12732results about "Drilling rods" patented technology

A surgical instrument having a locking mechanism for preventing an output shaft of the surgical instrument from rotating and a further locking mechanism for mounting a battery pack to a distal end of a housing of the surgical instrument. The surgical instrument further includes a clutch mechanism for limiting the torque of a drive shaft of the surgical instrument. The locking mechanism for preventing the output shaft from rotating includes a locking switch which mates with a locking cap disposed on the output shaft. The locking mechanism for mounting the battery pack to the housing includes a groove at the distal end of the housing and a retaining ring which engages the groove when the battery pack is mounted on the housing. The clutch mechanism includes a clutch plate that interfaces with both the output shaft and the drive shaft and prevents failure of the motor shaft.

A portable pneumatic fastening tool has an onboard compressor assembly to alleviate the need for an external air compressor. The onboard compressor assembly includes a motor and a compressor mounted to the tool body. The motor can be powered by a detachable battery mounted to a cover for covering the onboard compressor assembly. A portable pneumatic fastening tool may also be powered by a portable compressor assembly which can be borne by the user.

The invention relates to a hand tool for use with attachments. The hand tools of the invention may be used with attachments with various speed and torque requirements. Preferred hand tools comprise a body with a brushless DC motor and means. which control the energisation of the motor. In use the brushless DC motor of the preferred hand tool is electrically supplied to drive a power output means connected to said motor. Another preferred hand tool comprises a body with a motor contained therein, a void space between an internal surface of the body and at least a part of the motor, a fluid inlet port provided and a fluid outlet port provided in or on the body, and ducting means which provides a channel for fluid supplied via the fluid inlet port to and from the void space and then on to the fluid outlet port.

A nut includes an internal thread and at least two parts, each of the parts having a section of the internal thread which can be pushed onto an external thread in the radial direction. The parts may have connecting elements which interact and permit a relative displacement of the parts in a direction running radially to the axis of the internal thread into a position of use. The connecting elements may have guide surfaces which are inclined at an angle to the plane running radially to the axis of the internal thread and guide the parts in a rotational movement about an axis of rotation running transversely to the axis. A part may have a locking arm with a guide surface only on one side which produces the rotational movement during the displacement of the parts and bears against a complementary guide surface of the other part.

A power tool includes a body housing a motor with a first output shaft and an attachment for engagement with the output shaft. The attachment includes an output shaft which transmits rotational motion derived from the rotational motion of the motor and further includes a gear mechanism enabling a gear change in rotational speed between its input and output. A combination of the body and the attachment thereby provides a plurality of serially-coupled gear mechanisms.

Methods and apparatus are provided for obtaining a secure mechanical connection and a pressure-tight seal in the overlapping area of two telescoping tubular bodies. The two bodies, including the overlapping area, are radially expanded to increase the inside diameter of the bodies. The expansion forces an annular seal in the overlapping area into a pressure-sealing engagement between the bodies. A string of pipe assembled from joints secured to each other by telescoping, threadedly engaged expanded pin and box connections may be radially expanded into a surrounding well bore to provide a cased well having an internal diameter greater than the original internal diameter of the pipe string. The seal in the connection comprises an annular elastomeric seal ring and an annular Teflon spacer ring carried in a specially dimensioned groove formed in either the box or the pin, or both members of the connection. Radial expansion of the connection causes axial contraction of the groove, which acts with the spacer ring to expand the seal ring radially to seal the annular space created between the expanded pin and box.

In one embodiment, a method for drilling a wellbore includes an act of drilling the wellbore by injecting drilling fluid through a tubular string disposed in the wellbore, the tubular string comprising a drill bit disposed on a bottom thereof. The drilling fluid exits the drill bit and carries cuttings from the drill bit. The drilling fluid and cuttings (returns) flow to a surface of the wellbore via an annulus defined by an outer surface of the tubular string and an inner surface of the wellbore. The method further includes an act performed while drilling the wellbore of measuring a first annulus pressure (FAP) using a pressure sensor attached to a casing string hung from a wellhead of the wellbore. The method further includes an act performed while drilling the wellbore of controlling a second annulus pressure (SAP) exerted on a formation exposed to the annulus.

The invention relates to an electrical appliance, in particular a hand-held power tool, having an appliance housing, a circuitry substrate that is situated in the appliance housing and equipped with components, and sealing elements for preventing the influx of dirt into the region of the circuitry substrate. According to the invention, the sealing elements seal a subregion of the circuitry substrate off from other regions inside the appliance housing.

