| 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 | MODEL FOR ESTIMATING DRILLING TOOL WEAR | US15110120 | 2015-02-02 | US20170004235A1 | 2017-01-05 | Robello Samuel; Chris Neil Marland; Zhengchun Liu; Dong Li |
| A method for estimating the wear of a drilling tool is disclosed. The method includes selecting a first incremental distance along a length of a formation. The method further includes determining a first characteristic of the formation along the first incremental distance. The method further includes deriving a first fractional wear factor, y1, for the drilling tool based on the first characteristic of the formation and a first operating condition of the cutting element. The method further includes calculating a first wear function, Wf1, the cutting element based on the first fractional wear factor and estimating an amount of wear of the cutting element during a drilling operation based on the first wear function. | ||||||
| 82 | Holographic techniques for corrosion evaluation of wellbore pipes | US14888483 | 2015-07-08 | US09488749B2 | 2016-11-08 | Reza Khalaj Amineh; Luis Sanmartin; Burkay Donderici |
| A method includes obtaining a first small defect response at a given frequency of a first small defect on a first wellbore pipe positioned within a wellbore. A Fourier transform of the first small defect response is then calculated, and a first measured response at the given frequency of a first arbitrary metal loss defect in the first wellbore pipe is obtained with a sensor of a pipe inspection tool. A Fourier transform of the first measured response is then calculated, and a magnitude of the first arbitrary metal loss based on the Fourier transform of the first small defect response and the Fourier transform of the first measured response is then estimated. | ||||||
| 83 | ADAPTIVE DRILLING VIBRATION DIAGNOSTICS | US14920712 | 2015-10-22 | US20160115778A1 | 2016-04-28 | Eric van Oort; Theresa Baumgartner; Pradeepkumar Ashok |
| The disclosure relates to an adaptive system for diagnosing vibrations during drilling including a drilling assembly at least partially located in a wellbore, a sensor located in the wellbore, and a data processing unit. The drilling assembly may drill the wellbore. The sensor may detect high frequency data reflecting vibrations in the drilling assembly. The data processing unit may execute a classification model based on machine learning techniques which uses features extracted from the high frequency data to diagnose the type or intensity of a vibration or both in the drilling assembly. The disclosure further relates to an adaptive method of diagnosing vibrations during drilling by collecting high frequency data reflecting vibrations in a drilling assembly, extracting at least one feature from the high frequency data, and diagnosing the type of vibration using the at least one extracted feature and a classification model based on machine learning techniques. | ||||||
| 84 | Earth-boring tools including replaceable cutting structures and related methods | US13299914 | 2011-11-18 | US09115554B2 | 2015-08-25 | Chaitanya K. Vempati; Timothy K. Marvel; Suresh G. Patel |
| Earth-boring tools include a body and one or more replaceable cutting structures attached to the body at a face region of the body. Each replaceable cutting structure includes an attachment member and a cutting portion located to engage an earth formation. Methods of forming an earth-boring tool involve attaching one or more cutting elements to a replaceable cutting structure; positioning the replaceable cutting structure proximate a region of a body of an earth-boring tool that is susceptible to at least one of localized wear and localized impact damage; and attaching the replaceable cutting structure to the body. Methods of repairing an earth-boring tool involve bringing a replaceable cutting structure proximate at least one portion of a body of an earth-boring tool exhibiting at least one of localized wear and localized impact damage; and attaching the replaceable cutting structure to the earth-boring tool at the at least one portion. | ||||||
| 85 | SYSTEM AND METHOD FOR MEASURING GAPS USING AN OPTO-ANALYTICAL DEVICE | US14424794 | 2012-08-31 | US20150218935A1 | 2015-08-06 | Michael T. Pelletier; Robert P. Freese; Gary E. Weaver; Shilin Chen |
| In one embodiment, a method includes drilling a wellbore in a formation with a drilling tool. The method further includes receiving electromagnetic radiation using an opto-analytical device coupled to the drilling tool. The method also includes determining a distance between a portion of the drilling tool and the formation based on the received electromagnetic radiation. | ||||||
