Abstract: The present invention relates to an attachment for drilling and/or foundation work, in particular a casing oscillator or casing rotator, comprising a receiving apparatus for clamping at least one pipe and a drive for generating a rotational movement of the clamped pipe, wherein the attachment comprises at least one integral control unit for an independent carrying out of control functions of the attachment.

Abstract: A combined multicoupler for connecting a tool to a top drive is disclosed. The combined multicoupler includes a load frame comprising a frame body having a load shoulder, and a side door coupled to the frame body. The side door opens from the frame body to allow a tool sliding horizontally into the load shoulder, and the side door closes to lock the tool in the load frame. The combined multicoupler further comprises a drive stem movably coupled to the load frame, wherein the drive stem moves vertically to connect and disconnect with the tool in the load frame.

Abstract: A self-calibrating system, apparatus, and method for accurately measuring a volumetric capacity of a tank. The system, apparatus and method comprise: a mechanism that adjusts a level of a platform; a light-emitting device with beam-like optics (laser, diode, etc.) mounted to the platform; mechanism for adjusting alignment of the light-emitting device with respect to the platform; a mechanism for rotating the platform by variable angles, including by 180-degrees; one or more level sensors (such as, for example, spirit levels, tilt sensors, or other devices) that provide feedback on the alignment of the platform normal to the gravity vector.

Abstract: A connector assembly attaches downhole tools to one another to form a tool string. The connector assembly includes male and female subs, each with latch ends that selectively latch to one another. Ends of the subs distal from their latch ends are configured for attachment to the downhole tools. A plug assembly is in one of the subs and a socket assembly is disposed in the other sub; the plug and socket assemblies mate with one another when the subs attach. Mating the plug and socket assemblies forms a signal communication path through the connector assembly so that adjacent tools are in signal communication. The plug and socket assemblies and male and female subs are annular and circumscribe a bore that extends axially through the connector assembly. Downhole tools that attach to opposing ends of the connector assembly are in communication through the bore in the connector assembly.

Abstract: A well pumping assembly has a stator mounted in a housing, the stator having an axially extending stator cavity. The stator has windings that when powered create an electromagnetic field into the stator cavity. A pump has a landed position within the stator cavity. The pump having a non-rotating pump portion and a rotating pump portion. Magnets mount on the rotating pump portion and impart rotation to the rotating pump portion in response to the electromagnetic field. A neck on a downstream end of the pump has a running and retrieval feature for engagement by a running and retrieving tool to retrieve the pump from and install the pump in the landed position.

Abstract: A centralizer device for center positioning of a bore hole component (90, 91) in a bore hole and a method for deploying such a centralizer are described. The centralizer device (100) is prepared to have two possible different states, one state being a locked state for improved deployment and another state being a released state for centring. The transition from the locked state to the released state is performed by introducing a pill of bore fluid having a pH-value outside range of pH-values of bore fluid in a well. The pill of bore fluid dissolves pH-soluble material in the centralizer device.

Abstract: A duplex snubbing jack and method of snubbing pipe into a well bore which includes first and second gripping units that alternately and synchronously grip and release a length of pipe to be attached to a pipe string. The first and second gripping units are synchronously movable upward and downward toward and away from each other to push or pull the pipe through a BOP stack and into or out of a wellbore. Linear actuators are used to synchronously move the first and second gripping units. Guide rails are provided to laterally support the pipe as the pipe is pushed or pulled through the BOP stack into or out of the wellbore. The first and second gripping units are preferably slip-type spiders.

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: In combination a drilling installation for drilling a well and a control and signal lines deployment module, wherein the drilling installation includes a rig floor slip device which is adapted to be cleared from a well centre opening to create a clear space around the well centre opening. The combination further includes a temporary workspace floor, which is adapted to be mounted in the clear space at a level below a rig floor surface and to provide a workspace floor for an operator standing in the clear space on said work space floor, allowing the operator to secure at a securing level the one or more control/and or signal lines externally to a second tubulars string suspended from a module slip device.

Abstract: A pipe handler for handling tubular members of a well system includes a mounting member for mounting the pipe handler to a structure of the well system, a first arm having a first end coupled to a structure of the well system, and a second end, wherein the first arm is configured to pivot relative to the mounting member about a first axis, a second arm having a first end and a second end, a connector coupled to the second end of the first arm and the first end of the second arm, and wherein the connector is configured to rotate the second arm about a second axis and a guide member coupled to the second end of the second arm for guiding a tubular member, wherein the second arm is configured to pivot relative to the connector about a third axis.

