| 序号 | 专利名 | 申请号 | 申请日 | 公开（公告）号 | 公开（公告）日 | 发明人 |
|---|---|---|---|---|---|---|
| 301 | COMPOSITE RETENTION FEATURE | US14094304 | 2013-12-02 | US20150044054A1 | 2015-02-12 | Peter Loftus; Adam L. Chamberlain; Ted J. Freeman |
| A retention feature for use in a gas turbine engine is disclosed herein. The retention feature includes a ceramic post, an insert, and a braze layer coupling the insert to the ceramic post. The ceramic post includes a body adapted to be coupled to a turbine engine component and a head coupled to the body. The insert is arranged in a space formed in the head and the braze layer extends from the ceramic post to the insert to bond the insert to the ceramic post. | ||||||
| 302 | FORMATION DIP GEO-STEERING METHOD | US14488079 | 2014-09-16 | US20150000980A1 | 2015-01-01 | Danny T. Williams |
| A geo-steering method for drilling a formation penetrated by multiple wells. The method comprises computing a stratigraphic target formation window, computing a target line utilizing an instantaneous formation dip angle correlated to offset well data from an offset well. The method further comprises calculating a target window from actual drilling data overlaying the target window over the stratigraphic target formation window to drill on the target line, identifying target deviation from target line using overlaid windows, generating a target deviation flag when the overlaid results differ above or below the stratigraphic target formation window or user inputted target deviation flag parameters, wherein the target deviation flag stops drilling by the rig. The method performs another actual survey, creating a new window, starting drilling, creating a new target window, overlaying the two windows and monitoring for target deviations, repeating the process until target depth is reached. | ||||||
| 303 | Drilling Advisory Systems and Methods to Filter Data | US14185833 | 2014-02-20 | US20140277752A1 | 2014-09-18 | Dar-Lon Chang; Lei Wang; Paul E. Pastusek; Jeffrey R. Bailey; Gregory S. Payette; Darren Pais |
| Integrated methods and systems for optimizing drilling related operations include recording data, parsing the data into intervals and analyzing the intervals to determine if the performance data in each time interval is of sufficient quality for using the interval data in a performance optimization process. The quality assessment may involve evaluating the data against a set of determined standards or ranges. The performance optimization process may utilize data mapping and/or modeling to make performance optimization process recommendations. | ||||||
| 304 | ROTARY STEERABLE SYSTEM FOR VERTICAL DRILLING | US13797875 | 2013-03-12 | US20140262507A1 | 2014-09-18 | Daniel Andrew Marson; Daniel Mark Sullivan; John Mackinley Pagett |
| A rotary steerable drilling system that is operable to drill vertical wellbores and automatically maintain a vertical wellbore drilling path. The system includes a control module for operating solenoid valves that control an amount of fluid pressure applied to bias pad piston/cylinders. The control module is operable to determine when the system is deviating from vertical, in what direction the system is deviating, and where the bias pads are in relation to the direction of deviation. Based on these determinations, the control module actuates the requisite bias pads by controlling the amount of fluid pressure applied to the bias pad piston/cylinders to direct the system back to the vertical drilling path. | ||||||
| 305 | Mechanical specific energy drilling system | US13442642 | 2012-04-09 | US08833487B2 | 2014-09-16 | Rudolf Ernst Krueger, IV; Philip Wayne Mock; Norman Bruce Moore |
| A mechanical specific energy downhole drilling assembly having a bottomhole assembly including drill pipe and a drill bit, a weight on bit and torque sub for sensing torque, weight on bit and revolutions per minute of the drill bit; a command and control sub for receiving input from the weight on bit and torque sub for determining instantaneous mechanical specific energy of the downhole drilling assembly and an anti-stall tool responsive to real time mechanical specific energy information from the command and control sub to adjust the weight on the drill bit to maximize rate of penetration of the drill bit. | ||||||
| 306 | METHOD AND SYSTEM FOR CONTROLLING TONGS MAKE-UP SPEED AND EVALUATING AND CONTROLLING TORQUE AT THE TONGS | US14050197 | 2013-10-09 | US20140174731A1 | 2014-06-26 | Steve Conquergood; David Lord |
