| 序号 | 专利名 | 申请号 | 申请日 | 公开（公告）号 | 公开（公告）日 | 发明人 |
|---|---|---|---|---|---|---|
| 161 | RHODONEA CELL ACOUSTIC HYPERLENS FOR THRU-CASING ULTRASONIC SENSORS | US15215159 | 2016-07-20 | US20180024265A1 | 2018-01-25 | DWIGHT W. SWETT |
| Apparatus, systems, and methods for investigating a subsurface volume of interest from a borehole. Apparatus comprise an enclosure configured for conveyance along the borehole; an acoustic source in the enclosure configured to generate acoustic signals; a lens assembly disposed in the enclosure and next to the acoustic source, the lens assembly being formed of a plurality of cells, each cell formed as a column oriented transverse to a direction of travel of the acoustical signals. Each cell comprises a plurality of cell segments with each cell segment of the plurality comprising at least one arcuate wall and at least one radial finger, and wherein the cell segments are oriented in alignment with a rhodonea conformal mapping geometry in a plane transverse to the column to cause acoustic waves to travel at a different speed in each of three orthogonal directions. | ||||||
| 162 | Multipurpose Permanent Electromagnetic Sensing System for Monitoring Wellbore Fluids and Formation Fluids | US15125650 | 2015-12-04 | US20180017697A1 | 2018-01-18 | Ahmed E. Fouda; Tasneem Mandviwala; Burkay Donderici; Etienne Samson |
| Methods and systems of electromagnetic sensing in a wellbore are presented in this disclosure for monitoring annulus fluids and water floods. An array of transmitters and one or more receivers are located along a casing in the wellbore. A transmitter in the array and one of the receivers can be mounted on a same collar on the casing forming a transmitter-receiver pair. The receiver can receive a signal originating from the transmitter and at least one other signal originating from at least one other transmitter in the array, wherein the signal is indicative of a fluid in the wellbore in a vicinity of the transmitter-receiver pair and the at least one other signal is indicative of another fluid in a formation around the wellbore. The receiver can further communicate, via a waveguide, the signal and the at least one other signal to a processor for signal interpretation. | ||||||
| 163 | MUD CAKE CORRECTION OF FORMATION MEASUREMENT DATA | US15128855 | 2015-12-11 | US20180016888A1 | 2018-01-18 | Luis Emilio San Martin; Burkay Donderici; Baris Guner |
| In some embodiments, an apparatus and a system, as well as a method and an article, may operate to estimate a value for a mud cake parameter to provide an estimated mud cake parameter value; to generate, in a solution operation, a formation parameter value and an adjusted mud cake parameter value using the estimated mud cake parameter value; and to provide corrected galvanic tool resistivity measurements based on at least the adjusted mud cake parameter value. Additional apparatus, systems, and methods are disclosed. | ||||||
| 164 | CASING COUPLING HAVING COMMUNCATION UNIT FOR EVALUATING DOWNHOLE CONDITIONS | US15545232 | 2015-03-27 | US20180010449A1 | 2018-01-11 | Mark W. ROBERSON; Scott GOODWIN |
| A communication unit is situated in or on a casing collar. The casing collar has two threaded ends for joining casing joints to construct a well casing, and a communication unit is disposed in or on a central region of the tube between the two threaded ends. In an example, the communication unit has a transmitter for transmitting sensor data uphole from a sensor sensing a well bore condition. For example, the communication unit has a receiver for receiving sensor data from Micro-Electro-Mechanical Systems (MEMS) sensors, a transceiver for interrogating RFID tags, an acoustic transceiver for sensing wellbore conditions, a pressure sensor, a temperature sensor, and batteries for powering the communication unit. | ||||||
| 165 | Downhole Communications Using Selectable Frequency Bands | US15541853 | 2015-03-11 | US20180003041A1 | 2018-01-04 | Mark W. Roberson |
| A system that is positionable in a wellbore in a subterranean formation can include a first transceiver that is positionable external to a casing string in the wellbore. The first transceiver can wirelessly transmit data via a signal within a frequency band that is selected based on a fluid property of a fluid in the wellbore and a property of the subterranean formation. The system can also include a second transceiver that is positionable externally | ||||||
| 166 | FLUID MONITORING USING RADIO FREQUENCY IDENTIFICATION | US15536089 | 2015-02-04 | US20180003029A1 | 2018-01-04 | Mark Roberson; Scott Goodwin |
| A system for fluid monitoring in a borehole for extracting hydrocarbons includes a casing to transport hydrocarbons, the casing defining an annulus between the casing and borehole wall. The system further includes a centralizer, coupled to the casing, to center the casing within the borehole. The system further includes a sensor unit, including a radio frequency identification (RFID) interrogator, positioned on the centralizer to monitor one or more fluids, including RFID tags, in the annulus. | ||||||
| 167 | Cement evaluation | US14780562 | 2014-03-27 | US09840911B2 | 2017-12-12 | Andrew J. Hayman |