Abstract: A technique facilitates joining of sections of tubing and related monitoring. An expandable tubular member may be coupled with an external tubing, e.g. a casing. The expandable tubular member is deployed into the external tubing to a desired position. Then, an expandable portion of the expandable tubular member may be plastically deformed in a radially outward direction and into engagement with the external tubing. A sensor system may be combined with the expandable tubular member to monitor a characteristic of the expandable tubular member.

Abstract: A floor wrench for a drilling rig floor is provided. The wrench can include a tong assembly having upper and lower tongs made up of articulated tong blocks that can move and lock together to enclose and make or break a joint between sections of drilling pipe. Each tong block can include a pair of die ram assemblies wherein each tong can have dies to grip the drilling pipe around its circumference. The tong assembly can be mounted in a frame configured for horizontal and vertical movement to and from the pipe joint. In some embodiments, the wrench can further include a pipe spinner having motorized spinners that can spin the upper pipe to form the joint prior to torqueing the joint together, or for uncoupling the upper pipe after the joint is broken.

Abstract: The present invention discloses a method of plugging a well that relies on casing expansion to plug uncemented casing sections, rather than milling out the casing or perforate wash and cement (PWC).

Abstract: A system and method for continuous mud circulation during a drilling operation, of which the method includes delivering a first flow of drilling mud to and through a blowout preventer via a drill string and a wellbore. The method also includes delivering a second flow of drilling mud to and through the blowout preventer. The second flow is delivered to the blowout preventer through an alternative line and not via the drill string. The method also includes stopping the first flow of the drilling mud, and adding or removing a tubular to or from the drill string after the first flow of drilling mud is stopped and while continuously delivering the second flow of drilling mud. Adding or removing the tubular includes decoupling a rotating control device from the blowout preventer, detachably coupling the rotating control device with a drag device, and raising or lowering the rotating control device with the drag device coupled therewith.

Abstract: A method is for hydrocarbon resource recovery. The method may include positioning an RF antenna assembly within a wellbore in a subterranean formation, the RF antenna assembly having first and second tubular conductors and a dielectric isolator defining a dipole antenna, and a dielectric coating surrounding the dielectric isolator and extending along a predetermined portion of the first and second tubular conductors. The method may include operating an RF source coupled to the RF antenna assembly during a start-up phase to desiccate water adjacent the RF antenna assembly, and operating the RF source coupled to the RF antenna assembly during a sustainment phase to recover hydrocarbons from the subterranean formation.

Abstract: A system for radially expanding a tubular element (2) in an underground borehole (3) comprises an expansion string (16) extending into the tubular element (2) and including an expander (27) and a jack device (24) for pulling the expander (27) through the tubular element (2) so as to radially expand the tubular element (2). The jack device (24) is provided with an anchor (28) having at least one slip element (50) adapted to be radially moved against the inner surface of the tubular element (2). A cage (14) is positioned above the tubular element (2), which cage (14) is surrounded by a cylindrical wall and adapted to receive the anchor (28) and to be radially expanded by the anchor (28) against said cylindrical wall.

Abstract: A downhole tool includes a tool body and a first anchoring device integrated with the tool body. The first anchoring device includes at least two linear actuators within and non-perpendicular to the tool body, each of the at least two linear actuators configured to move a corresponding contact pad between a retracted position and an anchor position. The first anchoring device also includes at least one guide component coupled to each contact pad to restrict movement of a corresponding contact pad to a predetermined path.

Abstract: A device and drilling rig are disclosed for suspending loads from a bail or an elevator of such drilling rig, and method therefor. The device includes an upper bail clamp for clamping around the bail, a lower bail clamp for clamping around the bail, and a connecting part which is connected to the upper bail clamp by means of upper connecting means and connected to the lower bail clamp by means of lower connecting means. The connecting part is further provided with a coupling means for connecting the connecting part to the load to be suspended from the bail. At least one of the upper connecting means allow translational movement of the connecting part with respect to one of the upper bail clamps, while another of the connecting means are arranged to prevent translational movement of the connecting part with respect to the other of the lower bail clamps.

Abstract: In an assembly for lowering and expanding a tubular element in a borehole on an expansion string, at least part of the weight of the tubular element is transmitted to the expansion string via an internal upset and a support protruding from an outer surface of the expansion string below the internal upset.

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.