Abstract: A pultrusion process comprises steps of: pulling a matrix of continuous reinforcement fibers through a wet-out chamber and forming die while injecting thermoplastic resin (e.g. thermoplastic polyurethane) into the wet-out chamber, and providing secondary stations that remove, reform, and/or add material downstream of the forming die using heat and pressure to form a final beam shape with integrally-formed features thereon. The reinforcement matrix is optimally glass fiber, but can include different types of reinforcements, including strands, bundles, mats, weavings, rods, and other reinforcements and combinations of reinforcements, each of which can be strategically located in the beam profile. The final beam includes intermittent or continuous specialized features integrated into the beam along its length, allowing reduction of material waste, reduced/minimized later assembly, and reduced total number of parts.

Abstract: A ladder base device having a base platform and a pair of socket-like receptacles for receiving the ends of a pair of ladder rails. The receptacles are pivotally attached to the platform and the platform is reversible with different surfaces for frictional engagement with different types of ground or floor surfaces on each side.

Abstract: A drilling assembly positionable in a well bore includes a turbine motor couplable to a drill string and a harmonic drive transmission coupled to the turbine motor. The harmonic drive transmission includes a circular spline, a wave generator, a flexspline, and a sealing subsystem. The sealing subsystem defines a substantially sealed volume containing the circular spline, wave generator, and flexspline, and isolates the circular spline, wave generator, and flexspline from drilling fluid exiting the turbine motor and flowing through the harmonic drive transmission.

Abstract: A fluid pressure driven, high frequency percussion hammer for drilling in hard formations is presented. The hammer piston (20) of the percussion hammer has a relatively large and longitudinally extending bore (41) that provides minimal flow resistance for a drilling fluid flowing through the bore (41) during the return stroke of the hammer piston (20). The bore (41) is closeable in the upstream direction by a valve plug (23) that follows the hammer piston (20) during the stroke. The valve plug (23) is controlled by a relatively long and slender valve stem (49) that is mechanically able to stop the valve plug (23) by approximately 75% of the full stroke length of the hammer piston (20) and separates the plug (23) from a seat ring (40). Thus the bore (41) opens up such that the bore fluid can flow there trough, and the inherent tension spring properties of the valve stem (49) returns the valve plug (23) so rapid that it will be good through flow during return of the hammer piston (20).

Abstract: A downhole tool may be operated using a locking clutch. The downhole tool may include an upper downhole motor having a rotor. The downhole tool may also include a lower downhole motor having a shaft. Both the rotor and shaft may rotate relative to the housing. The locking clutch may be coupled to the rotor and the shaft, and may transmit a torque from the rotor to the shaft. The locking clutch may include at least one locking pawl configured to move from an engaged position to a disengaged position when the shaft rotates above a disengagement speed. In the engaged position, the upper downhole motor may provide a torque boost to limit sticking or stall of a drill bit coupled to the downhole tool.

Abstract: A rolling cone drill bit for drilling in earthen formations. In an embodiment, the drill bit comprises a plurality of rolling cone cutters. Each cone cutter includes a plurality of gage cutting elements, a first plurality of bottomhole cutting elements, and a second plurality of bottomhole cutter elements. Each of the first plurality of bottomhole cutting elements is staggered relative to the gage cutting elements on each cone cutter, and the profiles of the gage cutting elements and the first plurality of bottomhole cutting elements on each cone cutter overlap in rotated profile view. Each of the second plurality of bottomhole cutting elements is staggered relative to the first plurality of bottomhole cutting elements on at least one cone cutter, and the profiles of the first plurality of bottomhole cutting elements and the second plurality of bottomhole cutting elements on at least one cone cutter overlap in rotated profile view.

Abstract: A downhole under-reamer for use in reaming a downhole bore. The under-reamer comprises a body and a plurality of cutters mounted on the body. The cutters are mounted on the body so as to be extendable from a retracted position to at least two extended positions. The at least two extended positions comprise reaming positions at respective first and second reaming diameters.

