| 序号 | 专利名 | 申请号 | 申请日 | 公开（公告）号 | 公开（公告）日 | 发明人 |
|---|---|---|---|---|---|---|
| 221 | Formation Evaluation While Drilling | US16051776 | 2018-08-01 | US20180355716A1 | 2018-12-13 | Steven G. Villareal; Reinhart Ciglenec; Michael J. Stucker; Khanh Duong |
| In one embodiment, a sampling while drilling tool includes a drill collar having a first end, a second end, an outer wall extending between the first and second ends, and at least one opening extending through the outer wall to a cavity within the drill collar. The sampling while drilling tool also includes a sample chamber positionable in the cavity through the opening in the outer wall and a passage for conducting a drilling fluid through the drill collar. | ||||||
| 222 | Electronic devices for high temperature drilling operations | US14265272 | 2014-04-29 | US10151195B2 | 2018-12-11 | Sheng Zhan; Jinhai Zhao; Herong Zheng; Weiping Xu |
| The present disclosure provides the printed circuit board assembly suitable for operating downhole at high temperatures. The printed circuit board assembly has a ceramic circuit board with a plurality of chips installed on it. At least one of the chips has an aluminum nitride or a silicon nitride substrate. In some of the chips, aluminum nitride is used as the oxide layer in a Si-on-Insulator configuration. In other chips, integrated circuits are fabricated on a substrate made from aluminum nitride, silicon nitride, silicon carbide, or sapphire. | ||||||
| 223 | METHOD AND APPARATUS FOR RETAINING COMPONENTS IN A DOWNHOLE MOTOR | US15767968 | 2015-11-19 | US20180305988A1 | 2018-10-25 | Hossam Gharib; John Keith Savage |
| Methods and apparatus are disclosed for retaining components in a downhole motor in the event of a mechanical separation or failure of one or more components therein. As described, the retention mechanism does not require a threaded connection to components of the mud motor drivetrain. Downhole motor assemblies including the new catch mechanism also include a structural element to engage the catch assembly and the components to which it is attached in the event of a mechanical failure within the mud motor assembly. | ||||||
| 224 | Data communication in wellbores | US15128966 | 2015-03-13 | US10066479B2 | 2018-09-04 | Mark Gregory Maylin; Adrian Robert Bowles; Micheal Alan Jones |
| Method and apparatus to allow continuous recovery and broadcast of data and commands to and from a tubular string (32) through all phases of drilling and completion running in a wellbore. A RF transceiver (76/74) is located on the tubular string, the transceiver being adapted to receive signals and broadcast the signals, and a RF transceiver (88/90) is located remote from the tubular string and adapted to receive the broadcasted signal by virtue of an antenna (92) arranged within a fluid filled annulus (60) around the tubular string. RF transmission through the wellbore using distributed RF transceivers providing data and command transmission up and down the tubing string. | ||||||
| 225 | SUBASSEMBLY FOR A BOTTOM HOLE ASSEMBLY OF A DRILL STRING WITH A POWER LINK | US15895230 | 2018-02-13 | US20180230779A1 | 2018-08-16 | Andrew Bridges; Raymond Garcia |
| A subassembly for a bottom hole assembly of a drill string, the subassembly comprising: a tubular portion having a wall for supporting one or more sensors and an inner surface defining a longitudinal bore; a probe assembly comprising a main body, the probe assembly being removably located in the bore and positioned such that a flow channel for drilling fluid is defined between the inner surface of the tubular portion and the probe assembly. A power link for transferring electrical power between the probe assembly and a sensor supported by the tubular portion. | ||||||
| 226 | SHANK ADAPTOR WITH STRENGTHENED FLUSHING HOLE | US15578737 | 2016-05-02 | US20180171723A1 | 2018-06-21 | Anna NORDSTRAND; Petri AHOLA; Rasmus HEMPH |
| A rock drilling shank adaptor has at least one flush hole extending radially through the body of the adaptor in communication with an axially extending internal bore. The flush hole in a direction from an external side to an internal side includes a surface at a rearward region that is curved at least at a radially inner portion to extend in an axial direction towards a forwardmost end of the adaptor to increase the resistance of the adaptor to stress concentrations whilst achieving a desired flow rate of flushing fluid flow into the internal bore. | ||||||
| 227 | NEAR-BIT TOOL ATTITUDE MEASUREMENT WHILE DRILLING APPARATUS AND METHOD | US15689879 | 2017-08-29 | US20180058192A1 | 2018-03-01 | Wenxiu ZHANG; Qingyun DI; Wenxuan CHEN; Yongyou YANG; Yuntao SUN; Jian ZHENG; Jianguang LIU |
| A near-bit tool attitude MWD apparatus includes measurement sensors and a measurement circuit. The measurement sensors transmit measured signals to the measurement circuit, and the measurement circuit processes and calculates the signals to obtain attitude data. The measurement sensors include a triaxial accelerometer, a triaxial gyroscope, a triaxial magnetic sensor and a temperature sensor, the measured data of the triaxial accelerometer, the triaxial gyroscope and the triaxial magnetic sensor are respectively corrected using the measured data of the temperature sensor, a first attitude angle is calculated using the corrected measured data of the triaxial accelerometer and the triaxial magnetic sensor. Quaternions are initialized using the first attitude angle, and the initialized quaternions are subjected to time updating according to the measured data of the triaxial gyroscope, and further an attitude angle is calculated utilizing the updated quaternions. The quaternions are periodically initialized to eliminate cumulative errors of the triaxial gyroscope, so as to improve the near-bit tool attitude MWD accuracy. | ||||||