In one aspect of the invention, a downhole tool string component comprises a tubular body with at least one end adapted for threaded connection to an adjacent tool string component. The end comprises at least one shoulder adapted to abut an adjacent shoulder of an adjacent end of the adjacent tool string component. An annular magnetic coupler is disposed within an annular recess formed in the at least one shoulder, and the magnetic coupler comprises a coil in electrical communication with an electrical conductor that is in electrical communication with an electronic device secured to the tubular body. The coil comprises a plurality of windings of wire strands that are electrically isolated from one another and which are disposed in an annular trough of magnetic material secured within the annular recess.

A deformable member can be used in a well tool for use in downhole oil/gas wells. In one embodiment, a deformable member (46) is described which is deformable between undeformed and deformed positions, and comprises a generally hollow cylindrical body (48) defining a wall (50). The wall (50) includes three circumferential lines of weakness in the form of grooves, with two grooves (52, 54) provided in an outer surface (56) of the member wall (50), and the other groove (58) provided in an inner surface (60). The member (46) is deformed outwardly by folding about the lines of weakness (52, 54, 56) and is used in particular to obtain sealing contact with a tube in which the member (46) is located.

A technique for providing auxiliary conduits in multi-trip completions is disclosed. The technique has particular applicability to liner mounted screens which are to be gravel packed. In the preferred embodiment, a protective shroud is run with the gravel pack screens with the auxiliary conduits disposed in between. The auxiliary conduits terminate in a quick connection at a liner top packer. The gravel packing equipment can optionally be secured in a flow relationship to the auxiliary conduits so as to control the gravel packing operation. Subsequent to the removal of the specialized equipment, the production tubing can be run with an auxiliary conduit or conduits for connection down hole to the auxiliary conduits coming from the liner top packer for a sealing connection. Thereafter, during production various data on the well can be obtained in real time despite the multiple trips necessary to accomplish completion. The various completion and/or production activities can also be accomplished using the auxiliary conduits such as actuation of down hole flow control devices, chemical injection, pressure measurement, distributed temperature sensing through fiber optics, as well as other down hole parameters.

A measurement and communication system for use with a tubular string, comprises a tubular string having a plurality of self-powered, autonomous telemetry stations disposed at predetermined locations along the tubular string. Each autonomous telemetry station is adapted to receive at least one first signal and transmit at least one second signal related to the at least one first signal. Power is extracted from potential energy sources proximate each autonomous telemetry station. A method of communicating information along a tubular string comprises, disposing an autonomous telemetry station at predetermined locations along the tubular string. A preferred transmission path is autonomously determined at each of the autonomous telemetry stations. Information is transmitted along the tubular string according to the autonomously determined preferred path.

A release mechanism for use with setting wellbore isolation tools, such as packers or bridge plugs. The release mechanism typically includes a release piston which selectively isolates equalization ports extending from the interior to the exterior of a setting tool body. The release piston may be activated to allow equalization of pressure across the sealing elements of a set isolation tool, typically by applying pressure to the annular space above the isolation tool. The release mechanism may be used to allow a tool body (such as a setting or retrieving tool) to be removed from a set isolation tool under conditions in which high pressure differential exists across the isolation tool.

A stress cone for reducing electrical stresses is disclosed for use on terminated ends of tubing encapsulated power cable used in surface applications in a subsurface well power system employing electric submersible pumps (ESPs). The stress cone comprises an annular section about a longitudinal axis for receiving a terminated end of the TEPC in its first end and for abutting the terminated metal TEPC end against a metal shoulder at its second end therein, and an insulation chamber axially aligned with and connected to the annular section. The chamber comprises a metal interior surface symmetrical about the axis. The insulated TEPC core (without outer metal sheath) passes through the insulation chamber along the axis and then exits. The ID of the TEPC metal sheath and the inside metal surface of the chamber form a smooth ground plane transition surface. Insulation material surrounds the TEPC insulation layer within the insulation chamber.

PCT No. PCT/JP95/02034 Sec. 371 Date May 23, 1997 Sec. 102(e) Date May 23, 1997 PCT Filed Oct. 4, 1995 PCT Pub. No. WO96/10710 PCT Pub. Date Apr. 11, 1996An object of the present invention is to provide galling resistance to a threaded joint used for an oil well pipe. On a thread portion and a metallic sealing portion of the joint, there is provided a manganese phosphate chemical formation coating layer, or alternatively there are provided a nitriding layer of 1 to 20 mu m thickness and a manganese phosphate chemical formation coating layer of 5 to 30 mu m thickness, and also there is coated a solid lubricant which contains powder of molybdenum disulfide or tungsten disulfide and also contains one of epoxy resin, furan resin and polyamide resin as an essential component, and a ratio of composition is maintained at a specific value, so that a solid lubricant coating layer of 10 to 45 mu m thickness can be formed by heating. Due to the above surface treatment, even when the frequency of repetition of fastening and unfastening of the joint is increased, the occurrence of galling can be prevented over a long period of time.

