Abstract: A wear band for a well drill pipe which is made up of a coil spring sized to fit at the joint of the well drill pipe or casing. The inner surface of the coil spring includes a textured coating such as a carbide. The outer surface includes a plurality of hydrodynamic dimples defined therein, and preferably both the outer surface and the inner surface are adapted to resist corrosion. The abrasive coating preferably consists essentially of 95% tungsten carbide and a binder of 5% cobalt and coats an amount of the inner surface in the range of 50% to 100%. The hydrodynamic dimples are generally tear drop in shape to act as miniature fluid pumps. As a result, the wear band can be mechanically attached to the drill pipe while eliminating the need for metallurgically-welded hardbands and therefore unaffecting the drill pipe properties and dimensions.

Abstract: A rotating drill string sub redistributes wellbore drill cuttings into the drilling fluid flowstream to improve the efficiency of the drilling operation. Standoff elements are located on each side of an agitator, all configured on a relatively short section of drill pipe. The agitator comprises a plurality of alternating blades standing radially outward from and arranged helically about the axis of the sub, and grooves located between pairs of adjacent blades, each groove comprising a flow channel that is open at both ends of the agitator. The standoff elements contain abutment surfaces having an outer diameter greater than the outer diameter of the agitator, so that the agitator is prevented from contacting the wall of the wellbore and therefore does not experience the forces that the standoff elements experience.

Abstract: A tubing centralizing apparatus has a centralizer body including opposing end portions, a central passage extending through the opposing end portions, and a plurality of apertures extending therethrough between its exterior side surface and the central passage. The apertures are uniformly spaced about a longitudinal axis of the central passage. Bow springs are mounted on the exterior side surface of the centralizer body such that a central portion of each one of the bow springs is bowed away from the centralizer body. The tubing sub is slideably positioned within the central passage of the centralizer body. One of the tubing joint collars is attached to each end portion of the tubing sub. The tubing joint collars and the centralizer body are jointly configured such that the tubing joint collars engage the centralizer body for constraining the tubing sub within the central passage of the centralizer body.

Abstract: A system for recovering drilling mud in drilling an underground arcuate path around at least a portion of an obstacle has a conductor casing, a drill pipe surrounded by the conductor casing for at least a portion of an axial length of the drill pipe, a flow line connected to the conductor casing at a downhole position, and a pump coupled to the flow line placed at another downhole position. A volume of drilling mud within the underground arcuate path is pumped from the underground arcuate path to the surface and recovered for recirculation.

Abstract: Centralizer includes a body formed of a first material and an outer shell formed of a second material. The outer shell is installed to resist destructive damage and longitudinal creep of the portion formed of the first material. The outer shell covers the entire exterior surface of the body, including ribs that protrude from the exterior surface. The outer shell material is more durable than the material of the body. The outer shell material may be steel and the body material may be a polymer. The ribs and exterior surface of the body bond to the outer shell. The centralizers fit on well pipes to centralize them within boreholes.

Abstract: A joint according to the invention for connecting a pair of members rotatable about a common axis end to end. A sleeve has a non circular profile on an inner surface thereof whereby the sleeve can be slidably mounted on non circular exterior surfaces of the first and second members when such surfaces are brought into alignment by rotation of one member relative to the other in a manner effective to pass torque from one member to the other by means of the non circular surfaces. A fluid release passage includes a radial port that extends from the first longitudinal fluid supply passage to a clearance between the sleeve and the first member, which clearance communicates with a second clearance between the sleeve and the second member, which second clearance has a discharge opening.

Abstract: An interchangeable sleeve for a downhole tool includes a substantially cylindrical body configured to circumferentially engage the downhole tool, a blade extending radially from the body, and a transducer disposed within the blade. A drilling assembly includes a drill collar, an interchangeable blade configured to couple to the drill collar, and a transducer disposed within the blade. A size of the blade and a size of the transducer are selected based on a diameter of a borehole in which the downhole tool is to be used. A method of manufacturing an interchangeable sleeve for a downhole tool includes forming a blade on a body of the sleeve such that the blade extends radially from the body, disposing a transducer within the blade, and configuring the sleeve to circumferentially engage the downhole tool.