| 228 | Multi-angle rotary steerable drilling | US14062963 | 2013-10-25 | US09828804B2 | 2017-11-28 | Michael Pearce; Junichi Sugiura |
| Rotary steerable drilling apparatus and methods utilizing apparatus comprising a shaft, a multi-angle strike ring axially repositionable along the shaft, an articulated member coupled to the shaft, and a steering member carried by the articulated member. An actuator is operable to maintain an angular offset of the articulated member relative to the shaft by maintaining azimuthally-dependent contact between the multi-angle strike ring and the steering member. | ||||||
| 229 | DRILL STRING ROD WITH GUIDANCE SHOULDER | US15527778 | 2015-11-13 | US20170321496A1 | 2017-11-09 | Per MATTSON; David WICKSTROM |
| A drill string rod and a drill string assembly includes a drill rod and a drill bit. The rod includes a threaded male end and a female end. An axially extending shoulder is provided at the male end and has an axial length greater than an outside diameter of the shoulder to provide a shoulder driven rod exhibiting enhanced guidance to achieve straighter holes and better collaring. | ||||||
| 230 | Insulating component | US14374906 | 2013-01-24 | US09777538B2 | 2017-10-03 | Bruce McGarian |
| An insulating component for inclusion in a down hole drill string comprising a first part or connected group of parts, and a second part or group of parts. The first part or group of parts includes a first connection site and the second part or connected group of parts includes a second connection site. The insulating component also includes a first right-hand threaded connection located between the first connection site and the second connection site, and a second, left-hand threaded connection located between the first connection site and the second connection site. The first part or group of parts is electrically insulated from the second part or group of parts through insulating material provided between the first part or group of parts and the second part or group of parts, so that the first and second connection sites are electrically insulated from one another. | ||||||
| 231 | FRICTION REDUCING WEAR BAND AND METHOD OF COUPLING A WEAR BAND TO A TUBULAR | US15461876 | 2017-03-17 | US20170254158A1 | 2017-09-07 | Jean Buytaert; Eugene Edward Miller; Ira Eugene Hining |
| 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. | ||||||
| 232 | Centralizer assembly and method for attaching to a tubular | US14502799 | 2014-09-30 | US09745803B2 | 2017-08-29 | Jean Buytaert; Ira Eugene Hining; Eugene Edward Miller; David E. Y. Levie; Richard Ronald Baynham |
| A centralizer, method, and centralizer assembly. For example, the centralizer assembly includes a first stop collar fixed in place on a tubular, and a first end collar that is sized to slide axially over the first stop collar. The centralizer assembly also includes a first retainer coupled with the first end collar. The first retainer prevents the first stop collar from sliding past the first stop collar in at least one axial direction. The assembly also includes a plurality of ribs coupled with the first end collar and configured to engage a surrounding tubular in which the tubular is disposed. | ||||||
| 233 | WELLSITE HARDFACING WITH PARTICLE DISTRIBUTION AND METHOD OF USING SAME | US15016094 | 2016-02-04 | US20170226807A1 | 2017-08-10 | Kevin Joseph Wyble; Alan Jay Harmon; Kevin Lawrence Williams; Cameron Spiller |
| A chromium-free, distributed hardfacing disposable on a surface of a wellsite component is disclosed. The hardfacing includes a metal filler (e.g., nickel) and particles distributed about the filler. The particles include pellets made of tungsten carbide and pieces made of angular molybdenum carbide. The pieces are smaller than the pellets for distribution in the filler between the pellets whereby a uniform distribution of particles is provided about the filler. | ||||||
| 234 | DOWNHOLE DRILLING ASSEMBLY WITH CONCENTRIC ALIGNMENT FEATURE | US15334552 | 2016-10-26 | US20170114597A1 | 2017-04-27 | Josh Chevalier; Chris Bairrington |
| A concentric alignment device is provided that elevates the working face of a drill bit off of the inner wall of a casing or tubing to prevent premature wear of the working face of the drill bit. In horizontal drilling applications, the working face of a drill bit has a tendency to contact or rest on the inner wall of a casing or tubing, which negatively affects the working face of a drill bit. In some embodiments, one or more optional inserts are provided on the shank of a drill bit or on a centralizing sub such that the inserts contact the inner wall of a casing or tubing instead of the working face of the drill bit. In other embodiments, blade packages on a drill bit or sub contact the inner wall of a casing or tubing and also pump drilling fluid in a downhole direction. | ||||||
