Abstract: A method and related apparatus for forming a wellbore in a subterranean formation includes forming a drill string that has a drill bit at a distal end, a drilling motor configured to rotate the drill bit with a drive shaft; a joint coupled to the drive shaft; and an actuator assembly displacing the drive shaft between a first and a second deflection angle, the drive shaft being movable at each of the deflection angles until a predetermined weight is applied to the bit. The method also includes conveying the drill bit through the wellbore and fixing the drive shaft in at least one of the first and the second deflection angles by applying a predetermined weight on the bit.

Abstract: A downhole component including a first portion; a second portion; a controlled failure structure between the first portion and second portion. A method for improving efficiency in downhole components.

Abstract: A reamer for enlarging an underground borehole comprises a plurality of cutter assemblies distributed azimuthally around a longitudinal axis of the tool. Each cutter assembly comprises a supporting structure and a plurality of hard faced cutters secured therein with a hard surface of each cutter exposed and facing in a direction of rotation of the tool and extending radially outwards from the tool axis to a radially outward extremity. These cutters are arranged in a sequence extending axially along the tool. In contrast with convention a1 cutter assemblies, the supporting structure comprises at least one radially outward-facing surface which is positioned to follow behind the leading face of at least one cutter as the tool rotates and which is aligned with the radially outer extremity of the cutter at the same radial distance from the tool axis. Thus the surface area available to contact the borehole wall and stabilise the positioning and motion of the rotating reamer is enhanced.

Abstract: A rotary cutting tool, which may be a reamer for enlarging an underground borehole or a mill to remove tubing by cutting into the inside wall of the tubing, has a plurality of cutter assemblies distributed azimuthally around a longitudinal axis of the tool, wherein each cutter assembly includes a supporting structure bearing a sequence of cutters which extends axially along the tool with leading surfaces facing in a direction of rotation of the tool. The cutters of each sequence are positioned at a plurality of circumferential positions such that no more than three cutters of the sequence are aligned on any line parallel to the longitudinal axis of the tool. In an overlapping arrangement, a plurality of cutters in the sequence may have a leading face circumferentially behind the leading face but ahead of the trailing end of at least one other cutter.

Abstract: A reamer for enlarging an underground borehole comprises a plurality of cutter assemblies distributed azimuthally around a longitudinal axis of the tool, and each cutter assembly comprises a supporting structure and a plurality of hard faced cutters (211-216) embedded therein with a hard face of each cutter exposed and facing in a direction of rotation of the tool. Each cutter assembly includes at least one outward-facing gauge surface (220), at a radial distance from the tool axis which aligns the gauge surface with the radially outer extremity (218) of at least one cutter. This gauge surface (220) extends (221) in the direction of rotation circumferentially ahead of the extremity of the exposed face of the aligned at least one cutter. It may meet the side of the assembly at a curved (222) or bevelled (342) edge and may also extend back from the exposed face of the cutter.

Abstract: A reaming tool for enlarging an underground borehole has a plurality of cutter assemblies distributed azimuthally around a longitudinal axis of the tool. First, second and possibly more cutter assemblies each have an axially extending length comprising supporting structure bearing a sequence of cutters which have hard surfaces facing in a direction of rotation of the tool and are distributed axially along the length. A plurality of the cutters on the second cutter assembly are at axial positions relative to the tool which are intermediate between axial positions of the cutters on the first cutter assembly. Cutters on further assemblies may also be at intermediate axial positions. Cutters in the overall plurality of sequences are positioned at radial distances from the tool axis which increase as axial distance from an end of the tool increases.

Abstract: Earth boring tools with a plurality of fixed cutters have side rake or lateral rakes configured for improving chip removal and evacuation, drilling efficiency, and/or depth of cut management as compared with conventional arrangements

Abstract: A drill string with a bit at one end is used to dig an underground borehole. When the drill string exits the borehole at a surface exit point, a pullback adapter is used to interconnect the bit with an above-ground utility line. A drilling rig retracts the drill string from the borehole. As the drill string is pulled back through the borehole, the trailing utility line follows along its underground path. As the utility line is pulled through the borehole, the connector biases the utility line to the center of the borehole. Such biasing reduces the risk of ensnaring of the connector and utility line by the borehole walls during the pulling process.

