| 序号 | 专利名 | 申请号 | 申请日 | 公开（公告）号 | 公开（公告）日 | 发明人 |
|---|---|---|---|---|---|---|
| 121 | Wear indicator for rotary drilling tools | US09183504 | 1998-10-30 | US06167833A | 2001-01-02 | Douglas Bruce Caraway; Tony Martin Watts; Douglas Alan Patton; David Martin Nguyen |
| A wear indicator is provided for a rotary drilling tool of the type which comprises a bit body having a leading surface for cutting, abrading or reaming a hole in a target substrate material such as a sub-surface formation, the wear indicator comprising or including one or more discrete areas of a visually distinct material to that from which the drilling tool is mainly composed, the visually distinct material being arranged or configured at or adjacent the surface of the bit such that progressive wear of the bit and hence the or each visually distinct discrete area provides a visual indication of surface wear of the tool. | ||||||
| 122 | Method for monitoring the wear of a rotary type drill bit | US287640 | 1988-12-20 | US4926950A | 1990-05-22 | Djurre H. Zijsling |
| A rotary drill bit is provided with cutting elements having a front layer of interbonded abrasive particles, such as synthetic diamonds, which layer has a thickness that varies with distance from the bit body. The characteristic relation thus obtained between bit agressiveness and bit wear can be used to monitor the bit wear condition during drilling. | ||||||
| 123 | Downhole vibration monitoring of a drillstring | US166897 | 1988-03-11 | US4903245A | 1990-02-20 | David A. Close; Steven C. Owens; Trevor K. C. Pugh |
| Apparatus for monitoring vibration of a bottom hole assembly used to drill a well includes at least one accelerometer mounted in the bottom hole assembly to generate data in the form of electrical signals corresponding to the acceleration experienced by the assembly. The computer in the assembly is programmed to collect data from the accelerometer and compute magnitude of the assembly acceleration. Means are provided for selecting from the collected data a value which exceeds a preset level. In one form, when the collected data has a value above a preset level, an alarm signal is sent to the surface so corrective measures can be taken to prevent damage to downhole equipment. | ||||||
| 124 | Wellbore tool with hall effect coupling | US276722 | 1988-11-28 | US4884071A | 1989-11-28 | Mig A. Howard |
| The present invention is an improved wellbore tool for coupling to a drill string at a threaded junction and adapted for use in a wellbore during drilling. A sensor is disposed in the wellbore tool for sensing a condition and producing a data signal corresponding to the condition. A self-contained power supply is disposed in the wellbore tool and coupled to the sensor for providing power to the sensor as required. The Hall Effect coupling transmitter means is carried by the sensor and for transmitting data from the Hall Effect coupling transmitter means to a Hall Effect coupling receiver carried by the drill string and disposed across the threaded junction from the wellbore tool, wherein data is transmitted across the threaded junction without requiring an electrical connection at the threaded junction. | ||||||
| 125 | Drill bit with wear indicating feature | US166593 | 1988-03-10 | US4785895A | 1988-11-22 | Albert P. Davis, Jr.; Joseph W. Stolle |
| An earth drilling bit incorporating a tensioned linkage type bit wear indicator. A tensioned linkage extends through the bit between a wear sensor and a device for altering the resistance of the bit to receiving drilling fluid from the drill string. On detecting a predetermined degree of wear, the wear sensor releases the tension in the tensioned linkage. This activates the flow resistance altering device, causing the flow rate and/or pumping pressure of the drilling fluid to change. The tensioned linkage passes through two intersecting passageways in the bit. A guide element is inserted at the intersection of the two intersecting passageways. The guide element routes the tensioned linkage between the two passageways. | ||||||
| 126 | Method of analyzing vibrations from a drilling bit in a borehole | US901073 | 1986-08-28 | US4773263A | 1988-09-27 | Marc Lesage; Michael Sheppard |
| Information on tooth wear is obtained from the frequency distribution spectrum of a vibrational quantity influenced by the impact of cutter teeth on the bottom of a bore. For example, spectra may be obtained from the product of signals indicative of torque and torsional acceleration. Tooth wear is then indicated by the shift upwardly in frequency of peaks in the spectra. Other quantities which may be used, singly or together to enhance spectral information, are weight on bit, vertical acceleration, transverse acceleration, standpipe pressure. Abrupt changes in frequency distribution curves indicate abrupt occurrences such as broken teeth or stuck cones. A stuck cone is also indicated by unidirectional peaks in a plot of torsional acceleration against time. | ||||||
| 127 | Changeover bit for extended life, varied formations and steady wear | US839415 | 1986-03-14 | US4690228A | 1987-09-01 | Dieter Voelz; Roland Illerhaus |