| 235 | Systems and methods of a sample bottle assembly | US14734442 | 2015-06-09 | US09598956B2 | 2017-03-21 | Kristopher V. Sherrill; Clive D. Menezes; David Welshans |
| A method and apparatus according to which a sample bottle drill collar section is assembled. In an exemplary embodiment, the apparatus includes a drill collar that includes an outer surface; a pocket accessible through an aperture in the outer surface, the pocket defining a first side wall and a second side wall; a bottle assembly disposed within the pocket, the bottle assembly comprising a sample bottle having an axial length; one or more clamps coupled to the outer surface and abutting or overlapping the bottle assembly, the one or more clamps at least partially retaining the bottle assembly in the pocket; and one or more spacers disposed within the pocket, the one or more spacers abutting the bottle assembly and at least one of the first and second side walls of the pocket. | ||||||
| 236 | Friction reducing wear band and method of coupling a wear band to a tubular | US14481829 | 2014-09-09 | US09598913B2 | 2017-03-21 | Jean Buytaert; Eugene Edward Miller; Ira Eugene Hining |
| 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 stop collar and a second stop collar 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. | ||||||
| 237 | LOGGING-WHILE-DRILLING TOOL INCORPORATING ELECTRONIC RADIATION GENERATOR AND METHOD OF USING SAME | US15193849 | 2016-06-27 | US20160306070A1 | 2016-10-20 | Matthieu Simon; Peter Wraight; Christian Stoller; Kenneth E. Stephenson; Andrew Bazarko |
| Logging-while-drilling tools incorporating an electronic radiation generator, such as an electronic X-ray generator, and a method for using the same are provided. One example of such a logging-while-drilling tool may include a circumferential drill collar, a chassis disposed radially interior to the drill collar, and an electronic X-ray generator and an X-ray detector disposed within the chassis. The electronic X-ray generator may emit X-rays out of the logging-while-drilling tool into a subterranean formation. The X-ray detector may detect X-rays that return to the logging-while-drilling tool after scattering in the subterranean formation, which may be used to determine a density and/or a lithology of the subterranean formation. | ||||||
| 238 | CENTRALIZER FOR USE WITH WELLBORE DRILL COLLAR | US14913797 | 2015-08-18 | US20160290068A1 | 2016-10-06 | Benjamin Scott Riley; Daniel Patrick Carter |
| A centralizer includes one or more centralizer fins radially extending from a body of the centralizer. The centralizer fins may include one or more chambers extending through the outer surfaces of the centralizer fins. The one or more chambers may change shape in response to a compression force being applied to the centralizer fins to cause the centralizer fins to deform. The centralizer fins may be deformed for installation of the centralizer in a drill collar. The centralizer may also include a split-ring clamp for coupling the centralizer to a drilling tool positioned in a through-bore of the centralizer body. The split-ring clamp may apply a load on the drilling tool in response to an end cap being torqued to an end portion of the centralizer body. | ||||||
| 239 | Analyzing toolface velocity to detect detrimental vibration during drilling | US12971202 | 2010-12-17 | US09366131B2 | 2016-06-14 | Charles Mauldin; Roger Bartel; Richard Berns |
| A downhole drilling vibration analysis involves measuring orientation data in at least two orthogonal axes downhole while drilling with a drilling assembly. For example, two orthogonal magnetometers can be used. A toolface of the drilling assembly is determined using the measured sensor data, and velocity (RPM) values for the toolface for a plurality of revolutions of the drilling assembly are determined. From these determined values, a coefficient of variation for the toolface velocity (RPM) values for the revolutions of the drilling assembly is calculated. When a pattern in found in the toolface velocity (RPM) and/or the calculated coefficient of variations exceed one or more thresholds, the processing device determines that detrimental vibrations are occurring in the drilling assembly. | ||||||
| 240 | Attachable collar for down hole apparatus | US13785129 | 2013-03-05 | US09217301B1 | 2015-12-22 | William Garland Latham |
| An attachable collar arrangement for a down hole apparatus that includes a collar member releasably insertable into a cutaway section disposed circumferentially around a tool joint or other down hole apparatus. The collar member is stabilized in position within the cutaway section by means of a stabilizing insert member which is releasably inserted between at least two sections of the collar member, and removably secured into a member insert receptacle disposed upon the tool joint or other down hole apparatus. Wear and erosion are directed to the collar member during drilling operations and the tool joint or down hole apparatus is thereby protected. The collar member is expediently replaceable when needed and drilling operations are extended over the life of particular drilling equipment to which the device is installed. | ||||||
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