Abstract: A conical feeder is attached to a vertically conveying screw auger. The feeder is equipped with scoops and rotated from the surface to force-feed regolith the auger. Additional scoops are possible by adding a cylindrical section above the conical funnel section. Such then allows the unit to collect material from swaths larger in diameter than the enclosing casing pipe of the screw auger. A third element includes a flexible screw auger. All three can be used in combination in microgravity and zero atmosphere environments to drill and recover a wide area of subsurface regolith and entrained volatiles through a single access point on the surface.

Abstract: Downhole tools are provided with a topographical pattern, and anti-balling material is provided over the topographical pattern. The topographical pattern may be defined by at least one of a plurality of recesses extending into a surface of a body of the tool and a plurality of protrusions protruding from the surface. Downhole tools include an insert disposed within a recess in a body, and the insert comprises an anti-balling material having a composition selected to reduce accumulation of formation cuttings on the tools when the tools are used to form or service a wellbore. Downhole tools include anti-balling material disposed over a porous mass provided over the surfaces of the tools. Methods of forming downhole tools include providing anti-balling material over features on and/or in a surface of a body of a tool. Methods of repairing downhole tools include removing an insert therefrom and disposing a replacement insert therein.

Abstract: A technique facilitates creation of and production from a multilateral well. A lateral junction is deployed downhole to a lateral bore via a conveyance, such as a coiled tubing conveyance. The lateral junction comprises a main bore tubular and a lateral bore tubular which are pivotably joined via a pivotable coupling. The pivotable coupling enables pivoting of the lateral bore tubular outwardly through a lateral opening of the main bore tubular. The construction of the lateral junction enables establishment of a lateral junction, such as a TAML Level 3 or TAML Level 4 junction, in a single trip downhole.

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

Abstract: Disclosed is a release tool used to separate portions of a tool string. One release tool includes a main body, a bolt housing coupled to the main body and defining a bore for receipt of a separation bolt therein, the separation bolt being configured to couple the bolt housing to a lower sub, and a trigger mechanism communicably coupled to the separation bolt and configured to send an electrical signal to the separation bolt whereupon the separation bolt breaks and thereby allows the lower sub to separate from the bolt housing.

Abstract: A pressure responsive downhole tool comprises a threaded shearable retaining mechanism which performs the tension sleeve or shear pin function. The threaded shearable retaining mechanism comprises a pin and box thread that shears upon application of a predetermined pressure which may be adjusted based upon the amount of thread engagement. The pin thread may comprise indicators to indicate which thread engagement corresponds to what shear value. A keystone thread design may be utilized such that the thread would be retained along the threaded connection and not become lost in the well. Thus, the present invention allows for each pressure responsive tool to be custom tailored for a specific job.

Abstract: A downhole tool for dampening vibrational, lateral, compressive, and tensile forces within a drillstring is described. The downhole tool generally includes a bottom end shaft configurable to a drillstring and that is telescopically engaged within a compression housing and a torsional housing. The torsional housing enables the bottom end shaft to slide axially with respect to the torsional housing whilst preventing torsional movement of the bottom end shaft relative to the torsional housing. The compression housing is configurable to drillstring equipment and operatively contains a first spring between the compression housing and the bottom end shaft that absorbs compression forces between bottom end shaft and compression housing.

Abstract: A centralizer sub for cementing a tubular string in a wellbore includes: a tubular body; a centralizer disposed along an outer surface of the body and having a pair of collars and a plurality of bow springs connecting the collars; and a joint longitudinally linking the centralizer to the body. The joint has: a groove formed in and around the body outer surface, and a plurality of protrusions formed integrally with or mounted to one of the collars and extending into the groove.

Abstract: A method for prolonging a wellbore cable life that includes pulling a cable from a wellbore. The method can also include cleaning the cable as the cable is pulled out of the wellbore. The method can also include applying a fluid to the cable as the cable is pulled out of the wellbore.

Abstract: A mobile service rig with an integrated pipe handling assembly is provided. The rig includes an elongate frame, an attached elongate mast, and an attached a pipe handling assembly. The mast base is pivotally attached to the frame for moving the mast between horizontal and vertical orientations. The pipe handling assembly includes a pipe trough and a trough lifting arm pivotally attached to frame and pipe trough to move a pipe between a horizontal orientation and a vertical orientation collinear with the mast in the vertical orientation. The pipe handling assembly may also include a pair of pipe racks pivotally attached to the frame to extend transversely away from the frame.