| Make-up speed for a tongs drive system is monitored and controlled to maintain the speed within a limited target range either throughout the make-up process or during the final portion of the make-up process, thereby improving make-up consistency and allowing for improved evaluation or torque during the make-up process. An encoder generates speed and position data during the make-up process. The speed data is compared to a target speed, which is based on rod and/or tongs characteristics. If the speed does not match the target speed or is not within a range of the target speed, a signal is transmitted to the tongs drive to adjust the speed accordingly. Furthermore, position data from the encoder, or other position sensors, provide position data for the rod during the make-up process to limit or vary the speed control parameters during different portions of the make-up process. | ||||||
| 307 | System and method for determining incremental progression between survey points while drilling | US13530298 | 2012-06-22 | US08596385B2 | 2013-12-03 | Todd W. Benson; Teddy C. Chen |
| A system and method for surface steerable drilling are provided. In one example, the system receives toolface information for a bottom hole assembly (BHA) and non-survey sensor information corresponding to a location of the BHA in a borehole. The system calculates an amount of incremental progress made by the BHA based on the non-survey sensor information and calculates an estimate of the location based on the toolface information and the amount of incremental progress. The system repeats the steps of receiving toolface information and non-survey sensor information and calculating an amount of incremental progress to calculate an estimate of a plurality of locations representing a path of the BHA from a first survey point towards a second sequential survey point. | ||||||
| 308 | Method and apparatus for automated drilling of a borehole in a subsurface formation | US12961663 | 2010-12-07 | US08590635B2 | 2013-11-26 | William Leo Koederitz |
| A method for automated drilling of a borehole in a subsurface formation includes drilling the borehole using a set of drilling control variables assigned a set of values. An automated drilling index of the drilling is monitored. The automated drilling index of the drilling is a combination of a first index that depends on a rate of penetration of the drilling and a second index that depends on a mechanical specific energy of the drilling. The values assigned to the set of drilling control variables are selectively adjusted at least once during the drilling based on the monitoring of the automated drilling index. | ||||||
| 309 | Method and system for controlling tongs make-up speed and evaluating and controlling torque at the tongs | US12627529 | 2009-11-30 | US08590401B2 | 2013-11-26 | Steve Conquergood; David Lord |
| Make-up speed for a tongs drive system is monitored and controlled to maintain the speed within a limited target range either throughout the make-up process or during the final portion of the make-up process, thereby improving make-up consistency and allowing for improved evaluation or torque during the make-up process. An encoder generates speed and position data during the make-up process. The speed data is compared to a target speed, which is based on rod and/or tongs characteristics. If the speed does not match the target speed or is not within a range of the target speed, a signal is transmitted to the tongs drive to adjust the speed accordingly. Furthermore, position data from the encoder, or other position sensors, provide position data for the rod during the make-up process to limit or vary the speed control parameters during different portions of the make-up process. | ||||||
| 310 | Device and method of determining rate of penetration and rate of rotation | US12956394 | 2010-11-30 | US08571796B2 | 2013-10-29 | Roel Van Os; Dominique Dion; Philip Cheung |
| Methods and devices for determining a rate of penetration and/or rate of rotation for a drilling assembly or logging tool while drilling or logging a wellbore are provided. The methods can include the steps of:at respective first and second time instant, acquiring and storing a first logging data frame using a first array of sensors and a second logging data frame using a second array of sensors where wherein the logging data relate to at least one property of a zone surrounding the wellbore and the second logging data frame overlaps at least partially the first logging data frame; comparing the first and second logging data frames; determining a relative change in depth and/or azimuth between the first and second logging data frames; and calculating the rate of penetration and/or rate of rotation based on the relative change in depth and/or azimuth determined and a difference between the first and second time instants. | ||||||
