down connector (2), the preformed armor rod assembly (3), the first link fitting (4), the residual cable rack (5), the second link fitting (6), the insulator string (7) on the ground all together. Then the whole assemble can be erected on to the tower. Just as the conventional overhead power line construction. So it is simple and saving in work.

Abstract: An apparatus comprises a first number of splines located near a first end of a first joint section and a second number of splines located near a second end of a second joint section. The first number of splines extends in an axial direction of the first joint section and spans a circumferential surface of the first joint section. Each of the first number of splines has a base, a tip, and a pair of flanks that extends from the base to the tip and forms an acute angle. Each of the first number of splines are configured to be received between adjacent pairs of splines in the second number of splines as the first end of the first joint section and the second end of the second joint section are joined.

Abstract: A wellscreen assembly has first and second screen joints connected together and has at least first and second adjoining tubes with opposed ends separated by a gap from one another. At least one jumper tube has first and second tubulars and fits in the gap between the adjoining tubes. The first tubular has a first end connectable to one of the opposed ends, while the second tubular has a second end connectable to another of the opposed ends. The second tubular is telescopically connected to the first tubular, and a biasing element biases the first and second tubulars away from one another. The first and second tubulars are operable between (i) a retracted condition retracting the first and second ends from the opposed ends and (ii) an extended condition extending the first and second ends to the opposed ends of the adjoining tubes.

Abstract: A flow sub for use with a drill string includes a tubular housing having a longitudinal bore therethrough and a flow port through a wall thereof and a ball. The ball is disposed in the housing above the flow port, has a bore therethrough, and is rotatable relative to the housing between an open position where the ball bore is aligned with the housing bore and a closed position where a wall of the ball blocks the housing bore. The flow sub further includes a seat disposed in the housing above the ball for sealing against the ball wall in the closed position and a sleeve disposed in the housing and movable between an open position where the flow port is exposed to the housing bore and a closed position where a wall of the sleeve is disposed between the flow port and the housing bore.

Abstract: An apparatus comprises a first number of splines located near a first end of a first joint section and a second number of splines located near a second end of a second joint section. The first number of splines extends in an axial direction of the first joint section and spans a circumferential surface of the first joint section. Each of the first number of splines has a base, a tip, and a pair of flanks that extends from the base to the tip and forms an acute angle. Each of the first number of splines are configured to be received between adjacent pairs of splines in the second number of splines as the first end of the first joint section and the second end of the second joint section are joined.

Abstract: The disclosure provides a system and process for drilling a subterranean wellbore. An embodiment includes a bottom-hole assembly for a downhole mud motor that incorporates an information sub, such as a measurement-while-drilling or logging-while-drilling tool, at a location below, or down-hole from, the mud motor. The assembly also includes a micronized bit-to-bend length, or a length between a forward end of the assembly's bearing mandrel and a fixed bend in the assembly's housing, of less than or equal to forty inches. The combination of the forward-located information sub and micronized bit-to-bend length allow the driller to rely on real-time data relating to conditions adjacent to the drill bit/bottom of the wellbore and take that real-time drilling data into account in steering the bit along a planned wellbore trajectory. Other embodiments are also disclosed.

Abstract: A seat for a tubular treating system includes a single piece body having a central portion, and a frustoconical surface extending longitudinally from the central portion in a first direction configured to radially expand slips urged thereagainst. The seat also includes a collar extending longitudinally from the central portion in a second direction configured to be radially expanded into sealing engagement with a structure in response to a frustoconical member urged thereagainst. A seal surface is sealably engagable with a plug run thereagainst, and the seal surface is longitudinally displaced from the collar in the first direction.

Abstract: An example control line connector includes an expandable housing having a helical body that defines one or more windings and a helical shroud disposed about the one or more windings, wherein a helical conduit chamber is defined between the helical body and the helical shroud, a matable connector at least partially disposed within the expandable housing and providing a mating face that faces tangentially with respect to the expandable housing so as to angularly mate with an opposing matable connector, and a splitter block coupled to the expandable housing and conveying one or more communication media into the helical conduit chamber to communicate with the matable connector.