Abstract: A close-tolerance expandable bow spring centralizer 8 having a first expandable collar 10A coupled to and spaced apart from a second expandable collar 10B through a plurality of bow springs 30 wherein expandable collars 10A, 10B comprise a plurality of slidably coupled links 16 that separate to expand the diameter of the collars 10A, 10B, e.g., upon expansion of an expandable pipe string 80 on which the centralizer 8 is received. Expandable bow spring centralizer 8 may grip the expandable pipe string 80 when in the collapsed configuration to eliminate the need for a stop collar. Additionally or alternatively, a fin 32 may be connected to each bow spring 30, and then connected to one or more adjacent fins 32 upon collapse of the bow springs 30 to form a restraining band 39 that may be ruptured, e.g., upon expansion of the expandable pipe string 80.

Abstract: A device (100, 200) is for centering a drill casing (7) within a wellbore (3). The device (100, 200) includes a generally tubular body (9) having an outer surface (11) facing the wellbore (3). A plurality of protrusions (4) is disposed on the outer surface (11) along a line (6). A gap region between the protrusions (4) along the line (4).

Abstract: Centralizers including at least a portion formed of a first material and at least one end band secured to the first material and formed of a second material. The end band being installed to resist detachment from the portion formed of the first material.

Abstract: A housing (15) for connection to a downhole assembly (17), the housing comprising first and second sections (31, 32), the first section (31) being adapted for connection to a portion of the downhole assembly, the second section (32) defining a compartment (23) to receive a downhole tool (11) or component thereof, the second section (32) being configured to provide a path (40) for fluid flow past the compartment (23) as the assembly descends within the borehole, and the first section (31) being configured for fluid communication between a passage in said portion of the downhole assembly and the fluid flow path (40).

Abstract: A stop collar assembly used for axially securing and/or to resist axial sliding of a downhole tool device. The assembly provided on a housing of the downhole tool and includes a generally annular ring having an inner circumference beveled outward proximate to the ring edge. A clamp ring having a raised portion on its outer surface is disposed adjacent and substantially coaxial with the annular ring. Pushing the annular ring against the clamp ring compresses the clamp ring onto the housing to resist axial sliding of the annular ring.

Abstract: A centraliser segment (11) comprising a first collar portion(15), a second collar portion (17) and bow element (19) extending between said first collar portion and said second collar portion to maintain the collar portions in spaced relation to each other, said bow portions having an intermediate portion which lies to one side of the plane accommodating the collar portions, a first connector element (21) provided at one end of the collar portions and second connector element (23) provided at the other end of the collar portions, said first connector elements are engagable with said second connector elements of the same or another centraliser segment such that one or more said centraliser segments are connectable together to form a centraliser which in use is capable of being received around a borehole casing, said first and second connector element having an adjustment element which can cause the diameter of the centraliser can be varied by operation of the adjustment element (41) wherein the adjustment is co

Abstract: A transport assembly configured to be attached to downhole apparatus has a support assembly configured to be attached to the downhole apparatus and a ground engaging assembly, which may be a roller wheel configured to contact with and move in relation to a surface of a wellbore. The roller wheel may engage with the support assembly so as to provide for their relative rotation. The transport assembly also includes a retaining member disposed between the roller wheel and the support assembly, and the retaining member is operable to resist separation of the roller wheel from the support assembly. The transport assembly is further configured such that, when the transport assembly is in use moving along a wellbore, the roller wheel bears against the retaining member, which in turn bears against the support assembly. The retaining member is a ball-bearing.

Abstract: An adjustable centering tool for use in pipes of varying inner diameter. The centering tool being provided with a number of identical and steplessly adjustable, radially protruding wings having guiding lugs and chamfered end faces. The wings, having been set, are retained by an upper lock mandrel with a safety pin and a lower lock mandrel with a safety nut. The outer circumference of a cylindrical tool body is fitted with longitudinal grooves having sloped terminations cooperating with the wing dimensions, the chamfered end faces of the wings, and the guiding lugs.

Abstract: Apparatus and methods for using the drilling apparatus to increase the linear direction of the drilling action are described. The drilling apparatus contains a drill rod that is fitted with a reinforcing sleeve that is located on the drill rod as close as possible to the drill bit. The outer diameter of the sleeve is configured to be substantially the same as the bit diameter and, if necessary, just slightly smaller than the bit diameter. The sleeve reinforces the drill rod next to the drill bit and reduces and substantially eliminates the gap between the drill rod and the borehole in the vicinity of the drill bit. The sleeve, therefore, reduces the wobble of the drill bit in the borehole and reduces the drill bit from wavering from a straight linear drilling direction. The reinforcing sleeve can contain helical channels for moving material displaced by the drilling process away from the drill bit.

