| 序号 | 专利名 | 申请号 | 申请日 | 公开（公告）号 | 公开（公告）日 | 发明人 |
|---|---|---|---|---|---|---|
| 101 | Downhole Drilling Vibration Analysis | US12570015 | 2009-09-30 | US20100082256A1 | 2010-04-01 | 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. | ||||||
| 102 | METHOD AND SYSTEM FOR TRACKING LUBRICANT LEAKAGE FROM DOWNHOLE DRILLING EQUIPMENT | US12133984 | 2008-06-05 | US20090301778A1 | 2009-12-10 | Michael Robert Taylor |
| A method of detecting leakage from a drilling tool comprising putting at least one transmitter (110) in lubricant within the tool (26) and scanning for the transmitter (120) with a receiver (120) at the surface or in a downhole measurement and communications system (25). If the transmitter (110) is detected, then one can deduce that the lubricant has leaked from the tool (26). The method therefore provides an early warning of potential or impending tool failure. | ||||||
| 103 | WEAR INDICATORS FOR EXPANDABLE EARTH BORING APPARATUS | US12129540 | 2008-05-29 | US20090294173A1 | 2009-12-03 | 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. | ||||||
| 104 | Downhole abrading tools having fusible material and uses therefor | US12156150 | 2008-05-30 | US07600581B2 | 2009-10-13 | Yang Xu; Gerald Lynde |
| A downhole abrading tool has a body with a first end for connection to a drill string, a cutting end, a drilling fluid passageway, and a fusible material disposed within the body. The fusible material is capable of igniting and combusting in response to a selected temperature increase due to excessive wear on the cutting end. Combustion of the fusible material provides an indication to an operator of the downhole abrading tool of the excessive wear on the cutting end of the downhole abrading tool so that the downhole abrading tool can be removed from the well and replaced. The indication to the operator of the downhole abrading tool can be a temperature change or a pressure change in a drilling fluid flowing through the drilling fluid passageway. | ||||||
| 105 | Downhole abrading tools having excessive wear indicator | US12315732 | 2008-12-05 | US07575070B2 | 2009-08-18 | Sean L. Gaudette; Yang Xu; Gerald Lynde |
| A downhole abrading tool having a body with a first end for connection to a drill string, a cutting end, a drilling fluid passageway, a restrictor disposed within drilling fluid passageway, and an indicator chamber is disclosed. Upon exposure of the indicator chamber to a well environment due to excessive wear on the cutting end, the restrictor is actuated. Actuation of the restrictor restricts the flow of drilling fluid from the drilling fluid passageway into the well environment. The restriction of flow of drilling fluid from the drilling fluid passageway causes a pressure increase in the drilling fluid flowing through the well that can detected by an operator of the downhole abrading tool. The pressure increase provides an indication to the operator of excessive wear on the cutting end of the downhole abrading tool so that the downhole abrading tool can be removed from the well and replaced. | ||||||
| 106 | Downhole abrading tools having a hydrostatic chamber and uses therefor | US11479231 | 2006-06-30 | US07424910B2 | 2008-09-16 | Yang Xu; Gerald Lynde |
| A downhole abrading tool has a body with a first end for connection to a drill string, a cutting end, an exterior surface, a drilling fluid passageway, a valve, and a chamber. Upon exposure of the chamber to a wellbore fluid pressure due to excessive wear on the cutting end, the valve opens. The opening of the valve permits drilling fluid to flow from the drilling fluid passageway, through the exterior surface and into the wellbore. The flow of drilling fluid through the exterior surface causes a pressure drop that is detected at the surface by an operator of the downhole abrading tool. The valve movement may also cause the release of taggants, or indicators, into the drilling fluid that may also be detected by the operator, either visually or with the aid of detection equipment. | ||||||
| 107 | Method and system for predicting performance of a drilling system for a given formation | US11215673 | 2005-08-30 | US07357196B2 | 2008-04-15 | William A. Goldman; Oliver Matthews, III; William W. King; Gary E. Weaver; Gerald L. Pruitt |