Abstract: In embodiments, a drilling rig system includes a rig unit having rig equipment and a rig electrical subsystem configured for electrical communication with the rig equipment and including a rig electrical subsystem input transformer, an electrical system including a primary power supply subsystem remote from the rig unit, and an intermediate electrical subsystem.

Abstract: An electrical interconnect system which allows electrical service to be provided to an ESP suspended on coiled tubing without exiting the wellhead at the top of the well head structure, with three aligned plugs into which is inserted an exterior plug providing each leg of the electrical service to the ESP within the well.

Abstract: This application describes a snubbing frame unit having a pair of telescoping hydraulic cylinders for moving a jack head towards and away from the snubbing base slips to snub a pipe through the snubbing unit. The hydraulic cylinders are parallel dual-acting three stage hydraulic cylinder rods and are spaced from an opening designed to be above a wellbore. In an embodiment, each cylinder has two bidirectional ports for quickly moving hydraulic fluid into and out of the cylinders. The telescoping three stage cylinders allows the snubbing frame to handle heavier pipe and higher pressures while facilitating quicker insertion with lighter pipes and lower pressure. The compact design allows the equipment to be easily transportable while providing sufficient space for equipment connected to the wellbore including blow out preventers. An attachable gin lift device allows pipe handling and insertion of pipe without the need for a mast assembly.

Abstract: A rod and rod cup alignment apparatus for a drilling machine has a receptacle for receiving a drill rod of the type having at least one rod flat, where the drill rod has a leading corner and a trailing corner relative to the direction of its rotation. The receptacle has at least one cup flat disposed on the inner surface of the receptacle and the cup flat further has a first top surface and a second top surface. The second top surface has a slope downward toward the bottom of the rod cup, so that, as the drill rod is lowered into the rod cup while the drill rod is rotating, the leading corner of the drill rod is caused to move downward along the second top surface, whereupon the trailing corner of the drill rod contacts the first top surface, thereby aligning the drill rod flat with the rod cup flat.

Abstract: A modular carousel for holding a drill pipe segment in a drilling rig includes a central support having a top end and a bottom end, and a top plate removably coupled to the top end of the central support, the top plate including a top plate slot sized to receive an upper end portion of the drill pipe segment. A breaker plate has a breaker plate slot sized to receive an intermediate portion of the drill pipe segment, and a coupler assembly is configured to removably attach the breaker plate to the bottom end of the central support. A base plate is coupled to the breaker plate by an extension support, the base plate including a cup sized to receive a bottom end portion of the drill pipe segment.

Abstract: A top drive unit including a top drive housing, a drive stem disposed in the top drive housing, a carrier configured to axially move the drive stem relative to the top drive housing, and a drive mechanism for rotating the drive stem.

Abstract: The invention relates to a method for operating a tongs system (10) designed for assembling a drill string element (12) and an often stationary drill string element (12) or for separating a drill string element (12) from another drill string element (12), said tongs system having lower tongs and upper tongs that can be moved relative to the lower tongs by means of a drive unit (18). A displacement-measuring system (44) detects a position (46) of the upper tongs relative to the lower tongs. A control unit (48) compares an application torque determined as a function of the detected position (46) with a defined or definable desired application torque (54). The assembly of the two drill string elements (12) is terminated when the determined application torque reaches or exceeds the desired application torque (54). The invention also relates to a tongs system (I 0) operating according to said method.

Abstract: A first property, derivable from mass, of a drilling fluid is measured at a point upstream of a cuttings removal device. A second property (also derivable from mass) is measured at a point downstream of the cuttings removal device. A difference between the properties is determined over a period of time to obtain an estimate of the rate of cuttings removal. This allows the property of the drilling fluid before and after cuttings removal to be compared to give an indication of the rate of cuttings removal, which is indicative of the borehole cleaning.