Abstract: A sensor assembly may include a housing made of a non-magnetic material. The housing may define an interior chamber. A shaft may extend from the housing. A bearing may be positioned around the shaft. An impeller may be positioned around the shaft and the bearing, and the impeller may include a magnetized portion. A sensor may be positioned within the interior chamber and/or proximate the magnetized portion. The sensor may detect the magnetized portion of the impeller to sense a rate of rotation of the impeller. The rate of rotation of the impeller may correspond to changes in flow rate of the fluid. As the flow rate of the fluid, and the rate of rotation of the impeller change in predetermined manners, control signals may be conveyed to activate a tool.

Abstract: In one embodiment, a method for drilling a wellbore includes injecting drilling fluid through a drill string disposed in the wellbore and rotating a drill bit disposed on a bottom of the drill string. The drilling fluid includes a liquid and a gas. The drilling fluid is injected at the surface. The drilling fluid exits the drill bit and carries cuttings from the drill bit. The drilling fluid and cuttings (returns) flow to the surface via an annulus formed between the drill string and the wellbore. The liquid is injected at a rate so that a liquid velocity of the returns in the annulus is sufficient to transport the cuttings. The method further includes drilling through at least a portion of a non-productive formation.

Abstract: A core barrel support system for supporting at least one core barrel during removal of a core sample from the at least one core barrel. The core barrel support system includes an enclosure, a first core barrel holder secured to and positioned witin the enclosure and configured to receive a first core barrel, and a sonic vibrator positioned proximate the first core barrel holder. The sonic vibrator applies sonic energy to the core sample within each respective core barrel of the at least one core barrel.

Abstract: A milling tool includes a cutting insert coupled to a movable blade. The movable blade may change from a retracted to an expanded state to engage and cut downhole casing. A cutout initiation region of the movable blade makes contact with the downhole casing, and cutting inserts with turning portions designed to cut in a turning manner may be located in the cutout initiation region. Cutting inserts with milling portions designed to cut in a face-milling manner may be located outside the cutout initiation region. Some cutting inserts may include both turning portions and milling portions.

Abstract: A gripper assembly for anchoring a tool within a downhole passage and for possibly assisting movement of the tool within the passage. The gripper assembly includes an elongated mandrel and flexible toes that can be radially displaced to grip onto the surface of the passage. The toes are displaced by the interaction of a driver slidable on the mandrel and a driver interaction element on the toes. In one embodiment, the toes are displaced by the interaction of rollers and ramps that are longitudinally movable with respect to one another. In another embodiment, the toes are displaced by the interaction of toggles that rotate with respect to the toes.

Abstract: A downhole tool having a first packing element and a second packing element configured to synchronically set to selectively hydraulically isolate a portion of the wellbore. The movement of a pin along a j-slot track on a second sleeve sets the second packer in compression and the movement of a pin along a j-slot track on a first sleeve the first packer in tension after the second packer has been set. The j-slot track on the first sleeve has six different pin positions and the j-slot track on the second sleeve has four different pin positions. The pin positions and direction of travel of the j-slot tracks are adapted to permit the synchronized setting of the two packing elements to hydraulically isolate a portion of the wellbore. The wellbore may then be treated by flowing fluid out of a ported sub positioned between the packing elements.

Abstract: The present disclosure relates to a removable orifice plate device which has an orifice plate having a circular portion with an aperture therein, and a graspable end portion extending therefrom. A tee body is included which has oppositely extending first and second tee runs and a tee branch. The tee runs are coupled to gas inflow and outflow pipes. The tee body has internal structure forming a slot which is aligned with an opening formed by the tee branch, and which receives the circular portion of the orifice plate. The orifice plate, when installed in the slot in the tee body, thus allows a flow of fluid only through the aperture. A removable cover encloses the orifice plate within the tee body.

Abstract: An annular drilling device is provided that employs an active or passive, stationary sealing element. More specifically, rotating annular drilling devices commonly used depend on externally pressurized sealing elements that are energized by wellhead pressure or hydraulic pressure to grip a rotating drill pipe and rotate with the drill string. Thus, a plurality of rotary seals and bearings must be used. Here, however, the passive or active sealing element is stationary, thereby eliminating the need for bearings, etc. The passive or active stationary sealing element is made of a low-friction material that contacts the drill pipe, creates a seal, and does not adversely affect drilling operations.