| 86 | Apparatuses and methods for determining temperature data of a component of an earth-boring drilling tool | US14461957 | 2014-08-18 | US09045972B2 | 2015-06-02 | Xiaomin C. Cheng |
| Components, such as a cutting element for an earth-boring drilling tool, include an ultrasonic transducer coupled therewith and configured to transmit an acoustic signal therethrough, and transmit a data signal to a data acquisition unit in response to receiving a returning echo of the acoustic signal. An earth-boring drilling tool comprises a bit body including a plurality of components, an ultrasonic transducer, and a data acquisition unit operably coupled with the ultrasonic transducer. The data acquisition unit may be configured to receive the data signal and determine a temperature distribution of the component based, at least in part, on a time-of-flight of the acoustic signal and the returning echoes. Methods for forming such components and measuring a temperature of such components may relate to coupling and implementing such an ultrasonic transducer with a component of an earth-boring drilling tool. | ||||||
| 87 | Iterative drilling simulation process for enhanced economic decision making | US12179221 | 2008-07-24 | US08949098B2 | 2015-02-03 | William W. King |
| An iterative drilling simulation method and system for enhanced economic decision making includes obtaining characteristics of a rock column in a formation to be drilled, specifying characteristics of at least one drilling rig system; and iteratively simulating the drilling of a well bore in the formation. The method and system further produce an economic evaluation factor for each iteration of drilling simulation. Each iteration of drilling simulation is a function of the rock column and the characteristics of the at least one drilling rig system according to a prescribed drilling simulation model. | ||||||
| 88 | Magnetic Debris and Particle Detector | US13855406 | 2013-04-02 | US20140290351A1 | 2014-10-02 | Thomas Kruspe |
| A system, method and apparatus for determining wear on a component of a tool is disclosed. An oscillating member receives a particle freed from the component as a result of the wear on the component. A measuring device measures a change in a parameter of the oscillating member resulting from receiving the particle. A processor determines the wear on the component from the change in the parameter. In one embodiment, the component may include a component of a downhole tool. | ||||||
| 89 | Abrasion detecting apparatus detecting abrasion of component of cutter head and tunnel boring machine including abrasion detecting apparatus | US12844396 | 2010-07-27 | US08789890B2 | 2014-07-29 | Hiroyoshi Iwata; Yasunori Kondo; Yoshio Sakai; Taso Aimi |
| An abrasion detecting apparatus is configured to detect the abrasion of a component of a cutter head of a tunnel boring machine, which is configured to excavate ground using a cutter to bore a tunnel. The abrasion detecting apparatus includes an abrasion detection probe located rearward of a front end of the cutter by a predetermined distance and located forward or rearward of a front end of the component, whose abrasion is to be detected, of the cutter head by a predetermined distance, where the abrasion detection probe includes an abrasion detecting portion at a front end portion thereof. The abrasion detecting portion abrades away by contact with the ground to be excavated. The abrasion detecting apparatus also includes a detecting device configured to detect an abrasion of the abrasion detecting portion. | ||||||
| 90 | Method of monitoring wear of rock bit cutters | US13188284 | 2011-07-21 | US08757290B2 | 2014-06-24 | Sorin G. Teodorescu; Terry Hunt |
| A method of monitoring the wear of drill bits for drilling wells in earth formations, several embodiments of an improved drill bit for drilling a well in an earth formation, and methods of manufacture. In one embodiment, the bit is assembled by forming the bit, including a bit body and a plurality of cutting components; introducing a wear detector into the bit; and providing a module to monitor the wear detector and generate an indication of bit wear. The wear detector may be a witness material that may change a characteristic of at least a portion of the bit. The module may detect when the witness material is separated from the bit. The wear detector may be introduced during or after formation of the bit. The bit wear may be displayed for an operator. | ||||||