Abstract: In accordance with presently disclosed embodiments, systems and methods for selectively engaging, raising or lowering, and disengaging downhole equipment via a reduced friction J-latch mechanism is provided. The disclosed J-latch mechanism generally includes a J-latch receptacle including a cylinder having a slot formed therein, the slot having an open end exposed at one end of the cylinder and a truncated slot area at an opposite end of the slot from the open end. The J-latch mechanism also includes a J-latch lug member including a mounting portion with a lug disposed thereon for removably interfacing with the slot of the J-latch receptacle. The lug includes a bearing assembly to reduce friction between the slot and the lug while selectively engaging and disengaging the lug member from the receptacle. The disclosed J-latch mechanism may improve the efficiency of deployment, retrieval, and actuation of a wide range of oilfield equipment under heave conditions.

Abstract: The present invention relates to an annular barrier for being expanded in an annulus between a well tubular structure and a wall of a borehole downhole for isolating a first zone from a second zone in the annulus between the well tubular structure and the wall of the borehole, the annulus having an annulus pressure, comprising: a tubular part for being mounted as part of the well tubular structure, the tubular part comprising an opening and an inside having an inside pressure, an expandable metal sleeve surrounding the tubular part and having an inner face facing the tubular part and an outer face facing the wall of the borehole, each end of the expandable metal sleeve being connected with the tubular part, an annular space between the inner face of the expandable metal sleeve and the tubular part, the annular space having a space pressure, and a valve system comprising a first valve and a second valve, the second valve allowing pressurised fluid into the annular space to expand the expandable metal sleeve an

Abstract: An elastically deformable support for an expandable seal element of a downhole tool, an expandable seal assembly incorporating such a seal element and support, and a downhole tool, such as a packer, incorporating the expandable seal assembly are disclosed. The elastically deformable support may be one-piece. The support is deformable between an unexpanded configuration and a radially expanded configuration and includes a plurality of base portions, each base portion having a surface which, in use, faces towards the seal element; and a plurality of overlap portions, each overlap portion extending from a respective base portion so that it overlaps the surface of an adjacent base portion and having a surface which, in use, faces towards the seal element. The base portions and the overlap portions are arranged to define a generally ring-shaped seal support structure which forms a continuous circumferentially extending support surface for abutting and supporting the seal element.

Abstract: A stage tool for wellbore annular cementing may be opened for cementing by hydraulic actuation of a sliding sleeve valve from over a fluid port. After sufficient cement has been introduced, the stage tool fluid port can be closed by compressing two telescopically arranged parts of its tubular body to further overlap each other and overlie the fluid port. This permits the stage tool to be closed without employing a plug.

Abstract: A production assembly comprising a valve, a flow meter and a choke as part of a branch of a production tree.

Abstract: The invention relates to a multistage high pressure fracturing system and tubular hydraulic valve (THV) system for connection to a completion string to enable isolation of a zone of interest within a well. In particular, the system enables access to a downhole formation for fracturing the zone of interest and for hydrocarbon production. The system generally includes an electronic plug counting system, a plug capture system and a valve system wherein dropping a series of plugs down the completion string enables successive capture of individual plugs within individual THVs for subsequent fracturing operations.

Abstract: A tool is provided for use in a variety of ESP and other well control applications. The tool employs a simplified design for ESP and well control applications and has a main valve which may be operated by a plurality of different shifting tools.

Abstract: Switching a downhole tool between a first operation mode, a second operation mode, and a third operation mode, operation modes may include a sleep mode in which the downhole tool consumes less energy, a twilight mode in which the downhole tool consumes more energy than in sleep mode and/or may perform limited functions, and an awake mode in which the downhole tool consumes more energy than in the sleep mode or in the twilight mode and may perform additional tool functions.

Abstract: A system for connecting flow interface equipment to a subsea tree or manifold is disclosed. The system relates to an apparatus adapted to inject fluids into a well having a flow bore. The system includes a connection apparatus adapted to land a conduit on a subsea tree or manifold and to connect the conduit of the connection apparatus to an access port or choke body of the tree or manifold.

