| 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 | Evaluating a condition of a downhole component of a drillstring | US14028387 | 2013-09-16 | US09845671B2 | 2017-12-19 | Franck T. Kpetehoto; Donald Keith Trichel; Abdallah Ahmed ElKamel; Sandeep S. Janwadkar; Sridharan Chandrasekaran |
| Methods, systems and products for evaluating a downhole component condition for a drilling assembly in a borehole. Methods include estimating a bending moment on the component at a selected depth along the borehole; estimating a number of rotations of the component at the selected depth; and estimating the condition of the component using the estimated bending moment and the estimated number of rotations at the selected depth. Estimated bending moment may be derived from a borehole model using an estimated deviation on a selected length of the borehole about the selected depth. The condition may be accumulated fatigue or estimated remaining useful life. Estimating the condition may include tracking a total estimated number of rotations wherein the component is subjected to bending moment values in a corresponding moment window, which may be greater than a predetermined threshold bending moment. Weight factors may be associated with at least one moment window. | ||||||
| 182 | Imaging of wellbore pipes using deep azimuthal antennas | US14889327 | 2015-07-02 | US09803466B2 | 2017-10-31 | Burkay Donderici |
| A pipe inspection tool includes a body having a central axis, and one or more azimuthal antenna arrays operatively coupled to the body. Each azimuthal antenna array includes a plurality of antenna coils arranged circumferentially about the central axis and comprising an azimuthal array of z-coils or an azimuthal array of separated x-coils and separated y-coils. The separated x-coils are oriented in a first direction with respect to the central axis, the separated y-coils are oriented in a second direction with respect to the central axis, and the z-coils are oriented in a third direction with respect to the central axis. The second direction is orthogonal to the first direction, and the third direction is orthogonal to both the first and second directions. | ||||||
| 183 | Polymer composite wireline cables comprising optical fiber sensors | US14771249 | 2015-04-28 | US09791334B2 | 2017-10-17 | Hua Xia; Sean Gregory Thomas; David L. Perkins; John L. Maida |
| A polymer composite wireline cable comprising: a polymeric matrix material; at least one reinforced fiber embedded in the polymeric matrix material; and at least one optical fiber disposed in the polymeric matrix material, the at least one optical fiber having at least one pair of Bragg grating sensors, wherein one of the pair of Bragg grating sensors is configured to experience loading strain and the other of the pair of Bragg grating sensors is configured not to experience loading strain. | ||||||
| 184 | DOWNHOLE TOOL WITH RADIAL ARRAY OF CONFORMABLE SENSORS FOR DOWNHOLE DETECTION AND IMAGING | US15466047 | 2017-03-22 | US20170254918A1 | 2017-09-07 | Burkay Donderici |
| According to aspects of the present disclosure, an example downhole tool may include tool body, a first pad radially extendable from the tool body, and a radial array of conformable sensors coupled to the first pad. At least one conformable sensor of the radial array of conformable sensors may include a first flexible material. A transmitter may be coupled to one of the tool body and the first flexible material, and a receiver may be coupled to one of the tool body and the first flexible material. At least one of the transmitter and the receiver may be coupled to the first flexible material. | ||||||
| 185 | Real-Time Tension, Compression and Torque Data Monitoring System | US15438413 | 2017-02-21 | US20170248004A1 | 2017-08-31 | Louis D. Garner; Lubos Vacik; Silviu Livescu |
| A data monitoring system includes a data monitoring tool incorporated into a work string proximate a bottom hole assembly. The data monitoring tool detects at least one wellbore condition and at least one force experienced by the data monitoring tool. | ||||||
| 186 | Casing defect determination using stored defect response information | US15035155 | 2015-07-11 | US09745845B2 | 2017-08-29 | Luis Emilio San Martin; Reza Khalaj Amineh; Burkay Donderici |
| A system comprises a wellbore having a plurality of casings disposed therein and one or more electromagnetic coils disposed within the wellbore. The one or more electromagnetic coils are configured to generate and direct one or more excitation signals toward the plurality of casings and receive one or more response signals based on interactions of the one or more excitation signals with the plurality of casings. The system further comprises a casing evaluation module comprising a processor and memory and communicably coupled to the one or more electromagnetic coils. The casing evaluation module is operable to determine whether defect exists in at least one of the plurality of casings using a first response signal received from the one or more electromagnetic coils and elemental defect information, the elemental defect information comprising a plurality of combinations of small defect information. | ||||||