Abstract: A top drive includes a plurality of modules. The top drive includes a first fastening member and a second fastening member. The first fastening member and the second fastening member are configured to be removably coupled to connect a first module and a second module. In some embodiments, the top drive includes a third fastening member. The third fastening member is configured to be removably coupled to at least one of the first fastening member and the second fastening member, to connect the first module, the second module, and a third module. A tool for assembling or disassembling a top drive includes a fastening portion including an attachment mechanism configured to releasably couple the tool to a portion of a top drive. The tool includes a first housing including a recess disposed therein. The tool includes a first rod disposed at least partially within the recess.

Abstract: The present invention is a retrievable back pressure valve device and method of using the same that may be placed in tubing during well completion and retrieved as desired by dropping a ball down hole, which then interacts with the valve to shear the positioning points allowing for retrieval as the valve is allowed to move up the well to be removed from same.

Abstract: An apparatus comprises a first number of splines located near a first end of a first joint section and a second number of splines located near a second end of a second joint section. The first number of splines extends in an axial direction of the first joint section and spans a circumferential surface of the first joint section. Each of the first number of splines has a base, a tip, and a pair of flanks that extends from the base to the tip and forms an acute angle. Each of the first number of splines are configured to be received between adjacent pairs of splines in the second number of splines as the first end of the first joint section and the second end of the second joint section are joined.

Abstract: In one embodiment, the first casing string is releasably coupled to a second casing string using a latch assembly. The second casing string is released from the conductor after the first casing string is properly positioned in the wellbore. The latch assembly is configured to release the coupling by manipulating the second casing string relative to the first casing string.

Abstract: Inside blowout preventer release tool having an upper section and a tubular lower section. The upper section includes a pair of longitudinal members defining a central open region, and a formed lifting feature accepting a manipulator. The lifting feature is positioned such that when the release tool body and an inside blowout preventer connected thereto are lifted by the rig hoist they are easily moved over, aligned with, and connected with a working drillpipe while minimizing possibility of slipping off cables or chains. The lower section includes a threaded end mating with a mating end of an inside blowout preventer, a central longitudinal bore to accept a length-adjustable release rod, and an upper end formed to mate with the upper section. Slots in each longitudinal member may define one or more manipulating handles for a rig worker, machine, or tool, or a pair of generally horizontal hand holds are provided.

Abstract: A valve assembly with a longitudinal flow passage, a first longitudinal section of the flow passage having less flow area than a second longitudinal section of the flow passage, and a valve that permits flow in only one direction through the flow passage, the valve including a closure member. In an open position, the closure member can be disposed between the second flow passage section and a chamber in fluid communication with the first flow passage section. A method in which a valve assembly is connected in a tubular string, the valve assembly including a valve that permits flow in only one direction through a longitudinal flow passage of the valve assembly, and fluid is flowed in the one direction through the tubular string, thereby displacing a closure member of the valve to an open position and preventing displacement of the closure member toward a closed position.

Abstract: A valve assembly with a longitudinal flow passage, a first longitudinal section of the flow passage having less flow area than a second longitudinal section of the flow passage, and a valve that permits flow in only one direction through the flow passage, the valve including a closure member. In an open position, the closure member can be disposed between the second flow passage section and a chamber in fluid communication with the first flow passage section. A method in which a valve assembly is connected in a tubular string, the valve assembly including a valve that permits flow in only one direction through a longitudinal flow passage of the valve assembly, and fluid is flowed in the one direction through the tubular string, thereby displacing a closure member of the valve to an open position and preventing displacement of the closure member toward a closed position.

Abstract: A casing window assembly for completion of a lateral wellbore. The casing window assembly includes a tubular casing sleeve with a casing window and an inner sleeve releasably secured within the casing sleeve at a pre-released position adjacent the casing window.

Abstract: A fill up tool includes a mandrel; a primary sealing member disposed around the mandrel; and a selectively operable secondary sealing member activated by rotation of the mandrel. In another embodiment, the selectively operable secondary sealing member is activated using hydraulic pressure.

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: An expandable liner hanger system for forging a pressure seal and hanging of the liner weight against outer casing string in a wellbore that includes an outer casing string, and an inner casing string positioned within the outer casing string and having an inner diameter. The system also includes an elongate inner string tool selectively insertable into the inner casing string and having a torque locking sleeve that removably couples with the inner casing string. Also included in the expandable liner hanger system is an expansion cone slidable along the inner string tool and having a diameter greater than the inner diameter of the inner casing string so that when the cone is urged into the inner casing string, the larger diameter cone deforms the inner casing string radially outward into engagement with the outer casing string. The system also includes a downhole hydraulic force intensifier.

