子分类：
| 序号 | 专利名 | 申请号 | 申请日 | 公开（公告）号 | 公开（公告）日 | 发明人 |
|---|---|---|---|---|---|---|
| 81 | CASING CENTRALIZER | US13803088 | 2013-03-14 | US20140262215A1 | 2014-09-18 | Mitchel D. Hansen; Andrew M. Eldridge; Jody D. Riddle; Jeffrey Scott Danielson |
| A casing centralizer comprising a cylindrical base and a plurality of blades extending from the cylindrical base, wherein the plurality of blades and the cylindrical base are compression molded as a single piece from a mineral filled, glass and specialty fiber reinforced polyester molding compound. | ||||||
| 82 | CASING CENTRALIZER AND METHOD OF MANUFACTURING SAME | US14044485 | 2013-10-02 | US20140151026A1 | 2014-06-05 | Gregory James Alexander Andrigo |
| A casing centralizer and method according to which a body covers at least a portion of a frame. In an exemplary embodiment, the body is overmolded around the frame. In an exemplary embodiment, the casing centralizer centralizes a casing within a wellbore to facilitate oil and gas exploration and production operations. | ||||||
| 83 | Non-rotating casing centralizer | US12912615 | 2010-10-26 | US08668007B2 | 2014-03-11 | Garrett C. Casassa; Sarah B. Mitchell; Norman Bruce Moore |
| A non-rotating downhole sleeve adapted for casing centralization in a borehole. The sleeve includes a tubular body made of hard plastic with integrally formed helical blades positioned around its outer surface and an inner surface which allows drilling fluid to circulate to form a non-rotating fluid bearing between the sleeve and the casing. The tubular sleeve comprises a continuous non-hinged wall structure for surrounding the casing. The non-rotating centralizer sleeve reduces sliding and rotating torque at the surface while drilling the casing, for example, with minimal obstruction to drilling fluid passing between the casing and the surrounding borehole. | ||||||
| 84 | CONTINUOUS ROD CENTRALIZER | US13951509 | 2013-07-26 | US20140027107A1 | 2014-01-30 | Gerald L. BINETRUY; Mark J. BINETRUY |
| A continuous rod centralizer has a cylindrical centralizer body with a first end, a second end, an interior surface defining a bore which receives the continuous rod, and vanes extending radially from the exterior surface. A first rod clamp clamps onto the continuous rod at the first end of the body to confine movement of the body along the continuous rod in a first direction. A second rod clamp clamps onto the continuous rod at the second end of the body to confine movement of the body along the continuous rod in a second direction. | ||||||
| 85 | Well string centralizer and method of forming | US12302553 | 2007-05-31 | US08141629B2 | 2012-03-27 | Per G. Angman |
| 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. | ||||||
| 86 | In-situ method of forming a non-rotating drill pipe protector assembly | US12074787 | 2008-03-05 | US08119047B2 | 2012-02-21 | N. Bruce Moore; Eric J. O'Neal; Sarah B. Mitchell |
| A non-rotating drill pipe protector sleeve is molded in situ around a drill pipe tubing. The inner surface of the molded protector sleeve can be shaped to form a fluid bearing during use. Fixed stop collars may be molded in situ in the same mold and bonded to the tubing at opposing ends of the molded sleeve. Alternatively, a flexible sleeve liner made from a material having a hardness less than that of the sleeve's molding material can be used as a mold insert around the tubing. The liner can be bonded to the molded sleeve material when the sleeve is molded around the liner. The interior surface of the liner can be shaped to form a fluid bearing for the inside surface of the molded sleeve. Reinforcing inserts and wear pads can be placed in the mold region of the sleeve. Chemical and/or mechanical bonding is provided between the liner reinforcement and the material from which the sleeve is molded. Reinforcing inserts and wear pads also can be placed in the mold regions for the stop collars. | ||||||
| 87 | NON-ROTATING CASING CENTRALIZER | US12912615 | 2010-10-26 | US20110114338A1 | 2011-05-19 | Garrett C. Casassa; Sarah B. Mitchell; Norman Bruce Moore |
| A non-rotating downhole sleeve adapted for casing centralization in a borehole. The sleeve includes a tubular body made of hard plastic with integrally formed helical blades positioned around its outer surface and an inner surface which allows drilling fluid to circulate to form a non-rotating fluid bearing between the sleeve and the casing. The tubular sleeve comprises a continuous non-hinged wall structure for surrounding the casing. The non-rotating centralizer sleeve reduces sliding and rotating torque at the surface while drilling the casing, for example, with minimal obstruction to drilling fluid passing between the casing and the surrounding borehole. | ||||||
