| 序号 | 专利名 | 申请号 | 申请日 | 公开（公告）号 | 公开（公告）日 | 发明人 |
|---|---|---|---|---|---|---|
| 181 | Drill bit with rate of penetration sensor | US12557004 | 2009-09-10 | US09238958B2 | 2016-01-19 | Sorin G. Teodorescu |
| An apparatus for estimating a rate-of-penetration of a drill bit is provided, which in one embodiment includes a first sensor positioned on a drill bit configured to provide a first measurement of a parameter at a selected location in a formation at a first time, and a second sensor positioned spaced a selected distance from the first sensor to provide a second measurement of the parameter at the selected location at a second time when the drill bit travels downhole. The apparatus may also include a processor configured to estimate the rate-of-penetration using the selected distance and the first and second times. | ||||||
| 182 | EXCAVATION STATUS MONITORING SYSTEM FOR TUNNELING MACHINE | US14649715 | 2013-11-12 | US20150300152A1 | 2015-10-22 | Katsuya SASAKI; Keitaro HIDANI; Kohei TAKATORI; Takuya MIWA |
| An excavation status monitoring system for a tunneling machine that includes a detecting portion mounted on a cutter head of the tunneling machine, including an accelerometer that detects a vibration or an acoustic sensor that detects a sound wave and a sound output portion that outputs a signal detected by the detecting portion as sound. | ||||||
| 183 | Method and System for Prioritizing and Allocating Well Operating Tasks | US14682056 | 2015-04-08 | US20150294258A1 | 2015-10-15 | Ginger Hildebrand; Chunling Gu Coffman |
| A method for managing well construction operations includes accepting as input to a computer a list of tasks required to complete construction of at least one wellbore, the list of tasks having at least an initial chronological order. Measurements of at least one parameter related to at least one task on the list of tasks is entered into the computer. The list of tasks is prioritized by at least one of changing a chronological order of performance or a length of time to complete at least one of the tasks based on measurements of the at least one parameter. The prioritizing is performed to optimize at least one well construction performance parameter. The prioritized list is displayed to at least one user of the computer. | ||||||
| 184 | SYSTEM AND METHOD FOR DETECTING VIBRATIONS USING AN OPTO-ANALYTICAL DEVICE | US14424778 | 2012-08-31 | US20150247398A1 | 2015-09-03 | 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 detecting vibrations associated with drilling the wellbore based on the received electromagnetic radiation. | ||||||
| 185 | AUTOMATED RATE OF PENETRATION OPTIMIZATION WHILE MILLING | US14630857 | 2015-02-25 | US20150247396A1 | 2015-09-03 | Gokturk Tunc; Ashley Bernard Johnson; Anurag Sharma; Alan Fairweather; Walter David Aldred |
| A method for automating a downhole milling process includes receiving an input stream from at least one sensor within a downhole milling system, and segmenting the input stream. A safe operating envelope is identified based on segments of the input stream and models for the segments. At least one parameter of the milling system is then automatically changed along a path of optimal rate of penetration while remaining within the safe operating envelope. In some embodiments, an input stream may include surface pressure and the safe operating envelope may include swarf transport conditions. | ||||||
| 186 | ESTIMATING AND PREDICTING WELLBORE TORTUOSITY | US14368313 | 2013-08-30 | US20150226052A1 | 2015-08-13 | Robello Samuel; Gustavo A. Urdaneta |
| Estimating and predicting wellbore tortuosity. At least some of the illustrative embodiments are methods including: receiving, by a computer system, an indication of rotational drilling time and slide drilling time for a wellpath; calculating a value indicative of tortuosity for the wellpath based on the indication of rotational drilling time and slide drilling time for the wellpath; determining, by the computer system, that the wellpath exceeds a tortuosity threshold, the determining based on the value indicative of tortuosity; and changing a drilling parameter regarding the wellpath responsive to determining that the wellpath exceeds the tortuosity threshold. | ||||||
| 187 | Monitor and control of directional drilling operations and simulations | US12442637 | 2007-09-27 | US09103195B2 | 2015-08-11 | Victor Gawski; John Kenneth Snyder |
| A method includes performing a directional drilling operation. The method also includes receiving data from one or more sensors, wherein at least one of the one or more sensors output data related to a performance attribute of a downhole component that is from a group consisting of a downhole drilling motor and a rotary steerable tool. The downhole component comprises part of a drill string that is used to perform the directional drilling operation. The performance attribute is selected from a group consisting of rotations per unit of time of the downhole component, operating differential pressure across the downhole component and torque output of the downhole component. The method also includes displaying the data in a graphical and numerical representation on a graphical user interface screen. | ||||||
| 188 | Drilling rig with position and velocity measuring tool for standard and directional drilling | US14455628 | 2014-08-08 | US09080428B1 | 2015-07-14 | Paul F. Rembach; Reiner Fiege |