Abstract: A wireline cable includes an electrically conductive cable core for transmitting electrical power, an inner armor layer disposed around the cable core, and an outer armor layer disposed around the inner armor layer, wherein a torque on the cable is balanced by providing the outer armor layer with a predetermined amount of coverage less than an entire circumference of the inner armor layer, or by providing the outer armor layer and the inner armor layer with a substantially zero lay angle.

Abstract: A production string for use in a wellbore is disclosed. The production string includes an expansion joint having a first tubular that slides along a second tubular, and a control line extending from a location above the expansion joint to a location below the expansion joint. The control line is placed around the first tubular in a helical fashion that includes a plurality of coils. At least some of the coils in the plurality of coils are connected to each other by a flexible member to limit stretch between the connected coils when the control line is stretched.

Abstract: Apparatus, methods, and systems for preconditioning and/or testing a centralizer, and a preconditioned centralizer, are provided. The apparatus includes a restrictor positionable around a tubular and having an inner diameter that is greater than an outer diameter of the tubular. The apparatus also includes a driver configured to translate the restrictor relative to the tubular in at least a first axial direction. The restrictor is configured to engage a centralizer attached to the tubular, and the restrictor is configured to at least partially collapse flexible ribs of the centralizer when the driver axially translates the restrictor across at least a portion of the flexible ribs.

Abstract: An apparatus for handling one or more tubulars includes a body defining at least a portion of a tapered bowl. A plurality of slips may be disposed at least partially within the bowl and configured to slide along a surface of the bowl. Each of the slips includes a radial engaging surface and a tapered engaging surface. The radial engaging surface may have a plurality of gripping structures extending inwardly therefrom that are configured to engage an outer surface of a first tubular having a substantially constant outer diameter. The tapered engaging surface may be configured to engage a tapered outer surface of a second tubular.

Abstract: A system for facilitating the connection of a first tubular to a second tubular used in the oil and gas exploration and extraction industries includes a tubular handling device having a body having a profile shaped to accept a first tubular into a throat area and opposing scissor plates with overlapping tips. The system further includes a tubular engagement apparatus to engage and raise a tubular to a vertical position, and a spider apparatus including a plurality of slip assemblies. The slip assemblies include a slip back with an inclined load bearing surface, and a slip with a load bearing surface in sliding abutment with the inclined load bearing surface of the slip back.

Abstract: A drill pipe screen transporter device rotatably couples a drill pipe screen to a transporter for its insertion and/or extraction into and out of a derrick assembly. A first plate assembly has a first base plate; and first and second spacer plates have arcuate notches for engaging the transporter. U-shaped bolts secure the first plate assembly to the transporter. A second plate assembly rotatably connected to the first plate assembly, has an aperture for supporting the screen. A collar assembly, spacer collar and pivot pin rotatably attach the second base plate to the first base plate for rotation of the screen relative to the transporter. A swivel stopper engages the first base plate of the first plate assembly when the second plate assembly is rotated a predetermined amount. A counterweight located opposite to the swivel stopper returns the second plate assembly to its initial horizontal positioning.

Abstract: In one embodiment, a top drive system includes a quill; a motor operable to rotate the quill; a gripper operable to engage a joint of casing; a connector bi-directionally rotationally coupled to the quill and the gripper and longitudinally coupled to the gripper; and a compensator longitudinally coupled to the quill and the connector. The compensator is operable to allow relative longitudinal movement between the connector and the quill.

Abstract: An expandable liner hanger features carbide or other hard particles adhered to the outer surface of a tubular mandrel that is expanded using vulcanized rubber to retain the carbide during run in or set. The rubber can be directly applied to the outer surface of the mandrel or to a split ring that is subsequently secured to the outer surface of the mandrel. The rubber can also be mounted in an exterior recess to protect the carbide during running in from being knocked off with impact. A binder can be applied to the carbide or to the rubber for better fixation of the carbide when vulcanizing the rubber. The rubber moves with the expanding mandrel while binding the carbide until contact of the carbide to the surrounding tubular transfers the liner string weight to the surrounding tubular through the carbide.

Abstract: A pipe handler for assembling and deploying a string of threaded tubulars into a wellbore includes a pair of compensating bails and an elevator pivotally connected to the compensating bails. Each compensating bail includes: a first bail segment; a second bail segment; and a compensator connecting the respective first and second bail segments. Each compensator includes a load cylinder connected to the respective first bail segment and a linear actuator disposed in the respective load cylinder and operable to retract the respective second bail segment from a hoisting position to a ready position. Each second bail segment is engaged with the respective load cylinder in the hoisting position. The compensating bails are capable of supporting string weight in the hoisting position.

