Abstract: A drill bit of the type used to drill a wellbore in the earth can comprise a bore formed in the drill bit, and a plug sealingly and reciprocably disposed in the bore, whereby the plug prevents fluid communication between sections of the bore in the drill bit. The plug can comprise a spherically-shaped member. The plug can comprise a floating plug sealingly and reciprocably disposed in the bore, whereby pressure in the different sections of the bore on respective opposite sides of the plug is substantially equalized.

Abstract: Disclosed are systems and methods of balancing weight distribution between downhole cutting tools. One system includes a drill bit arranged at a distal end of the bottom-hole assembly, a first sensor sub arranged proximate to the drill bit and configured to monitor one or more operational parameters corresponding to the drill bit, a reamer axially-offset from the drill bit on the bottom-hole assembly, a second sensor sub arranged proximate to the reamer and configured to monitor one or more operational parameters of the reamer, and a communications module communicably coupled to the first and second sensor subs and configured to communicate one or more corrective action signals when the one or more operational parameters of the drill bit and the reamer surpass a predetermined operating threshold.

Abstract: An apparatus and method for manufacturing a downhole tool that reduces failures occurring along a bondline between a cemented matrix coupled around a blank. The cemented matrix material is formed from a tungsten carbide powder, a shoulder powder, and a binder material, wherein at least one of the tungsten carbide powder or the shoulder powder is absent of any free tungsten. The blank, which optionally may be coated, is substantially cylindrically shaped and defines a channel extending from a top portion and through a bottom portion of the blank. The absence of free tungsten from at least one of the tungsten carbide powder or the shoulder powder reduces the reaction with iron from the blank, thereby allowing the control and reduction of intermetallic compounds thickness within the bondline.

Abstract: A rotary drag bit includes a primary cutter row comprising at least one primary cutter mounted on a blade, at least some cutters in the primary cutter row having a portion of a cutting surface thereof covered by a portion of the blade. A backup cutter row comprising at least one cutter may also be included, and at least a portion of a cutting surface of at least some cutters in the backup cutter row is covered by a portion of the blade. Enhanced support for cutters is provided against impact loading.

Abstract: An earth-boring tool includes a formation-engaging structure with a formation-engaging surface at a distal end and a side surface between a proximal end and the distal end along a central axis of the formation-engaging structure. A generally linear recess may be formed in the side surface along an axis oriented at a non-parallel angle relative to the central axis of the formation-engaging structure. A generally helical recess may be formed in the side surface, and the generally helical recess may intersect the generally linear recess. Earth-boring tools may include such formation-engaging structures. Methods may be used to form such formation-engaging structures.

Abstract: Hardfacing compositions include grains of hard material embedded within a cobalt-based metal alloy that includes ruthenium. Earth-boring tools include such hardfacing compositions on one or more surfaces thereof. Methods of applying hardfacing to an earth-boring tool include embedding grains of hard material in a molten cobalt-based metal alloy including ruthenium on a surface of an earth-boring tool, and cooling and solidifying the molten cobalt-based metal alloy with the grains of hard material embedded therein.

Abstract: Cutting elements for earth-boring tools comprise a substrate including at least one material selected from the group consisting of CoCr, CoCrMo, CoCrW, and Ti. A polycrystalline superabrasive material may be attached to the substrate. Earth-boring tools comprise a body. At least one cutting element is attached to the body. The at least one cutting element comprises a substrate including at least one material selected from the group consisting of CoCr, CoCrMo, CoCrW, and Ti. A polycrystalline superabrasive material may be attached to the substrate. Methods of forming cutting elements for earth-boring tools comprise disposing a substrate including at least one material selected from the group consisting of CoCr, CoCrMo, CoCrW, and Ti in a container. Particles of superabrasive material may be disposed in the container. The particles of superabrasive material may be sintered with the substrate in the container to form a polycrystalline superabrasive material attached to the substrate.

Abstract: A riser assembly and method of producing a riser assembly for transporting fluids from a sub-sea location is disclosed. The assembly includes a riser comprising at least one segment of flexible pipe, the riser having a first end for connection to a floating facility and a further end; at least one buoyancy element for enabling a portion of the riser to form a hog bend configuration and an adjacent portion of the riser to form a sag bend configuration; and a weight element provided between the first end of the riser and the at least one buoyancy element, such that in an initial deployment position, the weight element is provided at least partially in the sag bend portion of the riser.