Abstract: A subsea production field has a subsea fortified zone that includes equipment designed to contain high pressure. The subsea production field also has a zone rated at lower pressure that includes equipment that is not capable of containing high pressure. A subsea pressure protection system is provided in the subsea fortified zone. The subsea pressure protection system includes a high integrity pressure protection system (HIPPS), and a pipe bundle. By selecting an appropriate length of the pipe bundle, the location of the separation between the subsea fortified zone and the zone rated at lower pressure may be kept fixed at the outlet of the pipe bundle.

Abstract: A directional tendency prediction system or method that provides: determining geometric parameters of a bottomhole assembly having at least a stabilizer, a bit, and an eccentering mechanism that provides a range of eccentricity settings; deriving a side force on the bit across the range of eccentricity settings; and based at least in part on the side force on the bit, determining a walk angle or dogleg severity (DLS) across the range of eccentricity settings. The resulting DLS range may be compared with requirements for a desired borehole trajectory and if suitable, the parameters may be used to configure the bottomhole assembly, and the DLS dependence may be expressed in a tabular or functional form to control steering.

Abstract: A method of designing a downhole drilling tool may include generating a three dimensional (3D) downhole drilling tool model and simulating engagement of the drilling tool model with a 3D model of a borehole bottom. First and second cutting zones of first and second cutting elements may be determined based on areas of the first and second cutting elements that engage the borehole bottom, where the first and second cutting zones respectively have first and second cutting zone shapes. First and second cutting forces for the first and second cutting elements may be calculated based on the respective first and second cutting zone shapes. A drilling efficiency of the drilling tool model may be modeled based at least on the first cutting force and the second cutting force and a design parameter of the drilling tool model may be modified based on the drilling efficiency of the drilling tool model.

Abstract: An apparatus can include a first curved blade for use in a centrifuge. The centrifuge can be for collecting debris particles in a fluid flowing through the centrifuge. The first curved blade can include a plurality of eccentric slots. The first curved blade can include a groove positioned at an outer edge of the curved blade. The first curved blade can also include a first mating element and a second mating element. The first and second mating elements can be for coupling the first curved blade to a second curved blade about a central axis.

Abstract: A subterranean screen assembly comprises a base pipe with end connections to attach to a pipe string and a portion that is perforated or slotted; and a coated screen radially outwardly disposed of the base pipe. The coated screen comprises a screen substrate and a coating disposed on a surface of the screen substrate; the coating comprising an amorphous diamond like carbon doped with about 10 to about 30 atomic percent of silicon, about 10 to about 20 atomic percent of oxygen, or a combination comprising at least one of the foregoing dopants, or a polymer comprising a fluoropolymer, a silicone, or a combination comprising at least one of the foregoing.

Abstract: The present invention provides system, method and apparatus for creating an electric glow discharge that includes a first and second electrically conductive screens having substantially equidistant a gap between them, one or more insulators attached to the electrically conductive screens, and a non-conductive granular material disposed within the gap. The electric glow discharge is created whenever: (a) the first electrically conductive screen is connected to an electrical power source such that it is a cathode, the second electrically conductive screen is connected to the electrical power supply such that it is an anode, and the electrically conductive fluid is introduced into the gap, or (b) both electrically conductive screens are connected to the electrical power supply such they are the cathode, and the electrically conductive fluid is introduced between both electrically conductive screens and an external anode connected to the electrical power supply.

Abstract: A screen assembly, such as a downhole/sand screen assembly, comprising first and second screen portions or screens longitudinally coupled together, wherein there is provided a fluid flow path between the first and second screen portions or screen. Optionally, the first and second sleeves are coupled or connected by a centraliser or further sleeve or screen, and/or optionally by or via first and second support ring.

Abstract: A downhole assembly can include plates in series along a length of a tubular member. Plates can include particulate-blocking areas and pass-through areas. A pass-through area of a plate can be angularly offset from a pass-through area of another plate in the series. The plates may be angled so that particulate carried by fluid from a wellbore may be trapped by particulate-blocking areas that may be tilted away from the fluid source.