Abstract: A system, in certain embodiments, includes a casing head and a tubing hanger disposed within the casing head and supported by a first retaining feature of the casing head. The tubing hanger is configured to support a tubing string. The system also includes a guide string hanger disposed within the casing head and supported by a second retaining feature of the casing head independent of the first retaining feature. The guide string hanger is configured to support a guide string.

Abstract: An apparatus comprises a first bearing assembly, a second bearing assembly, a housing and a pipe. The first bearing assembly, the second bearing assembly and the housing define an interior space. The pipe extends through the first bearing assembly and the second bearing assembly and through the interior space.

Abstract: A system including, a mineral extraction component, a conduit fitting coupled to the mineral extraction component, a floating seal insert disposed in the conduit fitting. The floating seal insert includes a feature configured to tune a fluid dynamic characteristic along a liquid flow path through the conduit fitting and the floating seal insert. Furthermore, the fluid dynamic characteristic can be shockwaves, flow rate, turbulence, etc.

Abstract: An independently operable disconnect device remotely disconnectable from an LMRP to reveal a riser profile compatible with a capping device connecter. A capping device including a capping device connector to be coupled to said riser profile. The capping device includes at least one blow-out preventer operable to stop the overflow of petroleum products from a well. Thus, a drilling marine riser may be fully disconnected from an LMRP in an emergency. Then the well may be subsequently capped.

Abstract: A downhole tool having a first packing element and a second packing element configured to synchronically set to selectively hydraulically isolate a portion of the wellbore. The lower packing element may be first set against the well with the upper packing element next being set against the well. A slip joint permits a change in distance between the packing elements during the setting of the packing elements. The slip joint may be energized to apply a force to the lower packing element to prevent the unsetting of the lower packing element during the setting of the upper packing element. A resilient member may be used to energize the slip joint or the slip joint could be hydraulically or pneumatically energized. Once both packing elements are set, the wellbore may then be treated by flowing fluid out of a ported sub positioned between the packing elements.

Abstract: A wellbore completion method comprising disposing a pressure relief-assisted packer comprising two packer elements within an axial flow bore of a first tubular string disposed within a wellbore so as to define an annular space between the pressure relief-assisted packer and the first tubular string, and setting the pressure relief-assisted packer such that a portion of the annular space between the two packer elements comes into fluid communication with a pressure relief volume during the setting of the pressure relief-assisted packer.

Abstract: Embodiments of the present disclosure include a plugging assembly configured to be disposed within a production flow bore of a tubing spool tree, wherein the plugging assembly includes a body having a central bore, a lock ring disposed about the body, a support sleeve slidably disposed about the body, and an inner body support pin coupled to the support sleeve and extending into the central bore of the body, wherein axial actuation of the inner body support pin drives the support sleeve between the body and the lock ring to actuate the lock ring radially outward, and wherein the plugging assembly is configured to be disposed within a production flow bore of a tubing spool tree.

Abstract: The present invention relates to a millable plugging device for use in a well pipe. The device includes an inner mandrel and an outer housing provided radially outside at least parts of the inner mandrel. A sealing assembly is provided radially outside the inner mandrel, where the sealing assembly is configured to be brought from a run state to a set state by a relative axial displacement between the inner mandrel and the outer housing. The millable plugging device has a first center axis and the second mandrel section has a second center axis which is displaced parallel in relation to the first center axis. Rotation of the inner mandrel in the set state is bringing a third mandrel section of the mandrel to a locked state, in which further rotation of the inner mandrel is prevented.

Abstract: A straddle packer system includes an upper seal member, a lower seal member, an upper equalizing valve configured to equalize pressure across the upper seal member, a lower equalizing valve configured to equalize pressure across the lower seal member, and an anchor. The upper and lower seal members do not move when actuating the upper and lower equalizing valves, respectively, into an unloading position to equalize the pressure across the upper and lower seal members.