Abstract: A method of constructing a borehole drilled with a drilling apparatus (16), the method comprises: connecting a flexible tubular liner sleeve (22) around the outside of the drilling apparatus and connecting the sleeve around an upper opening of the borehole so as to pass into the borehole; progressively extending the sleeve into the borehole as drilling progresses while maintaining connection to the drilling apparatus and borehole opening; at a predetermined point in the drilling, expanding the sleeve so as to contact the borehole wall; and setting the sleeve so as to be fixed to the borehole wall after expansion. Apparatus for use in such a method comprises: a flexible, expandable sleeve (22); a first connector for connecting the sleeve around the outside of a drilling assembly; and a second connector for connecting the sleeve around the opening of the borehole; wherein the sleeve is arranged to extend through the borehole between the connectors as drilling progresses.

Abstract: There is disclosed an improved tool, e.g. adapted to comprise at least part of a well completion assembly or well drilling assembly. The invention provides an improved downhole tool (or device) having a friction factor of the order of ten times less than those known from the prior art, e.g. of the order of 0.100 or less. Accordingly the invention provides a downhole tool (10; 10a; 10b; 10c; 10d), at least part of the downhole tool or device being made from Tungsten Disulphide (Tungsten Disulfide). In a disclosed embodiment the at least part comprises at least one surface of the downhole tool, the at least one surface comprising a bearing surface, e.g. a journal bearing surface and/or a thrust bearing surface.

Abstract: A close-tolerance expandable bow spring centralizer 8 having a first expandable collar 10A coupled to and spaced apart from a second expandable collar 10B through a plurality of bow springs 30 wherein expandable collars 10A, 10B comprise a plurality of slidably coupled links 16 that separate to expand the diameter of the collars 10A, 10B, e.g., upon expansion of an expandable pipe string 80 on which the centralizer 8 is received. Expandable bow spring centralizer 8 may grip the expandable pipe string 80 when in the collapsed configuration to eliminate the need for a stop collar. Additionally or alternatively, a fin 32 may be connected to each bow spring 30, and then connected to one or more adjacent fins 32 upon collapse of the bow springs 30 to form a restraining band 39 that may be ruptured, e.g., upon expansion of the expandable pipe string 80.

Abstract: A cutting tool includes a mandrel; a matrix affixed to the mandrel; and cutting material disposed within the matrix and method of making the same.

Abstract: In one embodiment, a wear band comprises a rotating element having a bore receivable on a tubular, the bore comprising first and second bore portions slidably receiving first and second sleeve bearings. Outer surfaces of the sleeve bearings slidably engage the bore portions and the bores of the sleeve bearings slidably engage the tubular. A first and a second stop collars may be received on the tubular to together straddle the rotating element and sleeve bearings to longitudinally secure the rotating element in a position on the tubular. The tubular may be included within a tubular string run into a borehole or into the bore of an installed casing, such as in casing while drilling. The rotating element provides stand-off between a tubular and the wall of a bore, reduces frictional resistance to longitudinal sliding and also to rotation of the tubular string within the bore.

Abstract: Apparatus and methods for using the drilling apparatus to increase the linear direction of the drilling action are described. The drilling apparatus contains a drill rod that is fitted with a reinforcing sleeve that is located on the drill rod as close as possible to the drill bit. The outer diameter of the sleeve is configured to be substantially the same as the bit diameter and, if necessary, just slightly smaller than the bit diameter. The sleeve reinforces the drill rod next to the drill bit and reduces and substantially eliminates the gap between the drill rod and the borehole in the vicinity of the drill bit. The sleeve, therefore, reduces the wobble of the drill bit in the borehole and reduces the drill bit from wavering from a straight linear drilling direction. The reinforcing sleeve can contain helical channels for moving material displaced by the drilling process away from the drill bit.

Abstract: Drilling apparatuses and methods for limiting precession are provided. According to one embodiment, a drilling apparatus includes a non-rotating stabilizer. The non-rotating stabilizer includes a first blade and a second blade, the first blade being arranged opposite the second blade. The first blade is biased radially outwardly by a force of a first value. The second blade is not biased radially outwardly by a force corresponding to the first value. The second blade may be a blade which is slidable along the non-rotating stabilizer in an axial direction and allow free sliding axial contact with the formation.