| 311 | SYSTEM AND METHOD FOR DETERMINING INCREMENTAL PROGRESSION BETWEEN SURVEY POINTS WHILE DRILLING | US13530298 | 2012-06-22 | US20130161096A1 | 2013-06-27 | TODD W. BENSON; TEDDY C. CHEN |
| A system and method for surface steerable drilling are provided. In one example, the system receives toolface information for a bottom hole assembly (BHA) and non-survey sensor information corresponding to a location of the BHA in a borehole. The system calculates an amount of incremental progress made by the BHA based on the non-survey sensor information and calculates an estimate of the location based on the toolface information and the amount of incremental progress. The system repeats the steps of receiving toolface information and non-survey sensor information and calculating an amount of incremental progress to calculate an estimate of a plurality of locations representing a path of the BHA from a first survey point towards a second sequential survey point. | ||||||
| 312 | GRAPH TO ANALYZE DRILLING PARAMETERS | US13414810 | 2012-03-08 | US20120287134A1 | 2012-11-15 | Rudolf C. Pessier; Stephen Nicholas Wallace; Hatem Oueslati |
| A method for presenting drilling information includes presenting a display including a graph having a first axis and a second axis. The first axis represents a rate of penetration (ROP) of a drill bit into a borehole and the second axis representing a mechanical specific energy (MSE) of a drilling system that includes the drill bit. The method also includes plotting time based or foot based data with a computing device for one or more drilling runs on the graph and overlaying the graph with lines of constant power. | ||||||
| 313 | MECHANICAL SPECIFIC ENERGY DRILLING SYSTEM | US13442642 | 2012-04-09 | US20120261190A1 | 2012-10-18 | Rudolf Ernst Krueger, IV; Philip Wayne Mock; Norman Bruce Moore |
| A mechanical specific energy downhole drilling assembly having a bottomhole assembly including drill pipe and a drill bit, a weight on bit and torque sub for sensing torque, weight on bit and revolutions per minute of the drill bit; a command and control sub for receiving input from the weight on bit and torque sub for determining instantaneous mechanical specific energy of the downhole drilling assembly and an anti-stall tool responsive to real time mechanical specific energy information from the command and control sub to adjust the weight on the drill bit to maximize rate of penetration of the drill bit. | ||||||
| 314 | Method for predicting rate of penetration using bit-specific coefficients of sliding friction and mechanical efficiency as a function of confined compressive strength | US12137752 | 2008-06-12 | US07991554B2 | 2011-08-02 | William Malcolm Calhoun; Hector Ulpiano Caicedo; Russell Thomas Ewy |
| A method for predicting the rate of penetration (ROP) of a drill bit drilling a well bore through intervals of rock of a subterranean formation is provided based on determined relationships between a bit-specific coefficient of sliding friction μ and mechanical efficiency EFFM and confined compressive strength CCS over a range of confined compressive strengths CCS. Confined compressive strength CCS is estimated for intervals of rock through which the drill bit is to be used to drill a well bore. The rate of penetration ROP is then calculated utilizing the estimates of confined compressive strength CCS and those determined relationships. | ||||||
| 315 | Drill bit with a sensor for estimating rate of penetration and apparatus for using same | US12193332 | 2008-08-18 | US07946357B2 | 2011-05-24 | Tu Tien Trinh; Eric Sullivan; Daryl Pritchard |
| In one embodiment, an apparatus includes a drill bit, a tip on a bit body configured to contact a formation when the drill bit is utilized to cut into the formation, and a spring coupled to the tip. The apparatus also includes a sensor coupled to the spring and configured to provide signals corresponding to the displacement of the tip when the tip is in contact with the formation. | ||||||
| 316 | Method of drilling and producing hydrocarbons from subsurface formations | US11901307 | 2007-09-17 | US07857047B2 | 2010-12-28 | Stephen M. Remmert; Joseph W. Witt; Fred E. Dupriest |
| A method associated with the production of hydrocarbons. In one embodiment, method for drilling a well is described. The method includes performing drilling operations at one or more wells to a subsurface location in a field to provide fluid flow paths for hydrocarbons to a production facility. The drilling is performed by (i) obtaining mechanical specific energy (MSE) data and other measured data during the drilling operations; (ii) using the obtained MSE data and other measured data to determine the existence of at least one limiter; (iii) obtaining and examining lithology data for the well; (iv) identifying a primary limiter of the at least one limiter based on the lithology data; and (v) adjusting drilling operations to mitigate at least one of the at least limiter. | ||||||