| 91 | Downhole drilling vibration analysis | US13560843 | 2012-07-27 | US08417456B2 | 2013-04-09 | Charles Lee Mauldin; Barry Vincent Schneider; Mark Adrian Smith |
| Downhole drilling vibration analysis uses acceleration data measured in three orthogonal axes downhole while drilling to determine whether drilling assembly's efficiency has fallen to a point where the assembly needs to be pulled. In real or near real time, a downhole tool calculates impulse in at least one direction using the measured acceleration data over an acquisition period and determines whether the calculated impulse exceeds a predetermined acceleration threshold for the acquisition period. If the impulse exceeds the threshold, the tool pulses the impulse data to the surface where the calculated impulse is correlated to efficiency of the assembly as the drillstring is used to drill in real time. Based on the correlation, operators can determine whether to pull the assembly if excessive impulse occurs continuously over a predetermined penetration depth. | ||||||
| 92 | Downhole drilling vibration analysis | US12570015 | 2009-09-30 | US08255163B2 | 2012-08-28 | Charles Lee Mauldin; Barry Vincent Schneider; Mark Adrian Smith |
| Downhole drilling vibration analysis uses acceleration data measured in three orthogonal axes downhole while drilling to determine whether drilling assembly's efficiency has fallen to a point where the assembly needs to be pulled. In real or near real time, a downhole tool calculates impulse in at least one direction using the measured acceleration data over an acquisition period and determines whether the calculated impulse exceeds a predetermined acceleration threshold for the acquisition period. If the impulse exceeds the threshold, the tool pulses the impulse data to the surface where the calculated impulse is correlated to efficiency of the assembly as the drillstring is used to drill in real time. Based on the correlation, operators can determine whether to pull the assembly if excessive impulse occurs continuously over a predetermined penetration depth. | ||||||
| 93 | Real Time Bit Monitoring | US13237754 | 2011-09-20 | US20120152617A1 | 2012-06-21 | Terry Hunt; Sorin G. Teodorescu; Eric Sullivan |
| A bit is assembled by forming the bit, including a bit body and a plurality of cutting components; embedding at least one electrical circuit into the bit, the circuit including a temperature sensor; and providing a module to monitor the circuits and generate an indication of bit wear. The electrical circuit may experience a change in resistance or conductivity due to wear of the bit and/or changes in an earth formation adjacent the bit. The bit wear and/or formation changes may be displayed for an operator. | ||||||
| 94 | EARLY WEAR DETECTION | US12791377 | 2010-06-01 | US20110290560A1 | 2011-12-01 | Robert J. Buske; Mark Philip Blackman; John F. Bradford; Michael S. Damschen; Robert D. Bradshaw; Rudolf C. Pessier |
| A drill bit with a bit body having a central bore in communication with a plurality of nozzles for directing drilling fluid; a plurality of cutters defining a cutting face of the bit; and a passageway extending from the central bore toward the cutting face, such that excessive wear of the cutting face opens the passageway to allow the drilling fluid to flow therethrough, thereby reducing a surface pressure of the drilling fluid and indicating excessive wear of the bit. The passageway may extend to adjacent, or within one half inch or three inches of, the cutting face, such that excessive wear opens the passageway to the cutting face. In some cases, the passageway may actually extend through the cutting face with a plug inserted into the passageway at the cutting face to prevent the drilling fluid from exiting the passageway absent wear of the bit. | ||||||
| 95 | METHOD OF MONITORING WEAR OF ROCK BIT CUTTERS | US13188284 | 2011-07-21 | US20110283839A1 | 2011-11-24 | Sorin G. Teodorescu; Terry Hunt |
| A method of monitoring the wear of drill bits for drilling wells in earth formations, several embodiments of an improved drill bit for drilling a well in an earth formation, and methods of manufacture. In one embodiment, the bit is assembled by forming the bit, including a bit body and a plurality of cutting components; introducing a wear detector into the bit; and providing a module to monitor the wear detector and generate an indication of bit wear. The wear detector may be a witness material that may change a characteristic of at least a portion of the bit. The module may detect when the witness material is separated from the bit. The wear detector may be introduced during or after formation of the bit. The bit wear may be displayed for an operator. | ||||||