Abstract: A rod guide is provided for use in a rotating rod string (12) for powering a progressive cavity pump (14) for pumping downhole fluids through tubing (16) to the surface. The rod guide includes a rotor sleeve (20) secured to the rod string and having a plurality of circumferentially spaced exterior surfaces (22) each positioned substantially along an exterior of a cylinder. The rotor sleeve also includes one or more stop surfaces (24) for limiting axial movement of a stator sleeve (40) with respect to the rotor sleeve, and two or more axially extending cavities (26) each extending from a bottommost surface to an opposing uppermost surface of the rotor sleeve and passing through the one or more stop surfaces. Stator sleeve (40) surrounds the rotor sleeve and has an interior surface (42) for engaging the plurality of circumferentially spaced exterior surfaces of the rotor sleeve, and a plurality of ribs (44) extending outward from two or more outer cylindrical surface portions (44) of the stator sleeve.

Abstract: Plate structures attachable to earth-boring tools comprise a disk including a circumferentially extending rim configured for attachment to an earth-boring tool. An aperture is formed through a portion of the disk and positioned radially interior from the rim. The aperture is configured to at least partially align with at least one junk slot of the earth-boring tool. Earth-boring tools comprising such plate structures, and methods of forming such earth-boring tools are also disclosed.

Abstract: A purely mechanical hydraulic control system includes at least one drilling fluid chamber and a hydraulic fluid chamber. A system pressure spring is deployed in one of the drilling fluid chamber(s) between a positioning piston and a system pressure piston. The spring is disposed to pressurize oil in the hydraulic fluid chamber via applying a spring force to the system pressure piston. When the system is actuated (e.g., via turning on the mud pumps), the positioning piston is urged in place against a stop (e.g., a shoulder) thereby compressing the system pressure spring and pressurizing oil in the hydraulic chamber. The invention advantageously converts highly variable drilling fluid pressure to a near constant pressure hydraulic fluid.

Abstract: A wear resistant sub assembly with a sleeve with a sleeve outer diameter larger than the body outer diameter, a plurality of offset indentations formed on the outer side of the sleeve formed in rows of four to eight offset indentations along a diagonal orientation to a sleeve axis; a plurality of a metal carbide inserts providing an interference fit into each offset indentation thereby forming a wear resistant sleeve; a sealing means disposed between the sleeve and the body and at least two spring locking apparatus engaging locking indentations on the body.

Abstract: A drill stem connection assembly includes a first drill stem section and a second drill stem section. At least one engaging feature is located at an end of the first drill stem section. At least one mating feature accepts the at least one engaging feature. The at least one mating feature is located at an end of the second drill stem section. Coupling of the respective ends of the first and second drill stem sections forms a drill stem joint. A threaded collar engages with at least one of the coupled first and second drill stem sections. When placed in a securing position, the threaded collar holds the engaging feature securely mated with the mating feature and at least partially covers the drill stem joint.

Abstract: A drilling stabilization system includes a power section coupled to an upper end of a transmission housing, a bearing housing coupled to a lower end of the transmission housing, and a drill bit coupled to the bearing housing, wherein the transmission housing includes at least two radially outwardly extending blades disposed on the transmission housing. A method of drilling a substantially concentric wellbore includes drilling a formation with a directional drilling bottomhole assembly coupled to a drill string, changing a direction of the drilling of the formation being drilled, removing the directional drilling bottomhole assembly from the drill string, coupling a drilling stabilization system to the drill string, and drilling the formation with the drilling stabilization system.

Abstract: Apparatus and methods disclosed herein utilize a seal within a well borehole annulus to re-direct forces generated by a column of effluents from a well-drilling bit assembly to a point above the bit assembly during drilling operations.

Abstract: An integrated spiral blade collar comprising: a collar comprising a wall defining a bore, the collar having a longitudinal axis extending from a proximal end to a distal end; the collar comprising a first engagement mechanism at the proximal end and a second engagement mechanism at the distal end; the collar comprising one or more integral blades extending radially outward from an outer surface and forming a spiral around the longitudinal axis of the collar from at or near the proximal end to at or near the distal end of the collar, the spiral being at an angle of from 1° to 89° relative to the longitudinal axis of the collar.

Abstract: A multi part centralizer can be secured quickly to tubular to be cemented and expanded in a deviated wellbore. The segments ratchet with respect to each other and are capable of holding the centralizer snug against the tubular for delivery downhole and cementing. After cementing the expansion of the tubular is not significantly resisted by the centralizer as its diameter increases with the expanded tubular below it. The end position after expansion is held due to the ratchet feature insuring the fixation of the centralizer as the cement sets.