| A roller cone bit may be used as a rotating drag bit by treating the roller cones as carriers for a plurality of distinguishable types of drag cutters. The roller cones are each coupled to a mechanism which selectively allows rotation of the roller cones. The roller cones are otherwise fixed and as the bit is rotated, the drag cutters are brought into engagement with the rock. However, where the roller cones are selectively allowed to rotate, rotation of the drag bit rotates the roller cones to bring a second set of drag cutters into a configuration for cutting the rock formation. A mechanism then selectively locks the roller cones to prevent further rotation, keeping the second set of drag cutters fixed in place. By selectively permitting and preventing rotation of the roller cones, a plurality of sets of drag cutters can be brought into a configuration for cutting the rock. Such a drag bit may be employed to bring drag cutters selectively into play to cut different types of rock formation, or to present renewed cutters after an initial set of cutters have been worn by a predetermined degree. Furthermore, rotation of the roller cones may be slowed by application of a drag to each roller cone. The drag cutters on each roller cone will be sequentially brought into a cutting configuration with respect to the rock and wear will be evenly distributed among the drag cutters. | ||||||
| 128 | Battery powered means and method for facilitating measurements while coring | US522923 | 1983-08-12 | US4499955A | 1985-02-19 | Frank L. Campbell; Dean C. Barnum; William C. Corea |
| In accordance with the present invention, rotation of the inner barrel relative of the axis of symmetry of the core barrel (indicative of core twist off or core sand erosion during coring operations) is detected by a novel sensor combination comprising a battery-powered Hall-effect device fitted to the inner barrel imbedded in a support sleeve of a custom safety sub attached to the outer core barrel adjacent to a single signature magnet.During coring, circumferential passage of the Hall-effect device adjacent to the signature magnet (during rotation of the outer core barrel to generate a core), produces a series of signals of constant repetition rate. But with the occurrence of rotation of the inner core barrel irregular repetition intervals are produced at uphole indicating equipment connected to the Hall-effect device through conventional downhole telemetering and power generating equipment. Result: sticking and jamming of the core can be immediately detected and uphole parameters modified to ease unsafe conditions.Use of a battery pack to power the Hall-effect device, simplifies operations, especially where the present invention is used in conjunction with the MWC mud pulse telemetering equipment. | ||||||
| 129 | Well tool | US49458 | 1979-06-18 | US4260030A | 1981-04-07 | Fred K. Fox |
| There is disclosed a turbodrill wherein excessive wear on the axial thrust bearing supporting the shaft from the housing is detectable at the surface by means of an increase in the back pressure of the drilling fluid circulating through the turbine section. | ||||||
| 130 | Down hole well drilling tool with reversible thrust bearings | US849988 | 1977-11-09 | US4114704A | 1978-09-19 | William Casper Maurer; Albert Richard Sinclair; William Jesse McDonald, Jr. |
| A turbo drill which is connected to a string of drill pipe as a rotating shaft for driving a drill bit which may be a rotary bit or a high speed solid head diamond bit. The turbine section has rotor and stator blades which are cresent shaped in cross section with each blade having an exit angle of 14.degree. - 23.degree. for maximum turbine efficiency. The bearing shaft is provided with chevron rotary seals positioned below the rotary bearings carrying both radial and vertical thrust. Fluid lubricant fills the space from the rotary seals to a predetermined level above the bearings. A piston seals the lubricant chamber and is pressurized by drilling fluid (i.e. mud) flowing through the tool. A layer of lubricant fluid overlies the first piston and has a second piston covering said fluid and transmitting pressure from the drilling fluid to the lubricant fluid surrounding the bearings. A plug member in the bearing shaft is positioned to be dislodged at the low lubricant position of the first piston to provide a temporary obstruction to the flow of drilling fluid to give an indication, at the well surface, of loss of lubricant in the tubro drill. An optional feature provides for increasing the pressure drop of drilling fluid in the turbo drill to cause the vertical thrust to be carried on the bottom vertical thrust bearings, after the top vertical thrust bearings are worn, and thus extend the drilling life substantially. A further optional feature is a locking ring arrangement which prevents separation of threaded connections in the drill housing during use. | ||||||
| 131 | Method and system for determining formation porosity | US740998 | 1976-11-11 | US4064749A | 1977-12-27 | Robert W. Pittman; Chester E. Hermes |
| A method and/or system for measuring formation porosity from drilling response. It involves measuring a number of drilling parameters and includes determination of tooth dullness as well as determining a reference torque empirically. One of the drilling parameters is the torque applied to the drill string. | ||||||
| 132 | Method and apparatus for developing a surface well-drilling log | US47499474 | 1974-05-31 | US3916684A | 1975-11-04 | RUNDELL HERBERT A |
| Method or system for developing a surface drilling log indicative of one or more parameters of the formation being drilled. Measurements include the bit revolutions, the depth of the bit in the hole, the weight on the bit, and a determination of tooth dullness of the bit. The results are correlated to produce a parameter in accordance with a predetermined relationship of the measurements and the determination.