Abstract: A system for manipulating a tubular about a drilling rig is provided. The system includes a swivel body rotatably coupled with a becket. The becket is configured to couple with a traveling block of the drilling rig. The system also includes an engagement feature rotatably coupled with the swivel body. The engagement feature is configured to be actuated to engage the tubular. In addition, the system includes a tilt mechanism configured to be actuated to transition the swivel body and the engagement feature between a tilted orientation and an upright orientation relative to the becket. Further, the system includes an actuator system configured to actuate the tilt mechanism and the engagement feature.

Abstract: A system for disengaging a power supply at the surface of a well from a downhole assembly having a pump for pumping fluid in the well to the surface thereof. A captured spline assembly interposed in the rod string, selectively connected to the downhole assembly to provide torsional drive.

Abstract: A screen assembly including one or more screen members that correspondingly form one or more flow paths. The one or more flow paths are discrete from a tubular with which the one or more screen members are associated, but in fluid communication with an axial passageway of the tubular. A method of using a screen assembly is also included.

Abstract: An electronic control system comprises a first tubular handling tool, a sensor, and a controller. The controller is configured to control actuation of the first tubular handling tool in response to an electronic signal received from the sensor that corresponds to an operational characteristic of the first tubular handling tool. The electronic control system functions as an electronic interlock system to prevent mishandling of a tubular. A method of controlling a tubular handling tool comprises measuring an operational characteristic of the tubular handling tool, communicating the operational characteristic to a controller in the form of an electronic signal, and using the controller to control actuation of the tubular handling tool in response to the measured operational characteristic.

Abstract: A casing window assembly for completion of a lateral wellbore. The casing window assembly includes a tubular casing sleeve with a casing window and an inner sleeve releasably secured within the casing sleeve at a pre-released position adjacent the casing window.

Abstract: Materials are delivered within an expanded string before the string is subsequently compressively loaded such that the heat given off by the reaction of the delivered materials raises the fluid temperature in the recently expanded string to temperatures in a range of about 150-300 degrees Centigrade. The materials can be separated for delivery and then allowed to contact to initiate the reaction. Alternatively the materials can be delivered in separate conveyances for more immediate start of the exothermic reaction at the needed location or locations. To the extent there is curing cement about the expanded tubular, then the heat generated also reduces curing time to full setup of the sealing material. The applied heat counteracts or eliminates the Bauschinger effect.

Abstract: Multiple sensors on a drill string can be utilized to perform equivalent circulation density (ECD) analysis. By utilizing multiple ones of the sensors, the pressure drop in each section of the wellbore can be classified. Additionally, the inclusion of multiple sensors in the drill string allows a wellbore to be sectioned into intervals bounded by any two sensors. Pressure events occurring in a single section of the wellbore bounded by any two sensors can be isolated and analyzed. The isolation can be achieved by subtracting the pressure measured on the shallower sensor from that measured on the deeper sensor.

Abstract: A stabilizer to suppress unwanted pivotal movement in pipe handling equipment suspended from bails. The stabilizer can contain either or both adjustable contacting members and non-adjustable contacting members which are rigidly connected to a portion of the pipe handling equipment. The adjustable contacting members contact the bails on one or both sides of the bail(s) to suppress motion of the elevator relative to the bail.

Abstract: An injector head for feeding a tool string support member downhole is described. The injector head includes a first gripping device and a second gripping device. The first and second gripping devices are adapted to grip a tool string support member passing through an injector head passageway. The injector head further includes an actuator movable between a first position and a second position wherein, movement of the actuator between the first and second positions moves at least a portion of both of the first and second gripping devices towards or away from a passageway longitudinal axis.

Abstract: The present invention generally relates to an expandable liner hanger capable of being expanded into a surrounding casing. In one aspect, an expandable tubular system is provided. The system includes an expandable tubular. The system further includes an expansion swage for expanding the expandable tubular, wherein the expansion swage is deformable from a compliant configuration to a smaller substantially non-compliant configuration. Additionally, the system includes a restriction member disposed on an exterior surface of the expandable tubular, wherein expansion of the expandable tubular in the location of the restriction member deforms the expansion swage from the compliant configuration to the smaller substantially non-compliant configuration. In another aspect, a method of expanding a liner hanger using a cone is provided.