Abstract: An apparatus for gripping a support member is described. The apparatus comprises a tubular clamp, the tubular clamp defining a throughbore adapted to receive a support member therethrough, a first apparatus member adapted to engage a first portion of an external surface of the tubular clamp, and a second apparatus member adapted to engage a second portion of the external surface of the tubular clamp. Relative movement of the first apparatus member with respect to the tubular damp in a first direction results in a deflection of a section of a first end of the tubular clamp into the clamp throughbore and relative movement of the second apparatus member in a second direction, opposite the first direction, with respect to the tubular clamp results in a deflection of a section of a second end of the tubular clamp into the clamp throughbore.

Abstract: A top drive system is provided. In one embodiment, a top drive includes a drive stem and a load nut with mating threaded surfaces that enable the drive stem to be threaded through the load nut and to support weight of a connected drill string via the load nut. One or both of the mating threaded surfaces may have a threadform with one or more undercut thread roots. Additionally, a portion of the mating threaded surfaces, such as thread roots of the drive stem, can be shot-peened. Additional systems, devices, and methods are also disclosed.

Abstract: A method and a safety device are disclosed for protection of well barrier(s) against excessive bending moments from a riser. The safety device is arranged to detect critical bending loads in or in between the well barrier(s) and/or riser, and may include: a device for detecting changes in a curvature between a load carrying riser pipe and an unloaded stiff body attached to or in the vicinity of the riser pipe, said device for detecting changes in the curvature being arranged to measure a relative distance between the load carrying riser pipe and the unloaded stiff body, and a device for triggering disconnection of a releasable riser connector when the distance between the load carrying riser pipe and the unloaded stiff body reaches a predefined critical distance.

Abstract: A method for installing multiple fiber optic cables in coiled tubing in oil and gas operations.

Abstract: A method for installing multiple fiber optic cables in coiled tubing in oil and gas operations.

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

Abstract: Device (11) for compensation of wave induced distance variations to a drill string between a floating drill rig and a seabed-fixed installation, comprising an extendable cylinder/piston unit (12) which is arranged to be able to compensate when the load exceeds a pre-determined threshold value. The cylinder (13) of the cylinder/piston unit (12) comprises a non-compressible liquid at both sides of a piston (14) positioned substantially in the middle of the cylinder (13) and is prevented from fluid communication with the surroundings. A control valve (19) is arranged to activate the device (11) by opening for fluid communication between the cylinder (13) and a gas containing accumulator (17) when the load exceeds a predetermined threshold value. The device is characterized by being a complete, self-supported unit comprising cylinder (13), piston (14) on a piston rod (15), accumulator (17), control valve (19) and drainage tank (20).

Abstract: A hydraulic cylinder unit for connection to a wire line riser tensioner system includes a hydraulic cylinder comprising a cylinder piston separating a first cylinder chamber from a second cylinder chamber. A low pressure tank is arranged as a closed cylinder. A first conduit is inserted into the closed cylinder and provides a fluid communication between the low pressure tank and the first cylinder chamber. A second conduit provides a fluid communication between a high pressure fluid reservoir and the second cylinder chamber. A feedback conduit provides a fluid communication between the first cylinder chamber and the second cylinder chamber. A valve element comprising at least one valve is configured to be in a fluid communication with the at least one first conduit and the at least one feedback conduit. The valve element is configured to provide a reversible switching between a first alternative configuration and a second alternative configuration.

Abstract: A connection lift system for handling oil and gas drilling tubular components includes a core component and a ring-shaped component. A range of ring-shaped components may be screwed onto the core component. The ring-shaped component may be configured based on the tubular component to be handled, and the core may be compatible with lifting equipment. A method for handling tubular components is also provided.

Abstract: A combination for making up and breaking out pipe at an oil rig site includes a torque module and at least one pipe clamp apparatus. The torque module includes a pair of hydraulic motors, a torque transmission driven by the motors, a herringbone gear segment driven by the transmission to rotate the torque module, and a pair of clamp cylinders actuated by the transmission. The at least one pipe clamp apparatus is actuated by at least one of the clamp cylinders to apply a uniform gripping load around a pipe that is pipe diameter independent.