| A method and apparatus for predicting the performance of a drilling system for the drilling of a well bore in a given formation includes generating a geology characteristic of the formation per unit depth according to a prescribed geology model, obtaining specifications of proposed drilling equipment for use in the drilling of the well bore, and predicting a drilling mechanics in response to the specifications as a function of the geology characteristic per unit depth according to a prescribed drilling mechanics model. Responsive to a predicted drilling mechanics, a controller controls a parameter in the drilling of the well bore. The geology characteristic includes at least rock strength. The specifications include at least a bit specification of a recommended drill bit. Lastly, the predicted drilling mechanics include at least one of bit wear, mechanical efficiency, power, and operating parameters. A display is provided for generating a display of the geology characteristic and predicted drilling mechanics per unit depth, including either a display monitor or a printer. | ||||||
| 108 | Downhole abrading tool having a taggant injection assembly for indicating excessive wear | US11496663 | 2006-07-31 | US20080000691A1 | 2008-01-03 | Gerald Lynde; Darrin L. Willauer |
| A downhole abrading tools has a body with a first end for connection with a rotating component of a drill string and a cutting end for rotation in unison with the body. The downhole abrading tool also includes a passage through the tool for circulating a drilling fluid. Disposed within the drilling fluid passageway is a taggant injection assembly having one or more taggants disposed therein that facilitates injection of taggants into the drilling fluid upon the cutting end experience excessive wear. The taggants are then transported to the surface location along with the drilling fluid for detection by the operator of the downhole abrading tool. | ||||||
| 109 | Downhole abrading tool having taggants for indicating excessive wear | US11479606 | 2006-06-30 | US20080000690A1 | 2008-01-03 | Gerald Lynde |
| A downhole abrading tools has a body with a first end for connection with a rotating component of a drill string, and a cutting end for rotation in unison with the body, the cutting end having an abrading matrix containing an abrasive material for rotating engagement with an object within the well. The downhole abrading tool also includes a passage through the tool for circulating a drilling fluid. The abrading matrix includes at least one taggant embedded within the abrading matrix capable of being released by the abrading matrix into the downhole location due to wear on the abrasive material and transported to the surface location along with the drilling fluid for detection. When the taggant is released due to excessive wear, the taggant is carried from the downhole location in the well to the surface of the well where it can be detected by the operator of the tool. | ||||||
| 110 | Roller bits with bearing failure indication, and related methods, systems, and methods of manufacturing | US09934075 | 2001-08-21 | US06725947B2 | 2004-04-27 | Yuri A. Palaschenko; Raul A. Miglierini |
| A rotary drill bit includes a bit body that includes a plurality of upright legs that terminate in an exterior bearing surface. At least one roller cutter is affixed to a corresponding exterior bearing surface of one of the plurality of legs. The roller cutter has an exterior cutting surface and a base edge and defines an interior bearing surface that is complementary to a corresponding exterior bearing surface. At least one duct is defined by the lower surface of the lateral wall and is adjacent to at least one exterior bearing surface. A plug is disposed in the duct at a distance from the base edge one of the roller cutters so that if either the interior bearing surface or the exterior bearing surface wears beyond a threshold, the plug will cause a remotely-sensible indication of excessive bearing wear to be asserted. | ||||||
| 111 | Method of assaying downhole occurrences and conditions | US10668788 | 2003-09-23 | US20040059554A1 | 2004-03-25 | William A. Goldman; Lee Morgan Smith |
| A method for determining bit wear in a drill bit of a drilling rig system is disclosed. The method provides a first drill bit design. The first drill bit design having a first geometry. The method also generates a geological model of given formation. The geological model including a geological characteristic based on a length of formation drilled in a given amount of time. The method predicts the first wear rate of the first drill bit design based on the first geometry compared to the geological model for the length of formation drilled. | ||||||
| 112 | Method of assaying downhole occurrences and conditions | US10133078 | 2002-04-26 | US20030187582A1 | 2003-10-02 | William A. Goldman; Lee Morgan Smith |