Abstract: A downhole system and related method, which may be used in an injection well for permitting removal, repair and or replacement of equipment installed in the well without unloading the formation in which the well is placed. The system generally includes an annulus sealing device, such as a packer, at least one valve, such as a flapper valve, a latching assembly and a rigid elongate member. The rigid elongate member may be connected to the latching assembly and serves the valve to open and close, or be permitted to open and close. The latching assembly serves to disconnect, and subsequently reconnect, equipment from the annular sealing device. Such release is accompanied by closure of the at least one valve and reconnection by opening of the at least one valve. The latching assembly has seals to prevent fluid from flowing around the latching assembly when the valve is open.

Abstract: A tubular has an exterior sealing element disposed in a recess. A swage passes through the tubular to increase its drift dimension from a location above the seal to below the seal. The interior projection that initially defined the exterior wall recess where the seal is located is expanded to the new drift dimension of the balance of the tubular. Extending members that are initially embedded in the seal while extending from the tubular wall that defines the recess move out during the expansion to engage the surrounding tubular to act as extrusion barriers and to aid in the fixation of the seal while being able to penetrate the wall of the surrounding tubular in so doing.

Abstract: A flow control assembly can be mechanically adjusted, rotationally or translationally, inside a tubing downhole between multiple positions by an intervening tool from the surface to change resistivity to flow through the flow control assembly. The positions among which the flow control assembly can be adjusted can include a closed position, a fully open position, and positions at which fluid experiences various resistances prior to flowing to an inner area of the tubing.

Abstract: A method of installing a wellbore junction assembly in a well can include inserting a tubular string into a deflector, and opening a flow control device in response to the inserting. A well system can include a deflector positioned at an intersection between at least three wellbore sections, and a tubular string connector having at least two tubular strings connected to an end thereof, one tubular string being received in the deflector and engaged with a flow control device positioned in a wellbore section, and another tubular string being received in another wellbore section. Another method of installing a wellbore junction assembly in a well can include inserting a tubular string into a deflector positioned at a wellbore intersection, then sealingly engaging the tubular string, and then opening a flow control device in response to the inserting.

Abstract: The present invention relates to a downhole tubular assembly for sealing an opening in a well tubular structure in a borehole downhole, comprising a first tubular part made of metal having an inner face, an inner diameter, an outer diameter and a first length in an unexpanded state, and a second tubular part having an outer face, an outer diameter and a second length, being arranged inside the first tubular part in an unexpanded state. Furthermore, the invention relates to a downhole system for sealing an opening in a well tubular structure in a borehole. Moreover, the invention relates to a method of sealing an opening in a well tubular structure in a borehole downhole and to a manufacturing method for manufacturing a downhole tubular assembly.

Abstract: The present invention generally relates to a cone system having a cone segment capable of deflecting in response to a restriction or obstruction encountered while expanding a tubular. In one aspect, an expansion cone system is provided. The expansion cone system includes a mandrel and two or more pockets disposed circumferentially around the mandrel. Each pocket is at least partially defined by a fin member. The expansion cone system further includes a cone segment coupled to each pocket. Additionally, the expansion cone system includes a biasing member disposed between the mandrel and the respective cone segment. In another aspect, a method of expanding a wellbore tubular is provided.

Abstract: A method of making a mechanical multishear link includes sizing the multishear link by breaking down a system comprised by the link into as many subassemblies as there are simple shear interfaces, defining the subassemblies around each shear interface, describing each shear by its stiffness, and applying the mechanical relationships to achieve a system of equations for a computer-assisted resolution by applying the Huth method to each shear interface.

Abstract: A downhole adjustable mud motor for boring wellbores, such as a hole in the earth. The downhole adjustable mud motor has a progressive cavity power section with a power cavity end, wherein the progressive cavity power section has a rotor rotatably captured within a stator and a plurality of fluid flow paths between the stator and the rotor for flowing drilling fluid. A power transmission section can be connected to the power cavity end having a central axis and an offset axis. A first adjustable member can be fastened to the stator. A second adjustable member can have a locking member, a bearing assembly connecting to the transmission assembly, and a fastener operatively connected to the bearing assembly. The locking member prevents compression of the second adjustable member inside of the first adjustable member when drilling fluid flows through the downhole adjustable mud motor.