| 96 | Methods and apparatuses for estimating drill bit condition | US12391665 | 2009-02-24 | US08028764B2 | 2011-10-04 | Sorin Gabriel Teodorescu |
| A drill bit for drilling subterranean formations includes a bit body bearing at least one gage pad and a shank extending from the bit body. An annular chamber is formed within the shank. A data evaluation module is disposed in the annular chamber and includes a processor, a memory, and a communication port. The data evaluation module estimates a gage pad wear by periodically sampling a tangential accelerometer and a radial accelerometer disposed in the drill bit. A history of the tangential acceleration and the radial acceleration is analyzed to determine a revolution rate, gage-slipping periods, and gage-cutting periods. A change in a gage-pad-wear state is estimated responsive to an analysis of the revolution rate, the at least one gage-cutting period and the at least one gage-slipping period. The determination of the gage-pad-wear state may also include analyzing a formation hardness. | ||||||
| 97 | Drag bit with utility blades | US12201516 | 2008-08-29 | US07926596B2 | 2011-04-19 | Yuelin Shen; Youhe Zhang |
| A drill bit comprises a bit body and a plurality of cutting blades extending radially from the bit body, the plurality of cutting blades further comprising cutting elements disposed thereon. The drill bit also comprises a plurality of utility blades extending radially from the bit body, the plurality of utility blades being free of cutting elements. | ||||||
| 98 | Wear indicators for expandable earth boring apparatus | US12129540 | 2008-05-29 | US07770664B2 | 2010-08-10 | Tommy Laird; Gordon Whipple |
| An expandable underreamer apparatus disposed on a distal end of a drillstring and configured to drill a formation includes a substantially tubular main body adjacent a cutting head, the main body providing at least one axial recess configured to receive an arm assembly, and the arm assembly configured to translate between a retracted position and an extended position. The apparatus further includes a plurality of cutting elements disposed on the arm assembly, and a plurality of wear indicators imbedded in at least one arm assembly and positioned behind the cutting elements with respect to a direction of rotation of the arm assembly, wherein the wear indicators are configured to provide an increased torque to the drillstring upon contacting the formation. | ||||||
| 99 | REAL TIME DULL GRADING | US12332107 | 2008-12-10 | US20100139987A1 | 2010-06-10 | Terry HUNT; Sorin G. Teodorescu |
| A method of monitoring the wear of drill bits for drilling wells in earth formations, several embodiments of an improved drill bit for drilling a well in an earth formation, and methods of manufacture. In one embodiment, the bit is assembled by forming the bit, including a bit body and a plurality of cutting components; introducing a wear detector into the bit; and providing a module to monitor the wear detector and generate an indication of bit wear. The wear detector may be one or more electrical circuits that may experience a change in resistance or conductivity due to wear of the bit. The module may determine wear by detecting an open circuit. The wear detector may be introduced during or after formation of the bit. The bit wear may be displayed for an operator. | ||||||
| 100 | METHOD OF MONITORING WEAR OF ROCK BIT CUTTERS | US12327925 | 2008-12-04 | US20100139975A1 | 2010-06-10 | Sorin G. TEODORESCU; Terry HUNT |
| A method of monitoring the wear of drill bits for drilling wells in earth formations, several embodiments of an improved drill bit for drilling a well in an earth formation, and methods of manufacture. In one embodiment, the bit is assembled by forming the bit, including a bit body and a plurality of cutting components; introducing a wear detector into the bit; and providing a module to monitor the wear detector and generate an indication of bit wear. The wear detector may be a witness material that may change a characteristic of at least a portion of the bit. The module may detect when the witness material is separated from the bit. The wear detector may be introduced during or after formation of the bit. The bit wear may be displayed for an operator. | ||||||
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