| 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 | Downhole abrading tools having excessive wear indicator | US11480169 | 2006-06-30 | US20080000634A1 | 2008-01-03 | 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. | ||||||
| 222 | Method and system for predicting performance of a drilling system for a given formation | US10669105 | 2003-09-23 | US07261167B2 | 2007-08-28 | 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 is disclosed. The method generates a geology model of a given formation. The geology model includes a geology characteristic of the given formation per unit depth. The method also determines a predicted drilling performance for a proposed drilling equipment based on the geology model and specification data of the proposed drilling equipment, wherein the specification data of the proposed drilling equipment is a function of the geology characteristic. | ||||||
| 223 | Iterative drilling simulation process for enhanced economic decision making | US10607900 | 2003-06-27 | US07085696B2 | 2006-08-01 | 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. | ||||||
| 224 | Method and apparatus for monitoring and recording of the operating condition of a downhole drill bit during drilling operations | US10405576 | 2003-04-01 | US07066280B2 | 2006-06-27 | 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 for use in drilling operations in a wellbore comprising a bit body including a plurality of bit legs, each supporting a rolling cone cutter, a lubrication system for a rolling cone cutter, at least one lubrication sensor for monitoring at least one condition of said lubricant during drilling operations, and an electronics member in the bit body for recording data obtained form said lubrication sensor. | ||||||
| 225 | Wear indication apparatus and method | US11120655 | 2005-05-02 | US20060099885A1 | 2006-05-11 | Gerald Lynde; John Davis |
| Apparatus and method for monitoring the wear of a downhole tool, and providing indication of the degree of wear to an operator at the well surface. A pressurized fluid path within the cutting element matrix can exhibit a pressure drop when wear of the matrix progresses into the fluid path, or rotating torque can exhibit a drop when wear of the matrix progresses to wear pads within the cutting element matrix. Other wear indicators can also be built into the cutting element matrix. Progression of wear down to the indicator can be directly measured at the well surface, or relayed to the surface via a downhole communication system. | ||||||
| 226 | Method of assaying downhole occurrences and conditions | US10133078 | 2002-04-26 | US07035778B2 | 2006-04-25 | William A. Goldman; Lee Morgan Smith |
| A method of assaying work of an earth boring bit of a given size and design including establishing characteristics of the bit of given size and design. The method further includes simulating a drilling of a hole in a given formation as a function of the characteristics of the bit of given size and design and at least one rock strength of the formation. The method further includes outputting a performance characteristic of the bit, the performance characteristic including a bit wear condition and a bit mechanical efficiency determined as a function of the simulated drilling. | ||||||
| 227 | Method and system for predicting performance of a drilling system for a given formation | US10669105 | 2003-09-23 | US20040182606A1 | 2004-09-23 | William A. Goldman; Oliver Matthews III; William W. King; Gary E. Weaver; Gerad 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 is disclosed. The method generates a geology model of a given formation. The geology model includes a geology characteristic of the given formation per unit depth. The method also determines a predicted drilling performance for a proposed drilling equipment based on the geology model and specification data of the proposed drilling equipment, wherein the specification data of the proposed drilling equipment is a function of the geology characteristic. | ||||||
| 228 | Method and apparatus for monitoring and recording of the operating condition of a downhole drill bit during drilling operations | US10405576 | 2003-04-01 | US20040069539A1 | 2004-04-15 | 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 for use in drilling operations in a wellbore comprising a bit body including a plurality of bit legs, each supporting a rolling cone cutter, a coupling member formed at an upper shank portion of said bit body, at least one sensor for monitoring at least one condition of said improved drill bit during drilling operations, and an electronics bay portion defined in-part by said upper shank portion of said bit body for housing at least one monitoring circuit. | ||||||
| 229 | Leadless sub assembly for downhole detection system | US10040294 | 2001-10-26 | US06712160B1 | 2004-03-30 | Roger L. Schultz; Orlando De Jesus; Andrew J. Osborne, Jr. |
| A drill string is equipped with a down hole sub assembly which contains sensors to detect equipment condition during drilling. The sub assembly has no electrical communication with the drill bit itself, and the sensors detect drill bit condition from vibrations or strain or other detectable phenomena. Sensors in the bit itself are not needed. | ||||||
| 230 | Spectral power ratio method and system for detecting drill bit failure and signaling surface operator | US10040927 | 2001-10-26 | US06681633B2 | 2004-01-27 | Roger L. Schultz; Orlando De Jesus; Andrew J. Osborne, Jr. |
| An apparatus and method for monitoring and reporting downhole bit failure. Sensors are located on a sub assembly (which is separate from the drill bit itself but located above it on the drill string). Data from the sensors (preferably accelerometers) are collected in blocks, then analyzed in the frequency domain. The frequency domain is divided into multiple bands, and the signal power in each band is compared to that of another band to produce a ratio of powers. When a bit is operating at normal condition, most of the spectral energy of the bit vibration is found in the lowest frequency band. As a bearing starts to fail, it produces a greater level of vibration in the higher frequency bands. This change in ratios is used to determine probable bit failure. Bit failure can be indicated by a given ratio surpassing a given threshold, or by monitoring the standard deviation of the frequency ratios. When the standard deviation exceeds a certain value, a failure is indicated. | ||||||
| 231 | Iterative drilling simulation process for enhanced economic decision making | US10607900 | 2003-06-27 | US20040000430A1 | 2004-01-01 | 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. | ||||||