Abstract: Systems and methods for separating fluids from drill cuttings, specifically, shakers that incorporate modifications including vacuum systems and/or partitions and methods of operating such shakers to affect a high degree of fluid separation. The systems and methods are effective across a variety of screen sizes, vacuum flows and vacuum designs. The systems are also particularly effective in assisting in the separation of gases from drilling fluids.

Abstract: A wellbore workstring. The workstring comprises a tubular string and a plurality of robots coupled to the tubular string. The robots establish a wireless communication network within a wellbore and deploy actuators to move themselves relative to the tubular string.

Abstract: A downhole tool comprises a housing defining a main bore and an actuatable member moveable from a first configuration to a second configuration to permit actuation of the tool. The tool includes an indexer mounted within the housing and arranged to progress linearly in a first direction along the main bore of the housing in a predetermined number of discrete sequential and progressive steps of linear movement in said first direction by passage of a corresponding number of objects through the indexer to cause said actuatable member to move towards its second configuration.

Abstract: An anchoring system includes a housing having a radial opening therein, and a piston disposed within the housing which is axially movable therein. A slip is in operable communication with the piston such that movement of the piston in a first axial direction relative to the housing causes movement of the slip in a first radial direction relative to the housing to anchor the anchoring system to a structure and movement of the piston in a second axial direction allows the slip to move in a second radial direction that allows unanchoring of the anchoring system. A sleeve is configured to cause movement of the piston in the second axial direction when moved in the second axial direction relative to the housing, in response to either mechanically pulling the sleeve in the second axial direction or increasing pressure applied against the piston.

Abstract: The present invention relates to a downhole driving unit (11) for insertion into a well, comprising a driving unit housing (51), a hydraulic motor (23) comprising a hydraulic motor housing (93), a wheel assembly (90) comprising a stationary part (91) and a rotational part (92), the stationary part being connected with the driving unit housing and being rotatably connected with the rotational part, the stationary part and the rotational part constituting the hydraulic motor housing, the rotational part comprising a wheel ring (99) closed from one end, wherein the wheel assembly comprises a spring member (113) assembling the hydraulic motor housing.

Abstract: A method of completing a subsea wellbore includes providing one or more conductor anchoring assemblies on an outer surface of a conductor; forming the subsea wellbore; positioning the conductor in the subsea wellbore; and energizing the one or more conductor anchoring assemblies into contact with the subsea wellbore, thereby stabilizing the conductor in the subsea wellbore. In yet another embodiment, the method further includes extending the subsea wellbore; positioning a casing inside the conductor, wherein the casing includes a casing anchoring assembly; and energizing the casing anchoring assembly into contact with the conductor.

Abstract: A hydraulic setting tool. The tool is configured to allow hydraulic setting of a bridge plug, packer or other radially expansive mechanical well isolation mechanism. Wireline or slickline deployment may be utilized. In either case, parameters of the setting application may be recorded. In the case of wireline deployment such parameters and downhole data may be monitored in real-time allowing an operator to make intelligent setting application adjustments as necessary.

Abstract: High productivity core drilling systems include a drill string, an inner core barrel assembly, an outer core barrel assembly, and a retrieval tool that connects the inner core barrel assembly to a wireline cable and hoist. The drill string comprises multiple variable geometry drill rods. The inner core barrel assembly comprises a non-dragging latching mechanism, such as a fluid-driven latching mechanism that contains a detect mechanism that retains the latches in either an engaged or a retracted position. The inner core barrel assembly also comprised high efficiency fluid porting.

Abstract: A method includes conveying a casing cutting tool into the wellbore lined with at least one casing string and cement, and stroking the casing cutting tool over a predetermined axial length of the wellbore while ejecting fluid from one or more nozzles in the casing cutting tool and thereby forming a plurality of longitudinal cuts through the casing string and cement. The casing cutting tool is then rotated about its longitudinal axis at two or more axially offset locations along the predetermined axial length while ejecting fluid from nozzles and thereby forming a plurality of axially offset transverse cuts in the casing string and the cement. The longitudinal cuts and axially offset transverse cuts form wedges in the wellbore, and the wedges are dislodged from the wellbore to expose formation rock along the predetermined axial length.