| 317 | Method and System for Controlling Tongs Make-Up Speed and Evaluating and Controlling Torque at the Tongs | US12627529 | 2009-11-30 | US20100132180A1 | 2010-06-03 | Steve Conquergood; David Lord |
| Make-up speed for a tongs drive system is monitored and controlled to maintain the speed within a limited target range either throughout the make-up process or during the final portion of the make-up process, thereby improving make-up consistency and allowing for improved evaluation or torque during the make-up process. An encoder generates speed and position data during the make-up process. The speed data is compared to a target speed, which is based on rod and/or tongs characteristics. If the speed does not match the target speed or is not within a range of the target speed, a signal is transmitted to the tongs drive to adjust the speed accordingly. Furthermore, position data from the encoder, or other position sensors, provide position data for the rod during the make-up process to limit or vary the speed control parameters during different portions of the make-up process. | ||||||
| 318 | Method for predicting rate of penetration using bit-specific coefficients of sliding friction and mechanical efficiency as a function of confined compressive strength | US12137752 | 2008-06-12 | US20080249714A1 | 2008-10-09 | William Malcolm Calhoun; Hector Ulpiano Caicedo; Russell Thomas Ewy |
| A method for predicting the rate of penetration (ROP) of a drill bit drilling a well bore through intervals of rock of a subterranean formation is provided. The method uses an equation based upon specific energy principles. A relationship is determined between a bit-specific coefficient of sliding friction μ and confined compressive strength CCS over a range of confined compressive strengths CCS. Similarly, another relationship for the drill bit is determined between mechanical efficiency EFFM and confined compressive strength CCS over a range of confined compressive strengths CCS. Confined compressive strength CCS is estimated for intervals of rock through which the drill bit is to be used to drill a well bore. The rate of penetration ROP is then calculated utilizing the estimates of confined compressive strength CCS of the intervals of rock to be drilled and those determined relationships between the bit-specific coefficient of sliding friction μ and the mechanical efficiency EFFM and the confined compressive strengths CCS, as well as using estimated drill bit speeds N (RPM) and weights on bit (WOB). | ||||||
| 319 | Data logging | US11311609 | 2005-12-19 | US07302346B2 | 2007-11-27 | Chung Chang; Marwan Moufarrej; Sandip Bose; Tarek Habashy |
| A device and method for determining a geophysical characteristic of a borehole using at least one logging device is provided, wherein the at least one logging device includes at least one sensing device. The method includes associating the at least one sensing device with the borehole, wherein the at least one sensing device includes a sensing device measurement length. The method also includes operating the at least one sensing device to generate borehole data responsive to a borehole portion disposed essentially adjacent the sensing device measurement length, wherein the borehole data includes start time of scan, location of the at least one sensing device at start time of scan, stop time of scan and location of the at least one sensing device at stop time of scan. Furthermore, the method includes correlating the borehole data to determine the geophysical characteristic. | ||||||
| 320 | SYSTEM, METHOD AND APPARATUS FOR PETROPHYSICAL AND GEOPHYSICAL MEASUREMENTS AT THE DRILLING BIT | US11739581 | 2007-04-24 | US20070186639A1 | 2007-08-16 | Ronald Spross; Paul Rodney |
| Measurement of petrophysical and geophysical data of formations in a wellbore using a long gauge bit having at least one sensor therewith. The at least one sensor may be installed in at least one flute of the long gauge bit and/or in the long gauge portion thereof. Data for creating images of the formations are obtained at or near the bottom of the borehole and proximate to the long gauge bit used for drilling the borehole. Orientation of the long gauge bit is also available on a real time basis. Magnetic and/or gravitational sensors may be used in determining bit orientation. The flutes of the long gauge bit and the long gauge portion thereof may have standard inserts to accommodate various types of different sensors and electronic packages therefor. | ||||||
QQ群二维码
意见反馈
意见反馈