| 232 | Roller bit rearing wear detection system and method | US09934436 | 2001-08-21 | US06631772B2 | 2003-10-14 | Yuri A. Palaschenko |
| A system and method for detecting the wear of a roller bit bearing between a roller drill bit body and a roller bit rotatably attached to the roller drill bit body. A valve-plug is placed between the roller drill bit body and roller bit such that the valve-plug is removably fitted in a drilling fluid outlet in the roller drill bit body, and the valve-plug extends into a channel in the roller bit whereby uneven rotation or vibration of the roller bit causes the valve-plug to impact the sides of the channel which removes the valve-plug from the drilling fluid outlet to cause drilling fluid to flow through the drilling fluid outlet. The drop in pressure from the drilling fluid flowing through the drilling fluid outlet indicates that the roller bit is worn and may fail. | ||||||
| 233 | Mean strain ratio analysis method and system for detecting drill bit failure and signaling surface operator | US10035350 | 2001-10-26 | US20020139581A1 | 2002-10-03 | Roger L. Schultz; Orlando De Jesus; Andrew J. Osborne JR. |
| An apparatus and method for monitoring and reporting downhole bit failure. Sensors are located on a sub assembly (which is separate from the drill bit itself but located above it on the drill string). Strain measurements are taken from the sensors to detect changes in induced bending and axial stresses which are related to a roller cone bearing failure. As a cone begins to fail, the average share of the total load on the bit that the failing cone can support changes, which causes a change in the bending strain induced by the eccentric loading of the cone. | ||||||
| 234 | Roller bit rearing wear detection system and method | US09934436 | 2001-08-21 | US20020092680A1 | 2002-07-18 | Yuri A. Palaschenko |
| A system and method for detecting the wear of a roller bit bearing between a roller drill bit body and a roller bit rotatably attached to the roller drill bit body. A valve-plug is placed between the roller drill bit body and roller bit such that the valve-plug is removably fitted in a drilling fluid outlet in the roller drill bit body, and the valve-plug extends into a channel in the roller bit whereby uneven rotation or vibration of the roller bit causes the valve-plug to impact the sides of the channel which removes the valve-plug from the drilling fluid outlet to cause drilling fluid to flow through the drilling fluid outlet. The drop in pressure from the drilling fluid flowing through the drilling fluid outlet indicates that the roller bit is worn and may fail. | ||||||
| 235 | Iterative drilling simulation process for enhanced economic decision making | US09820242 | 2001-03-28 | US20010042642A1 | 2001-11-22 | 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. | ||||||
| 236 | Method of assaying downhole occurrences and conditions | US48360 | 1998-03-26 | US6131673A | 2000-10-17 | 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. | ||||||
| 237 | Method and system for predicting performance of a drilling system for a given formation | US192389 | 1998-11-13 | US6109368A | 2000-08-29 | William A. Goldman; Lee Morgan Smith; Oliver Mathews, III; Kambiz Arab; William W. King; Kelley M. Murrell; Gary E. Weaver |
| 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. The geology characteristic includes at least rock strength. The specifications includes 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. | ||||||
| 238 | Method and apparatus for monitoring and recording of operating conditions of a downhole drill bit during drilling operations | US760122 | 1996-12-03 | US5813480A | 1998-09-29 | Theodore Edward Zaleski, Jr.; Scott Ray Schmidt |
| The present invention is directed to an improved method and apparatus for monitoring and recording of operating conditions of a downhole drill bit during drilling operations. The invention may be alternatively characterized as either (1) an improved downhole drill bit, or (2) a method of monitoring at least one operating condition of a downhole drill bit during drilling operations in a wellbore, or (3) a method of manufacturing an improved downhole drill bit. When characterized as an improved downhole drill bit, the present invention includes (1) an assembly including at least one bit body, (2) a coupling member formed at an upper portion of the assembly, (3) at least one operating conditioning sensor carried by the improved downhole drill bit for monitoring at least one operating condition during drilling operations, and (4) at least one memory means, located in and carried by the drill bit body, for recording in memory data pertaining to the at least one operating condition. Optionally, the improved downhole drill bit of the present invention may cooperate with a communication system for communicating information away from the improved downhole drill bit during drilling operations, preferably ultimately to a surface location. The improved downhole drill bit of the present invention may further include a processor member, which is located in and carried by the drill bit body, for performing at least one predefined analysis of the data pertaining to the at least one operating condition, which has been recorded by the at least one memory means. | ||||||
| 239 | Method of assaying downhole occurrences and conditions | US621411 | 1996-03-25 | US5794720A | 1998-08-18 | Lee Morgan Smith; William A. Goldman |
| 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 and recording the distance between the initial and terminal points. 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. | ||||||
| 240 | Method of testing the lifeline of coiled tubing | US638065 | 1996-04-25 | US5767671A | 1998-06-16 | Terry H. McCoy; Charles F. VanBerg, Jr. |
| To test coiled tubing, at least one test is performed on a coiled tubing that has been used, such as in an oil or gas well. Performing such test includes obtaining a specific output data event (e.g., a nondestructive evaluation test readout) for the used coiled tubing. The specific output data event is compared with a predetermined sequence of output data events (e.g., a collection of data defining a "lifeline" for the coiled tubing) for determining where the sequence and the specific output data event correspond. A coiled tubing status indication is generated in response to where the specific output data event corresponds with the sequence as a measure of a point in the useful life of the used coiled tubing. | ||||||
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