Abstract: The present invention generally relates to a method and apparatus for protecting tubular connections. In one aspect, an expandable tubular connection for use in a wellbore is provided. The tubular connection includes a tubular pin member. The tubular connection also includes a tubular box member having an end portion, wherein the tubular pin member is matable with the tubular box member to form the tubular connection. Additionally, the tubular connection includes a sleeve member disposed on the tubular pin member, wherein the sleeve member is configured to substantially protect the end portion of the tubular box member as the tubular connection is lowered into the wellbore. In yet a further aspect, a method for utilizing a tubular connection in a wellbore is provided.

Abstract: A roller cone bit is provided that includes a companion ring positioned exterior to a seal, wherein the companion ring includes a textured surface where the inner diameter of the companion ring contacts the bearing pin.

Abstract: A torque head for gripping tubular members, in at least some aspects, has a housing, grip mechanism secured within the housing, the grip mechanism for selectively gripping a tubular member, the grip mechanism including at least one jaw selectively movable toward and away from a portion of a tubular member within the housing, the at least one jaw having mounted thereon slip apparatus for engaging the portion of the tubular member, the slip apparatus including die apparatus movably mounted to the at least one jaw, the die apparatus movable with respect to the at least one jaw so that relative movement of the tubular with respect to the torque head is possible to the extent that the die apparatus is movable.

Abstract: A dewatering device is provided that can be inserted concentrically within the production tubing string of a natural gas-producing wellbore. The dewatering device includes a pressure-isolating chamber that is provided with a fluid inlet valve and a fluid outlet valve and associated gas lift valves. Compressed gas and soap are used to form a foamy liquid mixture that is lifted out of the chamber.

Abstract: Electronic time delay apparatuses and methods of use are disclosed. An explosive or propellant system, which may be configured as a well perforating system includes an electronic time delay assembly comprising an input subassembly, an electronic time delay circuit, and an output subassembly. The input subassembly is activated by an external stimulus, wherein an element is displaced to activate an electronic time delay circuit. The electronic time delay circuit comprises a time delay device coupled with a voltage firing circuit. The electronic time delay circuit counts a time delay, and, upon completion, raises a voltage until a threshold firing voltage is exceeded. Upon exceeding the threshold firing voltage, a voltage trigger switch will break down to transfer energy to an electric initiator to initiate an explosive booster within the output subassembly.

Abstract: A kit of parts which is assembled to form downhole apparatus comprises a swellable member, which expands upon contact with at least one predetermined fluid, and a connector. The swellable member has a first mating profile towards a first end and a second mating profile towards a second, opposing end. The connector has a mating profile configured to mate with each of the first and second mating profiles of the swellable member. The connector can therefore be connected to either the first and second ends of the swellable member. The connector may be an end connector, or may connect the swellable member to a second swellable member. In either case, the connector may define an arresting surface against which the swellable member abuts when expanding. The kit of parts can be adapted to and installed on any well tubular, and may form any of a variety of tools.

Abstract: A downhole tool has a mandrel and an expandable packer element for sealingly engaging the well. A slip assembly is positioned on the mandrel and will anchor the downhole tool in the well. The slip assembly may include a slip ring that moves from an unset to a set position. A retaining ring is disposed about the slip ring and will hold the slip ring in the unset position until sufficient force is applied to break the retaining ring. The retaining ring may comprise a retaining band with a dampener to suppress the spring effect experienced by the retaining band when it breaks upon the application of force.

Abstract: A movable arm 10 engages a flexible line 50 at a well site for positioning the flexible line between run-in position for passing the flexible line with a tubular through a well hole in the rig floor and a clamping position wherein the flexible line is adjacent the tubular above the rig floor for clamping the line to the tubular. The arm 10 extends upward from the rig floor 70, and includes a line guide, such as roller 12, for engaging the flexible line when in the run-in position. A powered drive 14 moves the arm between the run-in position and the clamping position. A spacer 82 may be used for positioning two or more flexible lines at a desired spacing relative to one another prior to positioning the lines within a clamp secured to the tubular. A slip bowl assembly 60 may be laterally movable so that slips do not engage the flexible line as it is run in the well.

Abstract: A gas lift production apparatus is provided for use in flushing and snubbing well operation. The apparatus comprises upper production string and lower production string. The upper production string includes at least one side pocket mandrel carrying a gas lift valve, tubular strings connected with every side pocket mandrel, a sliding sleeve installed as part of the production string below side pocket mandrels and a latch seal assembly threaded in the tubular string below the sliding sleeve. The lower production string includes a single bore packer below the latch seal assembly, tubular strings, a landing nipple and a bell mouth at the bottom of the production string. The upper production string are run in and removed as a single unit from the packer which is anchored within the well casing. It is emphasized that this apparatus is provided with three functions such as producing a gas lift well, flushing well and snubbing well operation.

Abstract: A valve (136, 136?, 136?, 200) adapted to replace an existing valve of a wellhead (114). Valve (136, 136?, 136?, 200) can have similar dimensions as the existing valve it replaces to utilize existing wellhead connections. In one embodiment, a replacement bypass master valve (136) incorporates a fluid bypass pathway (168) to enable communication and conveyance of a production enhancing fluid (132) from a location external to the well through small diameter tubing (126) to a specific downhole location independent the position of a flow control member in interior chamber (166). Replacement bypass master valve (136?) can include anchor seal assembly (122?) disposed in locking profile 180 of upstream inlet bore (162) to enable communication from fluid bypass pathway (168) to lower injection conduit (128). In another embodiment, replacement valve (200) includes a groove in gate (208) sealingly receiving capillary injection tubing (204) when in a closed position.