Abstract: A system and method is provided for hydraulically presetting a metal-to-metal seal, which may be installed in an annular space between wellhead components. A hydraulic running tool may be landed on a first wellhead component and coupled to a second wellhead component, for example, via a hydraulic or mechanical coupling assembly. Fluid pressure may then be applied to the hydraulic running tool to move the components axially together, thereby setting the metal-to-metal seal (i.e., axially compressing and radially expanding the seal). A coupling may secure the wellhead components in place relative to one another, while fluid pressure is being applied so that the metal-to-metal seal remains in the set position after the hydraulic tool is removed.

Abstract: A power triad of an umbilical may be rotated during multiple transition lengths to position each power cable of the power triad equally at radial orientation over the length of the umbilical. A first portion of the umbilical includes the triad in a first radial orientation, a second portion of the umbilical includes the triad in a second radial orientation, and a third portion of the umbilical includes the triad in a third radial orientation. The triad is rotated a first one hundred twenty degrees from the first radial orientation to the second radial orientation during a first transition length. The triad is rotated a second one hundred twenty degrees from the second radial orientation to the third radial orientation during a second transition length. The use of three radial orientations along the length of the umbilical may reduce imbalances between the power cables of the triad.

Abstract: A high energy tubular shear is connectable within a drilling system and includes a body forming a bore through which a tubular is disposed, a cross-bore intersecting the bore, opposing cutters moveably positioned in the cross-bore on opposite sides of the bore, and the each cutter in hydraulic communication with a respective hydraulic intensifier.

Abstract: A system for tethering a subsea blowout preventer (BOP) includes a plurality of anchors disposed about the subsea BOP and secured to the sea floor. In addition, the system includes a plurality of tensioning systems. One tensioning system is coupled to an upper end of each anchor. Further, the system includes a plurality of flexible tension members. Each tension member extends from a first end coupled to the subsea BOP to a second end coupled to one of the tensioning systems. Each tensioning system is configured to apply a tensile preload to one of the tension members.

Abstract: An acoustic control system wirelessly operates a subsea latching assembly or other subsea device, such as an active seal. The acoustic control system may control a subsea first accumulator to release its stored hydraulic fluid to operate the latch assembly or other subsea device, such as an active seal. An RCD or other oilfield device may be unlatched or latched with the latching assembly. The acoustic control system may have a surface control unit, a subsea control unit, and two or more acoustic signal devices. A valve may allow switching from an umbilical line system to the acoustic control system accumulator.

Abstract: A straddle packer tool for setting against a constraining wall includes: a drag assembly with a locking mechanism for locking a position of the drag assembly relative to the constraining wall; a mandrel installed in and axially moveable through an inner bore of the drag assembly; and a packing element housing including a first annular packing element and a second annular packing element spaced from the first annular packing element, the packing element housing positioned between a stop shoulder on the mandrel and the drag assembly, the packing element being settable to expand the first annular packing element and the second annular packing element by compression between the drag assembly and the stop shoulder. A valve sub including a pressure actuated piston is also described and may be operated to open using the straddle packer tool.

Abstract: A flow back plug, a bridge plug, a ball drop plug and plug with a disintegratable check therein are made from a common subassembly including, in some embodiments, a mandrel, a slips/seal section, a setting assembly and a mule shoe. In other embodiments, the common components are a mandrel, a slips/seal section and a mule shoe. To make the flow back plug, a ball check is placed in the mule shoe. To make the bridge plug, an obstruction is inserted in the mule shoe. To make the ball drop plug, the mule shoe is left unobstructed so any ball dropped in a well seats in a tapered inlet to the mandrel. To make a plug with a disintegratable check, a ball dropped in the well is of a type that disintegrated in frac liquids. The setting assembly includes a setting rod connected to a setting device in the mandrel passage. When the plug is expanded into sealing engagement with a production string, the setting rod pulls out of the setting device leaving a passage through the mandrel and through the setting device.