| 187 | METHODS FOR WELL TREATMENT | US15501078 | 2015-08-13 | US20170234104A1 | 2017-08-17 | Simon Gareth James |
| Methods for treating and restoring zonal isolation in a subterranean well involve the use of a well treatment tool that may drill one or more holes in casing and inject a treatment fluid that may seal cracks or fissures in the cement sheath behind the casing. Microannuli may also be sealed. The treatment fluids may be solids free or in the form of suspensions containing solids having a particle size between 1 nm and 100 nm. | ||||||
| 188 | DOWNHOLE TOMOGRAPHIC IMAGING | US15502534 | 2014-10-02 | US20170218749A1 | 2017-08-03 | Dongwon Lee; Weijun Guo; Sriram Srinivasan |
| A tomographic imaging apparatus utilizes Compton backscattering to evaluate cement behind the casing. The imaging apparatus includes a slant-hole or pin-hole collimator coupled to a series of detectors in order to count the number of photons that backscatter off from the cement. The number of backscattered photons is proportional to the density of the cement behind the casing. Using the photon count, an image processing unit of the imaging apparatus generates a 2D or 3D tomographic image of the borehole. | ||||||
| 189 | DIRECTIONAL DRILLING METHODS AND SYSTEMS EMPLOYING MULTIPLE FEEDBACK LOOPS | US15329537 | 2014-09-16 | US20170218744A1 | 2017-08-03 | Jason D. Dykstra; Yuzhen Xue |
| A directional drilling system includes a bottomhole assembly having a drill bit and a steering tool configured to adjust a drilling direction in real-time. The system also includes a first feedback loop that provides a first steering control signal to the steering tool, and a second feedback loop that provides a second steering control signal to the steering tool. The system also includes a set of sensors to measure at least one of strain and movement at one or more points along the bottom-hole assembly during drilling, wherein the first and second steering control signals are based in part on the strain or movement measurements. | ||||||
| 190 | ADJUSTING SURVEY POINTS POST-CASING FOR IMPROVED WEAR ESTIMATION | US15328414 | 2014-09-08 | US20170204720A1 | 2017-07-20 | Robello Samuel; Aniket |
| Disclosed embodiments include a method for estimating casing wear including the operations of: obtaining locations of survet points along a borehole, said survey point locations representing a borehole trajectory; casing at least a portion of the borehole with a casing string; deriving locations of adjusted survey points that represent a casing trajectory along said portion of the borehole, the casing trajectory being different from the borehole trajectory; estimating, as a function of position along said casing string, a side force of a drill string against the casing string; computing, as a function of position along the casing string, casing wear based at least in part on the side force; and generating a notification of any positions where casing wear exceeds a threshold. | ||||||
| 191 | Methods and systems for controlling torque transfer from rotating equipment | US14327020 | 2014-07-09 | US09702202B2 | 2017-07-11 | Jim B. Surjaatmadja; Loyd East |
| Systems and methods for reducing the amount of torque transferred to the Bottom Hole Assembly and the drill string during drilling operations are disclosed. The drill string includes an optionally non-rotatable portion. A rotational hold down system is positioned at a first position on the drill string where it is not rotationally coupled to the drill string. The rotational hold down system is then moved to a second position on the drill string where it is rotationally coupled to the optionally non-rotatable portion of the drill string. In the second position, one or more bars on the rotational hold down system substantially prevent rotation of the optionally non-rotatable portion of the drill string. | ||||||
| 192 | Systems and methods for wellbore optimization | US13805257 | 2010-06-18 | US09689207B2 | 2017-06-27 | Xinpu Shen; Mao Bai; William Bradley Standifird |
| Systems and methods for wellbore optimization, which include numerical procedures for selecting an optimal wellbore trajectory and casing strength based on Formation Loading Potential. | ||||||
| 193 | System and method for wireline tool pump-down operations | US14413320 | 2012-07-16 | US09657540B2 | 2017-05-23 | Randolph S. Coles; Dipesh P. Ashar |
| A system for pump down operations in a wellbore includes a tool string disposed in a wellbore, the tool string including a cable head having an upper end coupled to an electric wireline cable, a downhole tool coupled to the cable head, the downhole tool selected from the group consisting of perforating tools and downhole logging tools. In this embodiment, the system further includes a downhole tension sensor located proximal to the upper end of the cable head, the sensor adapted to obtain downhole wireline tension data and transmit the downhole wireline tension data via the electric wireline cable, a fluid pump with a fluid output operatively connected to the wellbore above the tool string, and a controller adapted to selectively adjust a pump fluid output rate of the fluid pump during pump down operations based on the downhole wireline tension data received from the downhole tension sensor. | ||||||