Abstract: Disclosed are wellbore flow control devices that allow on-site field adjustments to flow characteristics. One autonomous inflow control device (AICD) assembly includes a base pipe defining one or more flow ports and an interior, at least one AICD arranged on the base pipe and having at least one fluid inlet and an outlet in fluid communication with one of the one or more flow ports, and a fluid barrier configured to be arranged about the at least one AICD by a well operator on-site and configured to isolate the at least one AICD from an influx of fluid during operation.

Abstract: A production string pressure relief system comprising a hollow cylindrical housing with an outer wall, a first relief valve assembly that is mounted on a first support base that is welded to the outer wall of the housing, and a second relief valve assembly that is mounted on a second support base that is welded to the outer wall of the housing directly opposite the first support base. Each of the first and second relief valve assemblies comprises a valve element that is in the shape of a spherical segment with a spherical sealing face, a cylindrical valve seat with a circular sealing face, and a leaf spring. The leaf spring provides a biasing force that pushes the spherical sealing face of the valve element against the circular sealing face of the valve seat to form a fluid-tight seal when the valve is in a normally closed position.

Abstract: A tool string having a pressure dependent mandrel and actuator assembly can operate at the annulus pressure within a wellbore to lock the mandrel actuator assembly and prevent further motion of the mandrel within the tool string as the tool string is moved upward or downward in the wellbore. The tool string can further include a valve connected to the actuator assembly, where the valve can be in an open configuration within the wellbore due to the annulus pressure and related motion of the mandrel, and then be locked in an open configuration regardless of the annulus pressure as the tool string is moved upward or downward in the wellbore.

Abstract: It is sometimes desirable to regulate fluid flow using autonomous inflow control devices (AICDs), but they are not readily configurable in the field. Wellbore systems providing adjustable flow control may comprise: a wellbore pipe having an interior space, an outer surface, and one or more orifices defined in the wellbore pipe and extending between the interior space and the outer surface; a flow control assembly fixedly coupled to the wellbore pipe and comprising one or more flow chambers defined on the outer surface of the wellbore pipe that are in fluid communication with the one or more orifices; a movable cover configured to provide access to the one or more flow chambers; and a bung arranged within at least one of the one or more orifices, the bung being configured to accept an insert therein, the insert being at least one of an AICD, a blank, or any combination thereof.

Abstract: The present invention provides a bridge concentric continuously adjustable water regulator, comprising: an outer tube; an adjusting sleeve disposed in the outer tube; a concentric valve connected below the adjusting sleeve, with a center of circle of the concentric valve being concentric to the outer tube; a water outlet which runs through a side wall of the outer tube and is connected to the concentric valve; a lower sealed section which is disposed in the outer tube and is below the concentric valve and the water outlet; and a bridge passage disposed in the side wall of the outer tube and outside the concentric valve and the lower sealed section. The present invention provides necessary conditions in order to satisfy single-layer testing of bridge concentric layered water injection, thereby realizing single-layer direct testing to improve the testing accuracy.

Abstract: A wellbore system comprising an autofill and circulation assembly comprising a housing defining a flowbore and comprising a first port and a second port, and a first sleeve slidable within the housing from a first position to a second position and from the second position to a third position, when the first sleeve is in the first position, the assembly allows fluid communication from an exterior of the housing to the flowbore via the first port and does not allow fluid communication from the flowbore to the exterior of the housing via the first port, when the first sleeve is in the second position, the assembly allows bidirectional fluid communication between the exterior of the housing and the flowbore via the second port, and, when the first sleeve is in the third position, the assembly disallows fluid communication between the exterior of the housing and the flowbore.

Abstract: A locking apparatus for attaching to an end of a valve actuator includes an assembly body, the assembly body releasably securable to a valve actuator. The assembly body has a stem bore for receiving an actuator stem, and a plunger orifice through a sidewall of the assembly body. An immobilizer assembly has a plunger extending through the plunger orifice, and biased radially outward and moveable between a radially inner position where the immobilizer assembly extends over the stem bore, and a radially outer position where an inner end of the immobilizer assembly is radially outward of the stem bore. A segmented housing circumscribes the assembly body and is moveable between a first position where the plunger is in the radially outer position and a second position where the plunger is in the radially inner position. A fusible band selectively retains the segmented housing in engagement with the immobilizer assembly.