| A drilling rig with a position and velocity measuring tool that provides a self-adjusting auto driller usable for standard drilling and directional drilling in a wellbore. The position and velocity measuring tool has a processor and data storage with computer instructions for instructing the processor to present an operator directional drilling steering system dashboard with numerous graphic visual components which creates and uses a virtual encoder eliminating a failure point of a mechanical encoder. | ||||||
| 189 | METHOD OF, AND A SYSTEM FOR, DRILLING TO A POSITION RELATIVE TO A GEOLOGICAL BOUNDARY | US14412049 | 2013-07-05 | US20150185715A1 | 2015-07-02 | Charles Benjamin McHugh |
| A system (30) for drilling to a position relative to a geological boundary in a geological formation includes a sensor pack (26) for sensing parameters associated with a drilling operation carried out in the geological formation by a drill (10). A data storage module (34) stores a geological model of the geological formation and data relating to the sensed parameters, the geological model including data relating to the geological boundary. A processor module (32) is configured to monitor the drilling operation using the data related to the sensed parameters and to locate the position of a drill bit of the drill (10) in the geological formation and its corresponding position within the geological model. The processor module (32) is further configured to generate an end point at a defined position relative to the geological boundary. A drill controller (24) communicates with the processor module (32), the drill controller (24) being configured to control operation of the drill 10 and to cause the drill (10) to cease drilling when the end point has been reached. | ||||||
| 190 | Drill bit assembly having electrically isolated gap joint for measurement of reservoir properties | US13266080 | 2009-10-29 | US09022144B2 | 2015-05-05 | Brian Clark; Reza Taherian; Derek W. Logan; Garry Holmen; Anthony R. Dopf; Aaron Logan; Robert Utter |
| A drill bit assembly for measuring reservoir formation properties comprises a bit head and a pin body, and an electrically insulated gap joint between two conductive parts of the drill bit assembly. The bit head has a cutting end and an opposite connecting end with an engagement section. The pin body comprises a connecting end with an engagement section. The pin connecting end is connected to the bit head connecting end such that the engagement sections overlap. The electrically insulating gap joint can fill a gap between the bit head and pin body engagement sections such that the bit head and pin body are mechanically connected together at the connecting ends but electrically separated. Alternatively or additionally, the pin body can have two pieces which are separated by an electrically insulating gap joint. An electrical conductor is electrically connected at a first end to the bit head and is communicable at a second end with an alternating current signal to transmit an alternating current into the bit head, thereby inducing an electric current into a reservoir formation adjacent the bit head. Electronic equipment includes measurement circuitry configured to determine the alternating current at the bit head, the alternating current being inversely proportional to a bit resistivity of the formation. | ||||||
| 191 | SYSTEMS AND METHODS OF DRILLING CONTROL | US14403119 | 2012-07-12 | US20150105912A1 | 2015-04-16 | Jason D. Dykstra |
| A system to optimize a drilling parameter of a drill string includes a drill string control subsystem. The system includes an optimization controller to coordinate operations of the drill string control subsystem during a drilling process at least in part by: determining a first optimized rate of penetration based on a drilling parameter model and a first drilling parameter estimate; providing a first set of commands to the drill string control subsystem based on the first optimized rate of penetration; determining a second drilling parameter estimate during the drilling process based, at least in part, on the drilling parameter model and feedback corresponding to the drill string control subsystem; determining a second optimized rate of penetration during the drilling process based on the second drilling parameter estimate; and providing a second set of commands to the drill string control subsystem based on the second optimized rate of penetration. | ||||||
| 192 | SYSTEM AND CONSOLE FOR MONITORING AND MANAGING WELL SITE OPERATIONS | US14320564 | 2014-06-30 | US20150029034A1 | 2015-01-29 | FEREIDOUN ABBASSIAN; PER ARILD ANDRESEN; MARK SHELTON ASTON; CHRISTOPHER JEREMY COLEY; STEPHEN TEAN EDWARDS; MARK ADRIAN HONEY; NIGEL CHARLES LAST; CHRISTOPHER FRANCIS LOCKYEAR; COLIN JAMES MASON; JAMES MCKAY; MICHAEL LYLE PAYNE; TROND WAAGE; NICHOLAS ADAM WHITELEY; WARREN JEFFREY WINTERS; TERJE SORLIE REINERTSEN; RUNE ARNT SKARBO; SHARADA BHARATH; KEVIN PERRY RICHARDSON |
| A well advisor system and console for monitoring and managing well drilling and production operations. The system may be accessed through one or more workstations, or other computing devices, which may be located at a well site or remotely. The system is in communication with and receives input from various sensors. It collects real-time sensor data sampled during operations at the well site. The system processes the data, and provides nearly instantaneous numerical and visual feedback through a variety of graphical user interfaces (“GUIs”), which are presented in the form of an operation-specific console. The input and data provides information related to geologic uncertainty concerning a well being drilled, with a focus on the safety of the drilling operation. | ||||||