Abstract: A box by pin perforating gun system using swaged down gun bodies, a removable cartridge to hold a detonator and switch, and an insulated charge holder as an electrical feed-through.

Abstract: In an aspect, a method of operating a plunger lift system, a controller and a plunger lift system in a well is provided. The velocity of a plunger is measured by a velocity sensor positioned proximate a top of the well when the plunger passes the velocity sensor. The measured velocity can then be used to determine a kinetic energy of the plunger as it passed the velocity sensor. Each time the plunger passes the velocity sensors, the kinetic energy of the plunger can be determined. This determined kinetic energy can then be used to determine if the well should be shut down or if portions of the plunger lift system should be replaced.

Abstract: An automated sucker rod spacing device comprising a housing, a screw set within the housing and connected to a sucker rod string via a polished rod, a nut which is in threaded engagement with the screw, a means to transmit a rotation force to the nut, wherein the rotation of the nut can lower or raise the screw and thus lower or raise the sucker rod string. The device can be used to stop tagging, ensure full pump fillage, and avoid gas lock.

Abstract: A system for providing artificial lift to wellbore fluids having solid buildup removal capabilities includes a pump submerged in wellbore fluids and in fluid communication with a tubular member extending within a wellbore. The pump is oriented to selectively boost a pressure of the wellbore fluids traveling from the wellbore towards an earth's surface. A motor is located within the wellbore providing power to the pump. A seal assembly has a first side connected to the motor and a second side connected to the pump, wherein the pump, the motor and the seal assembly together form a submersible pump string. An ultrasonic device is connected to the submersible pump string and operable to produce pressure waves.

Abstract: A method of producing hydrocarbons from a subterranean reservoir comprises pre-heating by exposure to electromagnetic radiation from a electromagnetic radiation source, injecting through at least one injection well a solvent into the reservoir to dilute the hydrocarbons contained in the pre-conditioned portion, and producing through at least one production well a mixture of hydrocarbons and solvent. An apparatus for producing hydrocarbons from a subterranean reservoir comprises at least one radio frequency antenna configured to transmit radio frequency energy into a subterranean reservoir, a power source to provide power to the at least one radio frequency antenna, at least one injection well configured to inject a solvent from a solvent supply source into the subterranean reservoir to lower the viscosity of the hydrocarbons, and at least one production well configured to produce a mixture comprising hydrocarbons and solvent from the subterranean reservoir.

Abstract: A downhole energy transmission system is described. The system can include a casing string having a number of casing pipe disposed within a wellbore, where the casing string has at least one wall forming a cavity. The system can also include a remote electrical device disposed within the cavity of the casing string at a first location. The system can further include a first stripline cable disposed on an outer surface of the casing string, where the first stripline cable transmits a first energy received from an energy source. The system can also include a second stripline cable disposed adjacent to the first stripline cable at the first location, where the second stripline cable is electrically coupled to the remote electrical device.

Abstract: A system (2) for offshore hydrocarbon processing comprises a host (6) at surface level, a subsea processing plant (4), and an umbilical (8) connecting the host and the subsea processing plant. The subsea processing plant is adapted to receive a multi-phase hydrocarbon stream (10) from a wellhead and to output at least a hydrocarbon gas-phase stream (14) satisfying a rich gas pipeline transportation specification to a pipeline. The umbilical provides a desiccant (12) for drying the hydrocarbon gas, as well as power and control (12), from the host to the subsea processing plant.

Abstract: An abrasive jet drilling system is employed for transmitting information from a downhole location to a surface location. A jet drilling system is provided, with a drill string extending from surface to a downhole location in a borehole. A fluid flow with a mixture of drilling fluid and a quantity of abrasive particles is generated in the drill string. The quantity of abrasive particles in the mixture is modulated in dependence of information obtained regarding a downhole condition, to generate data pulses downhole which are detected at surface. A transmitted downhole condition is determined based on the detected data pulses.