Abstract: An improved centralizer is provided for centralization of tubulars such as casings, liners, production tubing, and production screens, in oil/gas wells. Such a centralizer comprises a tubular body, wherein a portion of an outermost surface of the tubular body is formed from a first material, and a portion of, or portion adjacent to, at least one end of the tubular body, and/or a portion of an innermost surface of the tubular body, is formed from at least one second material, in contrast to unitary construction centralizers disclosed by the prior art, and the first material has a lower Young's modulus than the at least one second material.

Abstract: An apparatus for protecting a sub assembly inside a borehole of a well, with a sleeve having a sleeve outer diameter larger than the body outer diameter; a plurality of offset indentations formed on the outer side of the sleeve formed in rows of 4 to 8 offset indentations along a diagonal orientation to a sleeve axis; a plurality of a metal carbide inserts providing an interference fit into each offset indentation thereby forming a wear resistant pad on the outer side of the sleeve; a sealing means disposed between the sleeve bottom beveled edge and the body forming a sealed sub assembly using at least two spring locking apparatus engaging locking indentations on the body.

Abstract: The invention relates to a device for control of the flow through a production tube placed in an oil well. The device comprising a portion of the production tube provided with through orifices and protection equipment for providing resistance to wear by erosion. The protection equipment comprises several add-on sectors assembled around the portion of the tube. Each add-on sector provided with an associated inner stiffener penetrating into the portion of the production tube through at least one through orifice. At least one of the add-on sectors provided with at least one opening extending through the sector and its associated inner stiffener.

Abstract: A drill bit for percussive rock drilling of the type that comprises a front head and a tubular skirt, which extends rearward from the head to a rear, ring-shaped end and includes an internal thread for the transfer of combined impact and rotary motions to the drill bit is disclosed. The rear end of the skirt is, via an unelastic joint, e.g., a friction weld, united to a front end of a sleeve having an envelope surface, from which a plurality of projections are peripherically spaced-apart from each other project, e.g., ridges, having the purpose of guiding the drill bit in the drill hole. By assembling the drill bit of two parts, the internal thread can be turned with high accuracy and smoothness, at the same time as the drill bit is given an inherent good controllability. In an additional aspect, a method for the manufacture of such a drill bit is also disclosed.

Abstract: A collar for protecting a body inside a borehole of a well, with a collar outer diameter larger than the body outer diameter, a plurality of offset indentations formed on the outer side of the collar formed in rows of four to eight offset indentations along a diagonal orientation to a collar axis. A metal carbide inserts engages each offset indentation with an interference fit forming a wear resistant pad on the outer side of the collar. A sealing means is disposed between a bottom beveled edge of a collar and the body forming a sealed sub assembly. At least two spring locking apparatus engaging a locking portion on the body.

Abstract: A method of avoiding the need for a scraper run in drill out operations. The method involves the single step of incorporating a rotary scraper into the downhole drilling motor assembly in such a manner that the rotary scraper rotates with the drill bit and follows the drill bit to scrape debris from interior casing walls.

Abstract: A method and apparatus for the application of a sleeve upon a tubular, such as a pipe string, used in downhole applications, for example in oil and gas exploration or recovery. A mould is located around the tubular into which a composite material is injected. The material is cured at ambient temperature. Optional heating may then be applied to enhance the properties of the sleeve. The heating temperatures are well below those at which the structural integrity of the metal tubular would be compromised as regards its fitness for downhole use. Embodiments of wear protectors are illustrated for sleeves with and without wear pads.

Abstract: Apparatus and methods are provided for reducing drilling vibration during drilling with casing. In one embodiment, an apparatus for reducing vibration of a rotating casing includes a tubular body disposed concentrically around the casing, wherein tubular body is movable relative to the casing. Preferably, a portion of the tubular body comprises a friction reducing material. In operation, the tubular body comes into contact with the existing casing or the wellbore instead of the rotating casing. Because the tubular body is freely movable relative to the rotating casing, the rotating casing may continuously rotate even though the tubular body is frictionally in contact with the existing casing.

Abstract: Stabilizer (1) designed to be slid onto a rod (2), particularly a string of drilling rods. It comprises at least one elastic part (4) that can deform when the stabilizer (1) is held in an initial position in compression against a shoulder (5) of the rod (2), this elastic part (4) compensating for play that may appear later between the stabilizer (1) and the rod (2). Application particularly to drilling for oil wells.