Abstract: A screening assembly with a swellable packer incorporated onto the exterior of the screen that swells in the presence of water or hydrocarbons. The swellable packer swells at a rate that allows the gravel pack operation to proceed without hindering the gravel pack operation but then swells to seal the annular region around the exterior of a blank tubular at the upper end of the screen. By running in a swellable packer with the screen assembly at least one additional trip into the wellbore may be eliminated.

Abstract: A setting assembly including a settable member. A housing including a chamber and a setting material disposed in the chamber and having a first phase of matter and a second phase of matter. The setting material occupying a greater volume in the second phase than in the first phase. The setting material arranged to exert a setting force on the settable member during transition of the setting material from the first phase to the second phase. Also included is a method of setting a settable member.

Abstract: A method for isolating a perforated interval of a well, the well including a casing liner having a wall with a plurality of perforations therethrough forming the perforated interval, the method comprising: providing a tool including a tubular body including an inner diameter and an outer surface, a first open end and a second open end, the first and second open ends providing access to the inner diameter; and a sealing element to isolate a mid region of the outer surface from the first open end and the second open end; positioning the tool in the well with the tubular first open end adjacent and above an uppermost perforation of the perforated interval and the second open end adjacent and below a lowermost perforation of the perforated interval; and installing the tool in the well with the sealing element sealing between the tubular body and the casing wall above the uppermost perforation of the perforated interval and below the lowermost perforation of the perforated interval to isolate fluid flow between th

Abstract: A safety mechanism (401) comprising: (i) an obstructing member (412,414) moveable between a first position where fluid flow is permitted, and a second position where fluid flow is restricted; (ii) a movement mechanism (416,418); (iii) a wireless receiver (360), optionally a transceiver, adapted to receive a wireless signal such as electromagnetic or acoustic. The movement mechanism (416,418) is operable to move the obstructing member (412,414) from one of the first and second positions to the other of the first and second positions in response to a change in the signal being received by the wireless receiver (360). The safety mechanism also has (iv) a valve (401) in a casing sub; the valve (401) being adapted to move from one of the first and second positions to the other of the first and second positions, and then back to the first of the first and second positions.

Abstract: The present invention relates to an annular barrier for being expanded in an annulus between a well tubular structure and an inside wall of a borehole downhole. The annular barrier comprises a tubular part for mounting as part of the well tubular structure; an expandable sleeve made of a first metal, surrounding the tubular part and defining a space being in fluid communication with an inside of the tubular part, the expandable sleeve having a longitudinal extension, an inner face facing the tubular part and two ends; a connection part made of a second metal, connecting the expandable sleeve with the tubular part; an opening for letting fluid into the space to expand the sleeve, and a transition area comprising a connection of the sleeve with the connection part.

Abstract: A packer tool having simple and reliable setting and release systems comprising three or more slips evenly distributed around a mandrel. Each slip comprises two members with gripping teeth which, except for one slip, typically have the capacity to grip a well casing in opposite axial directions. The remaining slip has only one member with teeth able to grip the casing, the other slip member has dummy teeth with nil gripping capacity. The latter teeth have blunt or rounded edges and are not slanted in a selective gripping direction as the sharper teeth of the other slip members.

Abstract: An internal completion string is anchored within a closed casing valve of a production liner in a wellbore. The internal completion string comprises a packer and a shifting tool. The production liner comprises a casing valve having a port and a moveable member. The annulus defined between the production liner and the internal completion string is sealed, and the shifting tool is remotely operated to move the moveable member away from the port, thereby opening the casing valve.

Abstract: The present invention relates to downhole tools and methods of removing such tools from wellbores. More particularly, the present invention relates to downhole tools designed to be comprised of dissolvable materials or frangible materials and methods for dissolving or fragmenting such downhole tools in situ.

Abstract: The presently disclosed technique provides a method for operating a valve in a wellbore by: applying a first fluid pressure to a bore of the valve; trapping the first fluid pressure in a portion of the valve; reducing the pressure in the bore of the valve to a second fluid pressure thereby creating a pressure differential between the portion of the valve and the bore of the valve; and opening the valve responsive to the pressure differential. The valve may employ a first piston disposed in the body to trap a first fluid pressure in a chamber to create a differential pressure across a second piston when a second fluid pressure is applied to open the valve to fluid flow therethrough. The valve and the method may be used to actuate another valve downhole.