| 88 | Apparatus and methods to protect connections | US11751841 | 2007-05-22 | US07798238B2 | 2010-09-21 | Merle E. Evans; John Richard Setterberg, Jr.; Lev Ring; Ghazi J. Hashem; Richard W. DeLange |
| 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. | ||||||
| 89 | System and method for making drilling parameter and or formation evaluation measurements during casing drilling | US11767744 | 2007-06-25 | US07766101B2 | 2010-08-03 | Brian Clark |
| A casing drilling system includes a casing having a drill bit at one end. The drill bit is capable of drilling subsurface formations and formed from a material removable by drilling or chemical exposure. The chemical is substantially harmless to the casing. The system includes a centralizer affixed to an interior of the casing. The centralizer includes a receptacle therein for engaging a measurement while drilling tool. The centralizer is formed from a material removable by drilling or chemical exposure, wherein the chemical is substantially harmless to the casing. The system includes a measurement while drilling tool configured to move along the interior of the casing and to engage with the centralizer. The tool includes a device to measure a drilling parameter or a formation parameter. The tool including a latch at an upper end thereof for engagement with a retrieval tool moved through the interior of the casing. | ||||||
| 90 | Downhole Device Actuator and Method | US12689787 | 2010-01-19 | US20100175888A1 | 2010-07-15 | Jean Buytaert; Ira Eugene Hining |
| An actuator to actuate a device received on a tubular string adjacent the device. The actuator comprises an energy storage member, such as a spring, restrained in a compressed mode between a stop collar and an outer sleeve threadedly received on a threaded portion of a non-magnetic tubular segment. An outer magnet is coupled to the outer sleeve to magnetically interact with an inner magnet coupled to an inner pipe string. The inner pipe string is run into the bore of the tubular string and the outer sleeve to position the inner magnet proximal the outer magnet to form a magnetic clutch. The inner pipe string rotates to transfer torque to the outer sleeve via a magnetic clutch, to rotate and threadedly disengage the outer sleeve from the tubular segment to release energy from the energy storage member to displace the outer sleeve to engage and actuate the device. | ||||||
| 91 | DOWNHOLE APPARATUS AND METHOD OF FORMING THE SAME | US12446351 | 2007-10-31 | US20100059218A1 | 2010-03-11 | Calum Whitelaw |
| The present invention relates to a method of forming downhole apparatus. The method comprises disposing a plastics material (26) on a reinforcing apparatus (24) to form a body (12) having a bore extending through the body. The reinforcing apparatus (24) provides reinforcement of the plastics material (26) and the thus formed body (12) is configured to provide, when in use, standoff between downhole components, with the reinforcing apparatus being configured to at least one of contract and expand. | ||||||
| 92 | Well String Centralizer and Method of Forming | US12302553 | 2007-05-31 | US20090151931A1 | 2009-06-18 | Per G. Angman |
| 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. | ||||||
| 93 | WELL STRING CENTRALIZER AND METHOD OF FORMING | US11961642 | 2007-12-20 | US20080164019A1 | 2008-07-10 | Per G. Angman |
| Centralizers including at least a portion formed of a first material and an outer shell formed of a second material. The outer shell being installed to resist destructive damage and longitudinal creep of the portion formed of the first material. | ||||||
| 94 | In and relating to downhole tools | US10312605 | 2001-06-28 | US07357178B2 | 2008-04-15 | John Thomas Oliver Thornton |
| 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. | ||||||
| 95 | Control line protector | US10778774 | 2004-02-13 | US20040211571A1 | 2004-10-28 | Oswaldo M. Moreira; Kevin R. Jones |
| Disclosed herein is a control line protector including a matrix having at least one bumper and at least one receptacle. Further disclosed herein is a method for protecting a bare control line by positioning a protector having a matrix at least one bumper and at least one receptacle configured to accept the control line. | ||||||