The present invention contemplates a choke control system that provides for local and off-site monitoring and control of the annulus flow pressure of a well. The choke control system includes a choke manifold connected to at least one choke and its associated actuator; a variety of instrumental drilling sensors, pump stroke counter switches, and choke position indicators; a local choke and hydraulic pressure control console; and a programmable controller in communication with the local choke and hydraulic pressure control console. The programmable controller handles the logical operations of the choke control system, including processing instrument measurements and operator input data to produce control signals for operating the choke, the choke actuator and the various valves associated with the choke manifold. The programmable controller is typically either an electronic digital computer and/or a programmable logic controller (PLC). The present invention further contemplates the two-way communication between the choke control system and the Internet via a satellite linkage.

A disposable downhole tool comprises a material that dissolves when exposed to a chemical solution, an ultraviolet light, a nuclear source, or a combination thereof. In an embodiment, the material comprises an epoxy resin, a fiberglass, or a combination thereof. In another embodiment, the material comprises a fiberglass and a binding agent. The material may also be customized to achieve a desired dissolution rate of the tool. In an embodiment, the disposable downhole tool further comprises an enclosure for storing the chemical solution. The tool may also comprise an activation mechanism for releasing the chemical solution from the enclosure. In an embodiment, the disposable downhole tool is a frac plug. In another embodiment, the tool is a bridge plug. In yet another embodiment, the tool is a packer.

A first flux-loop inductive coupler element electrically couples with a second flux-loop inductive coupler element. The first flux-loop inductive coupler element comprises a first ring-like core having high magnetic permeability and a conical-section annular first face transverse to the plane of the first core. The first face has a first annular groove separating a first conical-section larger-diameter face and a first conical-section smaller-diameter face. A first coil is wound within the annular groove. The first and second cores form a low-reluctance closed magnetic path around the first coil and a second coil of the second flux-loop inductive coupler element.

A first current-loop inductive coupler element electrically couples with a second current-loop inductive coupler element. The first current-loop inductive coupler element has a first high-conductivity, low-permeability shaped belt of a first end of a first pipe joint, a first ring-like core located at the first end, and a first electrically conductive coil wound about the first ring-like core. The first high-conductivity, low-permeability shaped belt partially encloses the first coil. It is shaped to cooperate with the second high-conductivity, low-permeability shaped belt of an adjacent second pipe joint having a second electrically conductive coil and a second high-conductivity, low-permeability shaped belt to create a closed toroidal electrical conducting path. The closed toroidal electrical conducting path encloses the first coil and the second coil when the first and second pipe joints are mated.

A method and apparatus for creating multiple branch wells from a parent well is disclosed. According to a first embodiment of the invention a multiple branching sub is provided for placement at a branching node of a well. Such sub includes a branching chamber and a plurality of branching outlet members. The outlet members, during construction of the branching sub, have previously been distorted into oblong shapes so that all of the branching outlet members fit within an imaginary cylinder which is coaxial with and substantially the same radius as the branching chamber. According to one embodiment, the distorted outlet members are characterized by an outer convex shape. In another embodiment, the distorted outlet members are characterized by an outer concave shape when in a retracted state. After deployment of the branching sub via a parent casing in the well, a forming tool is lowered to the interior of the sub. The outlet members are extended outwardly by the forming tool and simultaneously formed into substantially round tubes. Next, each outlet member is plugged with cement, after which each branch well is drilled through a respective outlet member. If desired, each branch may be lined with casing and sealed to a branching outlet by means of a casing hanger. A manifold placed in the branching chamber controls the production of each branch well to the parent well. According to a second embodiment of the invention, a pressure resistant branching sub is provided which may be installed in series with a casing string, and the associated equipment used for the installation operation and intervention of a well. The branching sub includes a main pipe and a lateral outlet.