Abstract: Fracture monitoring is provided. In one possible implementation, a smart proppant bead includes electronic functionality, a transmitter, a sensor and a power source. In another possible implementation, a smart proppant bead includes electronic functionality, a transmitter, a receiver, a sensor and a power source. In yet another possible implementation, a smart proppant bead includes a computer-readable tangible medium with instructions directing a processor to receive an activation signal and access identification information associated with the smart proppant bead. Additional instructions direct a transmitter on the smart proppant bead to transmit the identification information associated with the smart proppant bead.

Abstract: The disclosed embodiments include a system, method, or computer-program product configured to performing automated wellbore trajectory control for correcting between an actual wellbore trajectory path and a planned wellbore trajectory path. For example, in one embodiment, a controller is configured to obtain real-time data gathered during the drilling operation, determine whether the actual wellbore trajectory path deviates from the planned wellbore trajectory path, and automatically initiate the wellbore trajectory control to change the actual wellbore trajectory path to a minimum-incremental wellbore energy correction path using provided correction constraints. The correction path may optionally include spline, catenary, circular arc, or clothoid curves.

Abstract: Diversion material is particulate material used during wellbore treatment to temporarily seal a wellbore fluid passage such as a fracture. A method and apparatus for diversion material testing permits simulation of wellbore fracture parameters and testing thereof against a selected diversion material. The apparatus comprises: a fluid piping system including a fluid inlet end and a fluid outlet end; a fracture simulator chamber including a fracture-simulating outlet slot through a wall of the chamber, the fracture simulator chamber being releasably connectable to the fluid outlet end; a pump to pump fluid through the fluid piping system from the fluid inlet line to the fluid outlet end and into the fracture simulator chamber; a diversion material launch system connected in communication with the fluid piping system between the fluid inlet end and the fluid outlet line; and a pressure transducer in the fluid piping system to measure pressure in the fluid piping system.

Abstract: A magnetic marking method includes drilling a borehole and marking a position along an uncased section of the borehole with a magnetic marker comprising a magnetic rare earth alloy. A magnetic marker for open hole use includes an unconsolidated mass of high remanence, magnetized material that comprises a magnetic rare earth alloy. The magnetic marker for open hole use also includes a suspension fluid suited for conveying the magnetized material through a drill string bore into an open borehole. A magnetic marker for a casing terminus includes a magnet comprising a magnetic rare earth alloy and an attachment mechanism that secures the magnet to a casing shoe. Such magnetic markers for open hole use or a casing terminus can be used for borehole intersection operations.

Abstract: In some embodiments, an apparatus and a system, as well as a method and an article, may operate to receive a derived clock signal downhole, the derived clock signal being derived from a surface clock signal (associated with a surface clock), such that the frequency of the derived clock signal is less than the frequency of the surface clock signal. Further activity may include measuring the frequency of the derived clock signal in terms of an uncorrected downhole clock frequency (associated with a downhole clock) to provide a measured frequency equivalent, and correcting time measurements made using the downhole clock, based on the measured frequency equivalent, or based on an actual frequency of the downhole clock determined according to the measured frequency equivalent. Additional apparatus, systems, and methods are described.

Abstract: An echo communication system has a plurality of triggers disposed within a first distance of each other and a hub separated from the plurality of triggers by at least a second distance that is greater than the first distance. The hub is configured to wirelessly transmit a signal intended for one of the triggers and each of the triggers will re-broadcast the same signal if they are not the intended recipient.

Abstract: A telemetry method transmits data by MP telemetry to a telemetry relay system which retransmits the data by EM telemetry. The method avoids the need to incorporate MP telemetry pressure transducers into rig equipment and permits telemetry from regions unfavourable for EM telemetry because of depth and/or characteristics surrounding formations.

Abstract: Data is communicated from sensors at a downhole location near a drill bit to surface equipment. Communication to the surface equipment may be direct or may pass through a series of nodes. The nodes in some cases are intelligently reconfigured to achieve desired data rates, achieve power management goals, and/or compensate for failed nodes.

Abstract: A telemetry system with a plurality of controllers and telemetry systems, where the controllers are configured to obtain information from one or more sensors and transmit that information on one or more of the plurality of telemetry systems. The configuration of a controller may be changed so as to change which information is transmitted on a given telemetry system.