Abstract: A device for a drill rig comprising a ruggedized housing and a sensor contained in the ruggedized housing, the sensor adapted to measure at least one condition of a lubrication oil of an equipment on the drill rig. In an embodiment, the ruggedized housing can have a Class I, Division 1 & 2 standard rating according to UL1203 & FM3600(3615).

Abstract: In one aspect, the present invention relates to a drilling-information-management system. The drilling-information management system includes a probe assembly disposed on a drill rod, a first computer interoperably coupled to the probe assembly via a conductor disposed in a drill rod, and a second computer in communication with the first computer. The second computer includes a barcode scanner. The drilling-information management system includes a database in communication with the second computer. Drilling-project data is transferred from the database to the second computer and calibration data is transferred from the second computer to the first computer. The first computer executes a drilling plan according to the drilling-project data.

Abstract: A system includes a subsea on-site chemical injection management system configured to inject a chemical mixture into a well, wherein the subsea on-site chemical injection management system includes a subsea on-site head tank configured to store a plurality of discrete chemicals, a subsea on-site mixing unit configured to mix one or more of the plurality of discrete chemicals to create one or more chemical mixtures, and a subsea on-site distribution unit configured to distribute the one or more chemical mixtures to the well.

Abstract: Disclosed are sand control screen assemblies that include one or more erosion-resistant modules. One sand control screen assembly includes a base pipe defining one or more flow ports that provide fluid communication into an interior of the base pipe, a well screen arranged about the base pipe and in fluid communication with the one or more flow ports via a flow path extending between the well screen and the one or more flow ports, and an erosion module arranged within the flow path and comprising an erosion-resistant material, the erosion-resistant material being configured to filter a fluid prior to the fluid entering the interior of the base pipe.

Abstract: A perforating gun of a perforating gun system is provided including hollow charges positioned within a holding device. The holding device includes holes in which the hollow charges are inserted and secured. In an embodiment, the holes are arranged on at least one helix. In a further embodiment, the perforating gun provides collapsible and fragmentable components that minimize debris remaining in a wellbore upon detonation of the charges.

Abstract: A method of controlling a dynamic pressure created during detonation of a shaped charge comprises: positioning the shaped charge in a wellbore, wherein the shaped charge comprises a main explosive load, wherein a substance is included in the main explosive load or is positioned adjacent to the main explosive load, wherein the substance increases or decreases the dynamic pressure or increases or decreases the duration of a pressure pulse created during detonation of the shaped charge; whereas a substantially identical shaped charge without the substance does not increase or decrease the dynamic pressure nor increase or decrease the duration of the pressure pulse during detonation. A method of controlling the balance of a portion of a wellbore comprises: positioning the shaped charge in the portion of the wellbore; and creating a desired balance in the portion of the wellbore.

Abstract: A quick connection for coiled tubing run tools eases the assembly and disassembly while deploying such tools. The quick connection utilizes a locking collet and an inner mandrel with locking sleeve system. Such a quick connection does not require perfect alignment between mating pieces.

Abstract: A wireline-assisted coiled-tubing portion is arranged to be lowered into a well in a ground. The wireline-assisted coiled-tubing portion comprises a coiled-tubing portion, the coiled-tubing portion in its entirety being arranged to be lowered into the well; and a wire which is attached to an, in the position of application, upper portion of the coiled-tubing portion, the wire extending from the coiled-tubing portion to the opening of the well at a surface, and the wire being arranged to transmit electrical energy and electrical signals.

Abstract: A method and apparatus for improving the production efficiency of a well and preventing gas lock. The apparatus is a downhole pump and comprises a barrel, a reciprocating plunger and a body having a plurality of inlet valves. The apparatus does not require outlet valves. The body and inlet valves are positioned above the barrel and plunger, thus eliminating gas lock. Fluids enter the body through the valves and, during upstrokes of the plunger, are forced up the tubing string to the surface equipment. Modularity of the components permits pump components to be changed as the productivity of the well fluctuates and also allows production of more fluids with a smaller casing. The invention prevents gas lock by permitting gasses to escape between a sliding valve and a valve rod connected to the plunger. Additionally, an exit valve sealably engages the valve rod, which forms an aperture. During operation of the pump, the gasses escape through the aperture in the valve rod and rise up the tubing string.