A self-balanced adjustable mounting system for a flat panel display. A display interface having a hollow, semi-spherical shell portion is attached to the flat panel display. The semi-spherical shell is formed with a generally constant radius of curvature. The center of the radius of curvature is disposed proximate the center of gravity of the flat panel display with the display interface attached. The display interface is received in a guide structure that has a bearing portion engaging the outer surface of the semi-spherical shell, and a second bearing portion engaging the inner surface of the semi-spherical shell through an aperture formed in the semi-spherical shell. The semi-spherical shell is guided between the first and second bearing portions so that the flat panel display and device interface are generally rotatable about the center of the radius of curvature of the semi-spherical shell. The display is self balancing in virtually any position in the range of travel of the device due to the location of the center of rotation proximate the center of gravity.

The present invention provides a method and apparatus for handling tubulars and drilling with tubulars such as casing into a formation. In one aspect of the invention, the apparatus comprises a circulating head and a cementing head operatively connectible to a gripping member. The circulating head is used to circulate drilling fluid while drilling with casing, and the cementing head is used to cement the casing string within the formation at a desired depth. The present invention also relates to methods and apparatus for isolating a tensile load from a drilling apparatus rotated by a top drive. In one aspect, the present invention provides a load isolator apparatus having an isolator body operatively connected to the top drive and a torque body at least partially disposed in the isolator body. In operation, the bearing assembly transfers the tensile load from the torque body to the isolator body.

A well screen having an internal alternate flowpath for delivering gravel slurry to different levels within a well annulus and a method for assembling same. The screen is comprised of an outer pipe which is concentrically positioned over a base pipe so that an annulus is formed therebetween. Both pipes are perforated along their respective lengths but only part way around their respective circumferences. The respective perforated sections radially align with each other when the pipes are assembled. A plurality of longitudinal ribs isolate the annulus adjacent the perforated sections (i.e. production side of screen) from the annulus adjacent the non-perforated sections (i.e. alternate flowpath side of screen). At least one outlet is provided through the non-perforated section of the outer pipe to provide an outlet from the internal alternate flowpath.

An apparatus for use downhole is disclosed that, in one configuration includes a downhole tool configured to operate in an active position and an inactive position and an actuation device, which may include a control unit. The apparatus includes a telemetry unit that sends a first pattern recognition signal to the control unit to move the tool into the active position and a second pattern recognition signal to move the tool into the inactive position. The apparatus may be used for drilling a subterranean formation and include a tubular body and one or more extendable features, each positionally coupled to a track of the tubular body, and a drilling fluid flow path extending through a bore of the tubular body for conducting drilling fluid therethrough. A push sleeve is disposed within the tubular body and coupled to the one or more features. A valve assembly is disposed within the tubular body and configured to control the flow of the drilling fluid into an annular chamber in communication with the push sleeve; the valve assembly comprising a mechanically operated valve and/or an electronically operated valve. Other embodiments, including methods of operation, are provided.

The present invention relates to apparatus and methods for remotely actuating a downhole tool. In one aspect, the present invention provides an apparatus for activating a downhole tool in a wellbore, the downhole tool having an actuated and unactuated positions. The apparatus includes an actuator for operating the downhole tool between the actuated and unactuated positions; a controller for activating the actuator; and a sensor for detecting a condition in the wellbore, wherein the detected condition is transmitted to the controller, thereby causing the actuator to operate the downhole tool. In one embodiment, conditions in the wellbore are generated at the surface, which is later detected downhole. These conditions include changes in pressure, temperature, vibration, or flow rate. In another embodiment, a fiber optic signal may be transmitted downhole to the sensor. In another embodiment still, a radio frequency tag is dropped into the wellbore for detection by the sensor.

A gas-lift petroleum well and method for producing petroleum products using downhole pressurized gas to provide lift. The gas-lift well having a well casing, a production tubing, a packer, and a gas-lift valve. The well casing extends within a wellbore of the well, and the wellbore extends through oil and gas zones. The production tubing extends within the casing. The tubing having an opening formed therein, which is in fluid communication with an oil zone. The packer is located downhole in the casing and coupled to the tubing. The packer can have an electrically controllable packer valve, which is adapted to control a flow of downhole pressurized gas from one side of the packer to another. The downhole pressurized gas is provided by a gas zone that the wellbore passes through. The downhole gas-lift valve is coupled to the tubing and is adapted to control a flow of downhole pressurized gas into oil in the tubing for lifting the oil. The gas-lift valve can be an electrically controllable valve. The tubing and casing are used as electrical conductors for supplying power and/or communications downhole. The current in the tubing is routed using a ferromagnetic induction choke to create a voltage potential, which provides electrical power to downhole electrical devices. Also, there may be a bypass passageway to route downhole gas to gas-lift valves. There may also be downhole sensors to measure physical quantities (e.g., pressure). Such measurements can be used for feedback control of downhole electrically controllable valves.