| 194 | METHOD AND APPARATUS FOR VIBRATING HORIZONTAL DRILL STRING TO IMPROVE WEIGHT TRANSFER | US15420253 | 2017-01-31 | US20170138130A1 | 2017-05-18 | Gerald HEISIG |
| An apparatus for use in a horizontal section of a drill string is disclosed. The apparatus includes a motor that is connected to the horizontal section of the drill string. The motor is adapted to impart vibrations in the horizontal section of the drill string, where the vibrations are at about the lateral resonant frequency of the horizontal section of the drill string. | ||||||
| 195 | ENERGY-OPTIMIZED EDDY CURRENT MEASUREMENT SYSTEMS AND METHODS | US15315339 | 2015-07-13 | US20170131239A1 | 2017-05-11 | Reza Khalaj Amineh; Burkay Dondericl; Luis Emilio San Martin |
| A method for optimizing eddy current measurements includes conveying an electromagnetic tool through a borehole. The method further includes transmitting an excitation signal from the tool. The method further includes recording an eddy current response to the excitation signal from one or more tubings and casings within the borehole before the fall time of the excitation signal. | ||||||
| 196 | Determining stresses in a pipe under non-uniform exterior loads | US14769026 | 2013-11-27 | US09638023B2 | 2017-05-02 | Robert F Mitchell |
| Systems and methods for determining stresses in pipe under non-uniform exterior loads to test the pipe design for structural integrity by approximating non-uniform exterior loads on the pipe and performing a stress analysis of the pipe under the non-uniform exterior loading to determine the stresses in the pipe. | ||||||
| 197 | Method and apparatus for vibrating horizontal drill string to improve weight transfer | US13556015 | 2012-07-23 | US09598906B2 | 2017-03-21 | Gerald Heisig |
| An apparatus for use in a horizontal section of a drill string is disclosed. The apparatus includes a motor that is connected to the horizontal section of the drill string. The motor is adapted to impart vibrations in the horizontal section of the drill string, where the vibrations are at about the lateral resonant frequency of the horizontal section of the drill string. | ||||||
| 198 | Portable attachment of fiber optic sensing loop | US15338732 | 2016-10-31 | US09593569B2 | 2017-03-14 | Zbigniew Sobolewski; Ronald L. Spross; Gary Nguyen; Mark A. Sitka |
| The subject matter of this specification can be embodied in, among other things, a system for removably attaching an optical fiber sensor loop onto a tubular member, which includes an optical fiber sensor loop having a continuous optical fiber positioned arranged in a plurality of loops, each of said loops having a first end turn and a second end turn, a first and a second turn guide each including a plurality of turn grooves increasing outwardly in increasing radii, each of said turn grooves configured to receive an end turn portion of the optical fiber, a first and a second supporting wedge each having a planar first surface configured to receive a turn guide and a curved second surface configured to be received on the tubular member, and a connector configured to couple the first mounting wedge to the second mounting wedge. | ||||||
| 199 | System for estimating fatigue damage | US14879239 | 2015-10-09 | US09593568B1 | 2017-03-14 | Jeffrey LeMonds; Judith Ann Guzzo; Shaopeng Liu; Uttara Ashwin Dani |
| In one aspect, a system for estimating fatigue damage in a riser string is provided. The system includes a plurality of accelerometers which can be deployed along a riser string and a communications link to transmit accelerometer data from the plurality of accelerometers to one or more data processors in real time. With data from a limited number of accelerometers located at sensor locations, the system estimates an optimized current profile along the entire length of the riser including riser locations where no accelerometer is present. The optimized current profile is then used to estimate damage rates to individual riser components and to update a total accumulated damage to individual riser components. The number of sensor locations is small relative to the length of a deepwater riser string, and a riser string several miles long can be reliably monitored along its entire length by fewer than twenty sensor locations. | ||||||
| 200 | Monitoring system for well casing | US14617720 | 2015-02-09 | US09574434B2 | 2017-02-21 | Michele Scott Albrecht; Jeremiah Glen Pearce; Frederick Henry Kreisler Rambow; David Ralph Stewart |
| A system for use in a wellbore, comprises a length of casing, a structure that is configured to deform with deformation of the casing, said structure being affixed to the length of casing at substantially the same radial position along the length of casing, and a sensing device that is configured to measure deformation of the structure, said device comprising a plurality of sensors that are distributed with respect to at least one of the length of said structure and the periphery of said structure. | ||||||
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