| A method of assaying work of an earth boring bit of a given size and design comprises the steps of drilling a hole with the bit from an initial point to a terminal point. A plurality of electrical incremental actual force signals are generated, each corresponding to a force of the bit over a respective increment of the distance between the initial and terminal points. A plurality of electrical incremental distance signals are also generated, each corresponding to the length of the increment for a respective one of the incremental actual force signals. The incremental actual force signals and the incremental distance signals are processed to produce a value corresponding to the total work done by the bit in drilling from the initial point to the terminal point. Using such a basic work assay, a number of other downhole occurrences and/or conditions can be assayed. These include a wear rating for the type of bit, a determination of whether such a bit can drill a given interval of formation, and assessment of the abrasivity of rock drilled (which in turn can be used to modify the assays of other conditions and/or occurrences), a model of the wear of such a bit in current use, and a determination of the mechanical efficiency of the bit. | ||||||
| 113 | Method and apparatus for monitoring and recording of the operating condition of a downhole drill bit during drilling operations | US09702921 | 2000-10-27 | US06571886B1 | 2003-06-03 | Eric Charles Sullivan; Theodore Edward Zaleski, Jr.; Scott Ray Schmidt; Don Quy Nguyen; Glenn R. Zadrapa; Timothy K. Marvel; Daniel E. Ruff |
| An improved drill bit includes a bit body, a coupling member formed at an upper shank portion. It further includes at least one sensor for monitoring at least one condition of the bit during drilling operations. In one embodiment the at least one sensor is a capacitor disposed in a lubrication pathway. An electronics bay is defined in-part by the upper shank portion. It houses at least one monitoring circuit. A battery cavity is disposed in at least one of the bit legs. A battery cavity cap is provided. A seal is provided to seal the battery cavity cap at the bit leg to define a fluid tight battery cavity. | ||||||
| 114 | Method and apparatus for monitoring and recording of the operating condition of a downhole drill bit during drilling operations | US09777332 | 2001-02-06 | US06543312B2 | 2003-04-08 | Eric Charles Sullivan; Theodore Edward Zaleski, Jr.; Scott Ray Schmidt; Don Quy Nguyen; Glenn R. Zadrapa; Chih Lin |
| A drill bit for use in drilling operations in a wellbore, the drill bit having a bit body including a plurality of bit legs, each supporting a rolling cone cutter; a coupling member formed at an upper portion of the bit body; at least one temperature sensor for monitoring at least one temperature condition of the improved drill bit during drilling operations; and at least one temperature sensor cavity formed in the bit body and adapted for receiving, carrying, and locating the at least one temperature sensor in a particular position relative to the bit body which is empirically determined to optimize temperature sensor discrimination. | ||||||
| 115 | Failure indicator for rolling cutter drill bit | US09682165 | 2001-07-30 | US06484824B2 | 2002-11-26 | Lane P. Skyles |
| A bearing failure indicator for sealed and lubricated rolling cutter earth boring drill bits is disclosed. A plurality of cutting inserts, arranged in a plurality of rows, are secured in the rolling cone cutters. At least two of the rolling cone cutters are intermeshing cutters, arranged such that they have intermeshing rows of cutting inserts. A groove is formed in the intermeshing cutters with a row containing a plurality of generally flat top bearing inserts. In the normal operation of the drill bit, the rows of generally flat top bearing inserts do not contribute to the drilling action of the drill bit. However, when a bearing assembly fails in operation, the generally flat top bearing inserts engage the intermeshing rows of inserts in the adjacent intermeshing cutter causing the drilling torque to increase and thereby providing a signal indicating the bearing has failed. | ||||||
| 116 | Differential sensor measurement method and apparatus to detect a drill bit failure and signal surface operator | US10040304 | 2001-10-26 | US20020148644A1 | 2002-10-17 | Roger L. Schultz; Orlando De Jesus; Andrew J. Osborne JR. |
| An apparatus and accompanying method for monitoring and reporting downhole bit failure. Individual sensors are placed on a sub which is separate from the drill bit itself, and are powered by a vibration driven power system. The sensor readings are used to compute values which represent the ratios of sensor readings on one sensor in relation to the readings of one or more other sensors. This creates a self-calibrating sensor system that accounts for changes in downhole conditions which might cause sensor readings to fluctuate, but which do not indicate failure. | ||||||