A system for continuously circulating fluid to and through a tubular string either of coiled tubing or made up of a plurality of tubulars connected end-to-end while an upper tubular is added to or removed from a top tubular of the plurality of tubulars, all tubulars having a top-to-bottom fluid flow channel therethrough, the system having an upper chamber with a bottom opening, a top opening, and an upper sealing apparatus for sealingly encompassing a portion of the upper tubular, a lower chamber with a bottom opening, a top opening and a lower sealing apparatus for sealingly encompassing a portion of the top tubular, one of the upper chamber and the lower chamber sized for accommodating connection and disconnection therein of the upper tubular and the top tubular, and gate apparatus between and in fluid communication with the upper chamber and the lower chamber. Such a system may have apparatus for isolating a tubular therein from an axial load imposed by fluid pressure in a chamber; at least one of the lower chamber and the upper chamber with inner bushing apparatus with a portion thereof movably disposable within the chamber's sealing apparatus for facilitating movement of a tubular with respect to the chamber's sealing apparatus, and the system connectible to and rotatable by a rotating system for rotating the tubular string; and/or heave compensation interconnections for interconnecting the system to an offshore rig's heave compensation system. The system in certain aspects including fluid flow lines to each of the top and bottom chambers, a supply of fluid for circulating through the tubular string and through the upper and lower chambers, apparatus for continuously moving circulating fluid from the supply through the system into the tubular string.

An expandable reamer apparatus and methods for reaming a borehole, wherein a laterally movable blade carried by a tubular body may be selectively positioned at an inward position and an expanded position. The laterally movable blade, held inwardly by blade-biasing elements, may be forced outwardly by drilling fluid selectively allowed to communicate therewith by way of an actuation sleeve disposed within the tubular body. Alternatively, a separation element may transmit force or pressure from the drilling fluid to the movable blade. Further, a chamber in communication with the movable blade may be pressurized by way of a downhole turbine or pump. A ridged seal wiper, compensator, movable bearing pad, fixed bearing pad preceding the movable blade, or an adjustable spacer element to alter expanded blade position may be included within the expandable reamer. In addition, a drilling fluid pressure response indicating an operational characteristic of the expandable reamer may be generated.

A Drill-To-The-Limit (DTTL) drilling method variant to Managed Pressure Drilling (MPD) applies constant surface backpressure, whether the mud is circulating (choke valve open) or not (choke valve closed). Because of the constant application of surface backpressure, the DTTL method can use lighter mud weight that still has the cutting carrying ability to keep the borehole clean. The DTTL method identifies the weakest component of the pressure containment system, such as the fracture pressure of the formation or the casing shoe leak off test (LOT). With a higher pressure rated RCD, such as 5,000 psi (34,474 kPa) dynamic or working pressure and 10,000 psi (68,948 kPa) static pressure, the limitation will generally be the fracture pressure of the formation or the LOT. In the DTTL method, since surface backpressure is constantly applied, the pore pressure limitation of the conventional drilling window can be disregarded in developing the fluid and drilling programs. Using the DTTL method a deeper wellbore can be drilled with larger resulting end tubulars, such as casings and production liners, than had been capable with conventional MPD applications.

An arrangement for restricting the inflow of formation water from an underground formation to a hydrocarbon producing well, where, between the underground formation and a production tubing (38) located in the well, there is disposed at least one flow chamber (3, 33) connected to the production tubing (38), the flow chamber (3, 33), preferably via a filter (2) in one portion, being open to inflow of formation fluid and in communication with the production tubing (38) via at least one opening (7, 32), and where the flow chamber (3, 33) is provided with at least one free-floating body (4, 34) with approximately the same density as the formation water, the at least one body (4, 34) being designed by means of the closing of at least one opening (32) or choking, to reduce the inflow of formation water to the production tubing (38).

A cabled communication link for a drill string includes spaced apart adapter subs within the drill string and a cable connecting the adapter subs for communication of a signal therebetween. The cabled communication link may be drill pipe joints are interconnected within the drill string between adapter subs to form a piped communication link, whereby the cabled communication link establishes a pathway to the piped communication link for transmitting a signal through the drill string. The cabled communication link may also be in a non-wired section of the drill string is disposed between adapter subs, whereby the cabled communication link establishes a pathway for transmitting a signal through the non-wired section of the drill string. Inductive couplings are preferably used for communication across the adapter subs and wired drill pipe joints. Another aspect of the cabled communication employs wireless transceivers at or near the surface of the wellbore.