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| 133 | Method and apparatus for preventing and detecting rotary drill bit failure | US45180074 | 1974-03-18 | US3913686A | 1975-10-21 | MANSON JR CHARLES D |
| Methods and apparatus for preventing the failure of a rotary drill bit as a result of the roller cutters thereof becoming jammed when drilling out disposable materials blocking a string of conduit. A drillable core which includes an abutment formed therein for engaging the roller cutters of the drill bit is provided in the string of conduit below the disposable materials.
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| 134 | Method op determining downhole occurences in well drilling using rotary torque oscillation measurements | US38195673 | 1973-07-23 | USRE28436E | 1975-06-03 | |
| 1.THE METHOD OF DETERMINING BIT DAMAGE IN ROTARY DRILLING COMPRISING ROTATING A DRILL STRING HAVING A BIT ATTACHED THERETO IN A HOLE AND MONITORING THE ROTARY TORQUE FOR CHARACTERISTIC OSCILLATIONS, SAID CHARACTERISTIC OSCILLATIONS HAVING A FREQUENCY NOT MORE THAN TWICE AND NOT LESS THAN HALF THE EXPECTED FREQUENCY OF TORSIONAL OSCILLATION OF THE DRILL STRING, AND SAID CHARACTERISTIC OSCILLATIONS HAVING AN AMPLITUDE SUBSTANTIALLY IN EXCESS OF THE OSCILLATIONS PRODUCED WHILE ROTATING AN UNDAMAGED BIT.
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| 135 | Radioactive tracer system to indicate drill bit wear or failure | US28186972 | 1972-08-18 | US3818227A | 1974-06-18 | FRIES B |
| A radioactive tracer system for indicating drill bit wear or failure utilizing radioactive krypton 85 in clathrate form, in the form of water-soluble kryptonates, or dissolved in grease. Preferably the radioactive krypton is placed so that when drill bit wear or failure occurs, the radioactive krypton 85 is released and effectively becomes diffused in the circulating drilling fluid. At the surface, the radioactive krypton 85 gas is separated from the circulating drilling fluid by gas-mud separating means and is transported as a gas to a counting chamber where an accurate radioactivity count of beta rays released from the krypton is obtained. The beta rays indicate drill bit wear or failure when detected above the normal background radioactivity of the recirculating drilling fluid. The radioactive krypton may also be implanted in the teeth or other surfaces of the cones of drill bits or implanted in the shirttail or other body parts of the bit.
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| 136 | Method and apparatus for rotary drill testing | US3782190D | 1972-08-03 | US3782190A | 1974-01-01 | PITTMAN R |
| Rotary drilling method and apparatus for indicating incipient roller cone bearing failure of a bit, or similar downhole conditions. Use is made of signals representing the torque being applied and the weight on the bit, both during drilling, while a constant that is proportional to bit diameter is included in determining the ratio of torque to weight times diameter.
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| 137 | Method for detecting roller bit bearing failure | US3581564D | 1969-05-14 | US3581564A | 1971-06-01 | YOUNG FARRILE S |
| A method for detecting failure of bearings in roller drill bits used in rotary drilling. Two drilling parameters-rotary torque and drilling rate-are measured and plotted with a third parameter ( psi ) equals ratio of the parameter of rotary torque divided by the parameter of drilling rate. A sharp increase in the third parameter psi indicates bearing failure.
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| 138 | Drilling tools | US3578092D | 1966-02-11 | US3578092A | 1971-05-11 | TESCH HANS-JURGEN; HAVERKAMP GUNTHER; BECKER HERBERT; GOTTE HANS; WACKER ALEXANDER |
| A drilling tool has been provided which has a gastight cavity therein, the entrance of which cavity is preferably positioned away from a wear surface of the tool and which cavity contains krypton 85 as a wear indicating means either for a bearing wear surface or for an abrasive drilling wear surface. The indicating means are activated when, because of wear, the cavity is punctured and krypton 85 escapes or is expelled by means of auxiliary agents. The method of marking the tools as well as the tools thus marked are within the scope of the invention. Further, the improvement in the method of drilling deep bore holes with a tool possessing these indicating means is similarly within the scope of the disclosed invention.
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| 139 | Rock bit dullness indicator | US56833366 | 1966-07-27 | US3363702A | 1968-01-16 | BIELSTEIN WALTER J |
| 140 | Indicator device for bearing failures in drill bits | US2790360 | 1960-05-09 | US3062302A | 1962-11-06 | TOTH FREDERICK J; TOOMEY DAVID F |
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