Abstract: A system for boring horizontal boreholes and installing products using a dual member drill string. The system is comprised of a boring machine with a frame and a rotary drive supported on the frame, a downhole tool, and a dual member drill string. The drill string comprises an inner member disposed within a tubular outer member such that the inner member is rotatable independent of the outer member. The outer member has at least one helical projection supported on an exterior surface of the outer member. The projections on the outer member function as an auger to clear spoils and support the bore. The auger arrangement with the dual member drill string can be used in forward reaming or backreaming operations.

Abstract: An improved centralizer is provided for centralization of tubulars such as casings, liners, production tubing, and production screens, in oil/gas wells. Such a centralizer comprises a tubular body, wherein a portion of an outermost surface of the tubular body is formed from a first material, and a portion of, or portion adjacent to, at least one end of the tubular body, and/or a portion of an innermost surface of the tubular body) is formed from at least one second material, in contrast to unitary construction centralizers disclosed by the prior art, and the first material has a lower Young's modulus than the at least one second material.

Abstract: A drill string valve assembly includes a tubular valve body, including an outer surface and an inner bore for housing a valve mechanism to control fluid flow through the bore; and an axial load support releasably securable to the outer surface of the valve body, the axial load support including an upper releasable load bearing connection to the tubular body and a lower releasable load bearing connection to the tubular valve body.

Abstract: A drilling stabilization system includes a power section coupled to an upper end of a transmission housing, a bearing housing coupled to a lower end of the transmission housing, and a drill bit coupled to the bearing housing, wherein the transmission housing includes at least two radially outwardly extending blades disposed on the transmission housing. A method of drilling a substantially concentric wellbore includes drilling a formation with a directional drilling bottomhole assembly coupled to a drill string, changing a direction of the drilling of the formation being drilled, removing the directional drilling bottomhole assembly from the drill string, coupling a drilling stabilization system to the drill string, and drilling the formation with the drilling stabilization system.

Abstract: A slip ring assembly including a slip ring and an electrical contact assembly. The slip ring defines a circumference and an electrical contact groove extending around the circumference of the slip ring. The electrical contact assembly preferably includes a plurality of electrical contacts spaced around the circumference of the slip ring for engaging the electrical contact groove. In addition, an urging mechanism is preferably associated with each of the electrical contacts for urging the electrical contacts toward engagement with the electrical contact groove. Finally, a wiper is preferably associated with each of the electrical contacts for extending within the electrical contact groove to inhibit a fluid from passing through the electrical contact groove.

Abstract: A stabilizer used to centralize drill pipe in the drilling of wells, such as oil and gas wells, having a replaceable member with a contoured outer surface and specifically designed flow paths.

Abstract: A stabilizer comprises a body having first and second ends, each of which is formed with a respective connector means, the body having an outer wall upon which is formed a plurality of the upstanding blades radially outer surfaces of which define gauge pads, flow channels being defined between adjacent ones of the blades, and at least one bridging region interconnecting two adjacent ones of the blades to form an enclosed passage communicating with an associated one of the flow channels, the bridging region having a surface defining part of an outer gauge surface of the stabilizer, the at least one bridging region being located intermediate and spaced from the first and second ends.

Abstract: A down hole drilling motor includes a stator housing having an exterior surface, an upper end, a lower end, an upper vane mounting region at the upper end and lower vane mounting region at the lower end. An upper mounting sleeve engages the upper vane mounting region, such that rotation during use brings the upper mounting sleeve into contact with an upper contact shoulder. A lower mounting sleeve engages the lower vane mounting region, such that rotation during use brings the lower mounting sleeve into contact with a lower contact shoulder. A plurality of vanes are secured to each of the upper mounting sleeve and the lower mounting sleeve.

Abstract: A drill string system for performing measurement while drilling and logging while drilling operations for oil and gas drilling is provided. The drill string system includes a drill string section having a bore defined by an inner length of surface of a pipe wall which has an outer surface. A tool guide is secured in the drill string section and a support is provided for centering the tool guide in said bore. Communication ports extend through the drill pipe wall from the outer pipe surface to the inner surface and through the support to an inner surface of the tool guide, said communication ports being in communication with one another. An elongate cylindrical tool is disposed in the tool guide. A first terminated passageway in the tool is in communication with a pressure sensor within the tool to sense the drill string annular pressure.