Abstract: A shifting sleeve has differential piston areas so that applied pressure displaces the sleeve against spring bias, which preferably is a series of Belleville washer stacks associated with modular mandrel components, to obtain the desired opposing force to the movement initiated with pressure applied to differential piston areas. An indexing feature is located between the sleeve and the mandrel passage wall and on a predetermined number of cycles disables the Belleville washer stacks from biasing the sleeve in an opposed direction as when pressure is applied. At this time the pressure in the mandrel acting on the differential piston area simply shifts the sleeve to open a lateral port so that fracturing through the cement that was earlier placed with the port closed can take place.

Abstract: A resettable downhole tool actuator comprises a housing, a collet slidable within the housing and defining a seating with which a ball is engageable, in use, the collet being mounted upon a moveable support including a piston and arranged such that, when the bail engages the seating, fluid flow through an axially extending passage provided in the support is restricted, the housing including an increased diameter region arranged such that, when the seating is aligned with the increased diameter region, outward deflection of the collet permits the ball to pass through the seating and through the axially extending passage.

Abstract: A method, apparatus and system for cooling a component of a downhole tool is disclosed. The apparatus includes a first desiccant configured to adsorb a refrigerant gas. A transmitter is configured to transmit electromagnetic energy into the first desiccant to enable desorption of the refrigerant gas from the first desiccant. A condenser condenses the desorbed refrigerant gas into a liquid phase. The condensed refrigerant evaporates from a liquid phase to a gaseous phase to cool the component. A second desiccant can be used, wherein the processor is configured to operate the cooling system in a first mode of operation in which the first desiccant is in thermal communication with the component and the second desiccant is thermally isolated from the component and a second mode of operation in which the second desiccant is in thermal communication with the component and the first desiccant is thermally isolated from the component.

Abstract: Methods and systems for improving recovery from a subsurface hydrocarbon reservoir are described. A method includes drilling a horizontal well in a zone proximate to a contiguous section of cap rock over a reservoir interval. A refrigerant is flowed through the horizontal well to freeze water in the zone, forming a freeze wall in contact with the contiguous section of cap rock. A chamber is formed above the reservoir interval, wherein the chamber includes the contiguous section of cap rock and at least one freeze wall.

Abstract: A stimulation method involves arranging a fluid-activated gun in a well through a well head and/or a blowout preventer, dividing the well into a first and a second part, the first part being closer to the well head and/or blowout preventer than the second part, pressurizing the first part of the well with a hot fluid, the hot fluid having a temperature which is higher than the temperature of the formation at a downhole point of injection, activating the fluid-activated gun, thereby converting energy from the pressurized hot fluid into mechanical waves, directing said mechanical waves into the formation, and injecting the hot fluid into the formation simultaneous to activation of the fluid-activated gun via the hot fluid.

Abstract: A recovery method for recovering mineral resources from a hydrothermal fluid reservoir present beneath the ocean floor includes the steps of: (A) providing a hydrothermal fluid well by drilling a hole reaching a hydrothermal fluid reservoir from an ocean floor surface via a guide base on the ocean floor surface, and then installing a casing in the drilled hole via the guide base; (B) precipitating minerals on a mineral-culturing device by installing the mineral-culturing device on the base guide so as to cover a well head of the hydrothermal fluid well, and bringing hot water ejecting from the well head into contact with sea water on the mineral-culturing device; and (C) recovering minerals precipitated on the mineral-culturing device together with the mineral-culturing device.

Abstract: A basket is attached below a retrievable bridge plug used during the pressure testing of a well to verify integrity prior to fracturing operations. After the pressure integrity test above the plug, the plug is released and retrieved and a series of balls of increasing diameter are dropped on increasingly larger ball seats to allow shifting sleeves to an open position from the heel of the well toward the surface to sequentially frac in that direction. If any segments of the sealing element break off they are captured and removed in the basket that has flow through opening small enough to retain the debris and allow flow through the basket during removal. The basket is slotted for through fluid flow and can have a breakaway for the support rod if the basket sticks when the plug is removed.