| 117 | Method and apparatus for monitoring and recording of the operating condition of a downhole drill bit during drilling operations | US09777813 | 2001-02-06 | US06419032B1 | 2002-07-16 | Eric Charles Sullivan; Theodore Edward Zaleski, Jr.; Scott Ray Schmidt; Don Quy Nguyen; Glenn R. Zadrapa; Chih Lin |
| An improved drill bit includes a condition sensor and a semiconductor memory. The condition sensor includes an electrical sensor which has an attribute which changes in response to changes in the bit condition. Monitoring and sampling circuits are utilized to record this data into the semiconductor memory. A communication system may be provided which includes a signal flow path and a selectively-actuable flow control device for controlling the signal flow path until a predetermined operating condition is detected; upon actuation, a detectable pressure change is developed in the wellbore. | ||||||
| 118 | System and method for detecting roller bit bearing wear through cessation of roller-bit rotation | US09933865 | 2001-08-21 | US20020088647A1 | 2002-07-11 | Yuri A. Palaschenko |
| A system and method for detecting the wear of a roller bit bearing on a roller drill bit body where the roller bit has a plurality of cutting elements and is rotatably attached to the roller drill bit body at the bearing. In the invention, a rotation impeder is in between the roller bit and roller drill bit body and upon uneven rotation of the roller bit which indicates that the roller bit bearing may fail, the rotation impeder impedes the rotation of the roller bit. The drill rig operator at the surface can cease drilling operations upon detection of the cessation of rotation of the roller bit. The rotation impeder can also be seated in a drilling fluid outlet and cause a detectable loss in drilling fluid pressure when dislodged to otherwise cease rotation of the roller drill bit. | ||||||
| 119 | Method of assaying downhole occurrences and conditions | US09598131 | 2000-06-21 | US06374926B1 | 2002-04-23 | William A. Goldman; Lee Morgan Smith |
| A method of assaying work of an earth boring bit of a given size and design comprises the steps of drilling a hole with the bit from an initial point to a terminal point. A plurality of electrical incremental actual force signals are generated, each corresponding to a force of the bit over a respective increment of the distance between the initial and terminal points. A plurality of electrical incremental distance signals are also generated, each corresponding to the length of the increment for a respective one of the incremental actual force signals. The incremental actual force signals and the incremental distance signals are processed to produce a value corresponding to the total work done by the bit in drilling from the initial point to the terminal point. Using such a basic work assay, a number of other downhole occurrences and/or conditions can be assayed. These include a wear rating for the type of bit, a determination of whether such a bit can drill a given interval of formation, and assessment of the abrasivity of rock drilled (which in turn can be used to modify the assays of other conditions and/or occurrences), a model of the wear of such a bit in current use, and a determination of the mechanical efficiency of the bit. | ||||||
| 120 | Failure indicator for rolling cutter drill bit | US09682165 | 2001-07-30 | US20020023783A1 | 2002-02-28 | Lane P. Skyles |
| A bearing failure indicator for sealed and lubricated rolling cutter earth boring drill bits is disclosed. A plurality of cutting inserts, arranged in a plurality of rows, are secured in the rolling cone cutters. At least two of the rolling cone cutters are intermeshing cutters, arranged such that they have intermeshing rows of cutting inserts. A groove is formed in the intermeshing cutters with a row containing a plurality of generally flat top bearing inserts. In the normal operation of the drill bit, the rows of generally flat top bearing inserts do not contribute to the drilling action of the drill bit. However, when a bearing assembly fails in operation, the generally flat top bearing inserts engage the intermeshing rows of inserts in the adjacent intermeshing cutter causing the drilling torque to increase and thereby providing a signal indicating the bearing has failed. | ||||||
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