| 193 | Graph to analyze drilling parameters | US13414810 | 2012-03-08 | US08854373B2 | 2014-10-07 | 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. | ||||||
| 194 | System and method for surface steerable drilling | US13535573 | 2012-06-28 | US08794353B2 | 2014-08-05 | Todd W. Benson; Teddy C. Chen |
| A system and method for surface steerable drilling are provided. In one example, the method includes monitoring operating parameters for drilling rig equipment and bottom hole assembly (BHA) equipment for a BHA, where the operating parameters control the drilling rig equipment and BHA equipment. The method includes receiving current inputs corresponding to performance data of the drilling rig equipment and BHA equipment during a drilling operation and determining that an amount of change between the current inputs and corresponding previously received inputs exceeds a defined threshold. The method further includes determining whether a modification to the operating parameters has occurred that would result in the amount of change exceeding the defined threshold and identifying that a problem exists in at least one of the drilling rig equipment and BHA equipment if no modification has occurred to the operating parameters. The method includes performing a defined action if a problem exists. | ||||||
| 195 | GRAPH TO ANALYZE DRILLING PARAMETERS | US14163155 | 2014-01-24 | US20140138158A1 | 2014-05-22 | Hatem Oueslati; Rudolf Carl Pessier; Hanno Reckmann; Bernhard Meyer-Heye; Thorsten Schwefe |
| 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. | ||||||
| 196 | SYSTEM AND METHOD FOR DETERMINING INCREMENTAL PROGRESSION BETWEEN SURVEY POINTS WHILE DRILLING | US14095073 | 2013-12-03 | US20140131102A1 | 2014-05-15 | TODD W. BENSON; TEDDY 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. | ||||||
| 197 | DRILLING OPTIMIZATION WITH A DOWNHOLE MOTOR | US13993643 | 2011-12-13 | US20140027175A1 | 2014-01-30 | Maurice Ringer; Michael P. Barrett; Benjamin P. Jeffryes; Walter David Aldred; Ashely Johnson; Gokturk Tunc; John Cook |
| Optimising the operation of a hydraulically powered rotor and stator driven drill as it drills a wellbore into the earth is described. Drilling optimization is provided measuring a first set of rotor and stator operating parameters including the speed of rotation of the rotor and rotor torque for a first period of time, generating a first set of relationships from the first set of operating parameters to enable the rotor speed and rotor torque to be predicted over a range of operating parameter values, determining from the relationships a first more optimal mode of operation, and changing at least one operating parameter to move the operation of the rotor and stator towards the more optimal mode of operation. | ||||||
| 198 | HIGH DEFINITION DRILLING RATE OF PENETRATION FOR MARINE DRILLING | US13741990 | 2013-01-15 | US20130186685A1 | 2013-07-25 | Trenton Martin |
| Two sensors may be installed on a marine drill to improve measurements used for monitoring and operating the marine drill. The sensors may be installed in a differential configuration with one sensor located on a top block of the marine drill and a second sensor located on a drilling floor of the marine drill. Various calculations may be performed using measurements obtained from the two sensors such as, for example, rate of penetration of the marine drill, drilling level bubble for the marine drill, out of-straightness values for the marine drill, and vibration motion for the marine drill. | ||||||
| 199 | SYSTEM AND METHOD FOR STICK-SLIP CORRECTION | US13219125 | 2011-08-26 | US20130049982A1 | 2013-02-28 | Andreas Hartmann |
| A method of processing downhole measurement data includes: receiving formation measurement data generated by a downhole tool during a logging-while drilling operation over a selected time period; receiving a measured depth corresponding to the selected time period based on data taken at a surface location; receiving tool rotation data generated by measurements of a rotational rate of the downhole tool taken by a downhole sensor during the selected time period; calculating a new depth of the tool as a function of time over the selected time period based on a relationship between the tool rotation data and the measured depth; and correcting an original depth of the measurement data with the new depth. | ||||||
| 200 | System and method for surface steerable drilling | US13334370 | 2011-12-22 | US08210283B1 | 2012-07-03 | Todd W. Benson; Teddy C. Chen |
| A system and method for surface steerable drilling are provided. In one example, the system receives feedback information from a drilling rig and calculates an estimated position of a drill bit in a formation based on the feedback information. The system compares the estimated position to a desired position along a planned path of a borehole. The system calculates multiple solutions if the comparison indicates that the estimated position is outside a defined margin of error relative to the desired position. Each solution defines a path from the estimated position to the planned path. The system calculates a cost of each solution and selects one of the solutions based at least partly on the cost. The system produces control information representing the selected solution and outputs the control information for the drilling rig. | ||||||
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