| 96 | Method for making a stand-off device to prevent an oilfield tubular from contacting the side of the wellbore | US09862729 | 2001-05-23 | US06562401B2 | 2003-05-13 | Benny Alan Eaton |
| A stand-off device for tubulars comprising a sleeve adapted to fit around a tubular, the sleeve comprising an outer surface and a plurality of blades extending along the outer surface of the sleeve, the blades comprising a bearing surface, wherein the bearing surface of each blade is curved longitudinally. The device may be metallic or non-metallic. Non-metallic devices further comprise a protective coating to inhibit abrasion, corrosion, sparking, and electrolysis. The stand-off device is particularly suitable for use with casing in deviated wellbores. | ||||||
| 97 | Sucker rod protector | US09764494 | 2001-01-17 | US06516877B2 | 2003-02-11 | Marcus Terry |
| An apparatus for reducing abrasive wear within a housing that includes a body having at least one protrusion selectively positioned and extending outwardly from the outer surface thereof, the body being placed concentrically within the housing and rubbing against the inside surface thereof as the body is moved within the housing. The body is provided with a plurality of slides residing in a like number of grooves formed on the outside surface thereof, each of the slides having a groove formed in at least one side surface thereof The slides are affixed to the body by deforming the material comprising the body into the groove formed in the slide by striking the surface of the material comprising the body adjacent the groove in which the slide resides with enough force to deform the material comprising the body into the groove formed in the side surface of the slide. The apparatus is particularly effective for use with the sucker rod of a pump jack for a subterranean petroleum well. | ||||||
| 98 | Stand-off device | US09863617 | 2001-05-23 | US06439304B2 | 2002-08-27 | Benny Alan Eaton |
| A stand-off device for tubulars comprising a sleeve adapted to fit around a tubular, the sleeve comprising an outer surface and a plurality of blades extending along the outer surface of the sleeve, the blades comprising a bearing surface, wherein the bearing surface of each blade is curved longitudinally. The device may be metallic or non-metallic. Non-metallic devices further comprise a protective coating to inhibit abrasion, corrosion, sparking, and electrolysis. The stand-off device is particularly suitable for use with casing in deviated wellbores. | ||||||
| 99 | Drill pipe protection rings and method of using the same | US09363126 | 1999-07-28 | US06176328B1 | 2001-01-23 | Miles F. Caraway; Douglas D. Hall |
| Drill pipe protection rings for filling external identification slots in drill pipe tool joints prevent damage to the internal seals of a drilling head. The rings are formed from resilient elastomeric materials. In cross-section, each ring has slightly convex inner and outer surfaces, and a series of circumferentially spaced-apart, hemispherical bumps located along its inner surface. One ring is mounted within each slot on each drill pipe section. The rings stretch slightly while being installed, but form a tight fit once they are properly seated. When installed, the outer surfaces of the rings will protrude slightly outward from or beyond the slots. The hemispherical bumps help align and center the rings within the slots. Without the rings, sharp edges of the slots on the drill pipe tool joints could cause severe damage as they passed through the drill head. However, with the rings, the outer surfaces of the slots are substantially filled to prevent their edges from cutting or gouging the elastomers. | ||||||
| 100 | Non-metallic centralizer for casing | US850525 | 1997-05-02 | US5908072A | 1999-06-01 | Samuel P. Hawkins |
| A non-metallic centralizer for casing having a tubular, plastic sleeve adapted to fit closely about a joint of casing, said sleeve having a plurality of blades extending substantially longitudinally along an outer surface of said sleeve. The non-metallic centralizer having strength characteristics capable of withstanding the forces encountered in casing operations. The non-metallic centralizer is non-sparking for use in hazardous environments, abrasion and wear resistant, and provides protection from electrolysis between adjacent casing strings. The non-metallic centralizer is light weight, allowing increased transportation capacity at a economical cost. | ||||||
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