Abstract: A downhole device used to divert fluid flow out of a work string into an annulus. The downhole device is activated by the movement of a plurality of pistons within the downhole device. Fluid flow through a restriction of the downhole device creates an increase in fluid pressure causing the movement of the pistons. The pistons move a flow tube between various locations within the device. In one location, the flow tube prevents fluid flow to the annulus while in another location the flow tube allows fluid flow to be diverted into the annulus. The downhole device may include a locating sleeve having a continuous j-track allowing the flow tube to be selectively retained at the various locations within the downhole device. Fluid flow through the downhole is used to cycle the device between diverting fluid flow to the annulus and forcing fluid flow down the work string.

Abstract: In one aspect of the invention, a downhole tool string component comprises a fluid passageway formed between a first and second end. A valve mechanism is disposed within the fluid passageway adapted to substantially cyclically build-up and release pressure within the fluid passageway such that a pressure build-up results in radial expansion of at least a portion of the fluid passageway and wherein a pressure release results in a contraction of the portion of the fluid passageway. The valve mechanism disposed within the fluid passageway comprises a spring. Expansion and contraction of the portion of the fluid passageway varies a weight loaded to a drill bit disposed at a drilling end of the drill string.

Abstract: A technique distributes localized stress acting on a tubular. The tubular is formed with an inner layer and an outer layer that is compliant relative to the inner layer. A force distribution material is disposed between the inner layer and the outer layer to spread any concentrated loads acting against the tubular. The compliant nature of the outer layer causes it to distort against the force distribution material when acted on by a concentrated external load. The outer compliant layer and the force distribution material cooperate to isolate and protect the inner layer from displacements of the surrounding subterranean material.

Abstract: A drill bit having a bit body intermediate a shank and a working face having at least one cutting insert. A bore is formed in the working face co-axial within an axis of rotation of the drill bit. A jack element is retained within the bore by a retaining element that intrudes a diameter of the bore.

Abstract: Piston bore distortions in a sub-surface safety valve are reduced or eliminated when valve body is subjected to high working pressures. In one embodiment, a piston is disposed in a sleeve that is disposed in a piston bore. The bore can distort but the sleeve within will not distort to the point of losing sealing pressure around the piston. In another approach additional bore or bores are provided adjacent the piston bore to make the pin end of the connection for the valve housing more uniform in the region of the piston bore so that pressure loading does not result in sufficient distortion of the piston bore to lose the piston sealing relation in its bore.

Abstract: A drilling system includes a control unit and a bottomhole assembly (BHA) coupled to a drill string. The control unit uses measurements from sensors distributed throughout the drill string and BHA to determine the physical condition of the drill string and BHA and to determine whether drilling can be optimized. The drill string sensors are housed in receiver subs and optionally can be positioned on extensible members. The receiver sub also can include a short-hop telemetry module, a processor module, and a clock module. In one embodiment, the receiver subs include seismic sensors for enabling vertical seismic profiling. During operation, the processor visually presents to the operator via one or more graphical user interfaces a dynamically updated pictorial image representing the drilling system. The image is annotated with an appropriate visual signal to indicate a determined physical condition at a given location or component.

Abstract: In one aspect of the present invention a drill bit has a jack element with a distal end extending beyond a working face. A porting mechanism within the bore comprises first and second discs contacting along a flat interface. The first disc is attached to a turbine which is adapted to rotate the first disc with respect to the second disc. The discs comprise a first set of ports adapted to align and misalign with each other as the first disc rotates. The first set of ports is adapted to route a drilling fluid to extend the jack element.

Abstract: A reamer for underground boring is provided. The reamer includes at least: (a) a center mandrel, wherein the center mandrel defines a mandrel axis; (b) a plurality of radial members extending radially from the center mandrel; (c) a plurality of cutting heads, wherein each of the cutting heads: (i) is supported by at least one of the radial members; (ii) is arcuately spaced-apart around the center mandrel from the other cutting heads; (iii) has a rounded surface; and (d) a plurality of cutting teeth on the rounded surface of each of the cutting heads. A method of horizontal drilling with the reamer is also provided.

Abstract: Pressure balanced downhole connections. A well system includes a well tool, a conduit assembly connected to the well tool, the conduit assembly including a conduit and a line positioned within the conduit, the line being connected to the well tool for operation of the well tool, and a device for equalizing pressure between an interior and an exterior of the conduit, the device being positioned downhole. A method of isolating a line in a subterranean well from well fluids in the well includes the steps of: connecting a conduit assembly to a device for equalizing pressure between an interior and an exterior of the conduit assembly, the conduit assembly including a line installed within a conduit; and positioning the conduit assembly and pressure equalizing device in the well.

Abstract: In one aspect of the present invention, a drill bit has a jack element that is substantially coaxial with an axis of rotation of the drill bit and the jack element has an asymmetrical distal end that extends beyond a working face of the drill bit. A turbine is located within a bore formed in the drill bit and a flow valve is actuated by the turbine. The flow valve is adapted to route a drilling fluid in the bore into a porting mechanism adapted to extend the jack element farther beyond the working surface of the drill bit. The turbine is also adapted to rotate the jack element at variable speeds.