| Surface equipment of a cement analysis system (CAS) estimates a first drilling fluid slowness (FSLO) and a first drilling fluid acoustic impedance (ZMUD) based on a type and density of wellbore drilling fluid. A second FSLO is estimated based on a thickness and diameter of wellbore casing and transit time for energy emitted by a downhole tool to travel to and from the casing. An FSLO graphical interface is generated based on the first and second FSLO. A second ZMUD is estimated based on the drilling fluid type and density and one of the first and second FSLO selected utilizing the FSLO graphical interface. A ZMUD graphical interface is generated based on the first and second ZMUD. The downhole tool then obtains log data utilizing at least one parameter selected utilizing the ZMUD graphical interface. The log data includes a final ZMUD measured with respect to wellbore depth. | ||||||
| 168 | LOGGING SYSTEM AND METHOD FOR EVALUATION OF DOWNHOLE INSTALLATION | US15539308 | 2015-12-21 | US20170350999A1 | 2017-12-07 | Ioan-Alexandru MERCIU |
| A downhole installation comprises: a first pipe layer 8, a second pipe layer 10 about the first pipe layer 8, an annulus 12 between the first pipe layer 8 and the second pipe layer, and a geological formation out-side of the second pipe layer 10. A logging system for evaluation of the downhole installation comprises: a logging tool 4 including an angled acoustic transmitter 20 for exciting a flexural wave in the first pipe layer 8, and three or more 10 angled acoustic receivers 14, 16, 38, 40, 42 spaced apart along the tool 4 such that, in use, the receivers are at different locations along the length of the pipe layers 8, 10, the receivers 4, 16, 38, 40, 42 each being for obtaining third interface echo data from the second pipe layer 10; and a processor arranged to process acoustic data from the receivers in order to: identify trends in the amplitude of the third interface echo as it propagates along the length of 1 the pipes, calculate an estimated exponential decay for the third interface echo when reinforcement from other acoustic energy is disregarded, use this estimation to predict if the material behind the second pipe layer 10 is fluid or solid, and analyse the third interface echo data in light of the determined material state in order to thereby evaluate material conditions in the annulus 12 outside the second pipe layer 10. | ||||||
| 169 | DOWNHOLE FLUID CHARACTERIZATION METHODS AND SYSTEMS EMPLOYING A CASING WITH A MULTI-ELECTRODE CONFIGURATION | US15536090 | 2015-02-13 | US20170342818A1 | 2017-11-30 | Mark Roberson; Scott Goodwin |
| A method that includes deploying a casing with a multi-electrode configuration over a dielectric layer in a downhole environment. The method also includes collecting electromagnetic (EM) measurements using the multi-electrode configuration, and processing the EM measurements to obtain a characterization of fluids in an annulus between the casing and a borehole wall. A related system includes a casing deployed downhole, the casing having a multi-electrode configuration and a dielectric layer between the casing and the multi-electrode configuration. The system also includes a controller for directing collection of EM measurements using the multi-electrode configuration, and a processor that processes the EM measurements to obtain a characterization of fluids in an annulus between the casing and a borehole wall. | ||||||
| 170 | Ultrasonic Cement and Casing Thickness Evaluation | US15163105 | 2016-05-24 | US20170342817A1 | 2017-11-30 | Lucio N. Tello; Edwin K. Roberts; Thomas J. Blankinship |
| Methods and systems for logging a wellbore having a casing are described. Acoustic energy, typically ultrasonic acoustic energy, is used to stimulate reverberation of the casing at a harmonic (for example, the second or third harmonic) of the resonance frequency of the casing. One or more acoustic sensors are used to measure acoustic signals generated by the casing reverberation. Parameters of the casing are calculated based on the measured acoustic signals adjusted by an adjustment factor determined by the particular harmonic. The use of harmonics instead of the fundamental resonance frequency allows wellbores with casings having walls thicker than 0.625 inches to be logged. | ||||||
| 171 | Behind pipe evaluation of cut and pull tension prediction in well abandonment and intervention operations | US14895039 | 2015-08-10 | US09822629B2 | 2017-11-21 | Fnu Suparman; Philip Edmund Fox; Gary James Frisch |
| Casing removal operations may utilize an analytical model to the estimate the total force to (1) break bonding between a cut casing and the annular materials contained between the cut casing and the surrounding borehole and (2) pull the cut casing upward through the borehole while taking into account frictional forces inside and outside the cut casing, shear forces, and the like. Such models may further predict the casing overpull and total tension needed to extract the cut casing from the borehole. Using these models in conjunction with the specifications of the casing retrieval equipment may allow for determining the cutting depth for producing the cut casing with higher accuracy than previously available. | ||||||
| 172 | Systems and methods for downhole cement evaluation | US14366676 | 2012-12-20 | US09822627B2 | 2017-11-21 | Benoit Froelich |
| Systems and methods for cement evaluation by determining a shear velocity of a shear wave (26) propagating within a medium (20) located between a formation (12) and a casing (13) in a borehole (11) are presented. The method can include positioning an ultrasonic transducer array (21) in the borehole inside the casing. The method can also include in a pushing mode, generating a shear wave in the medium with the ultrasonic transducer array inside the casing. The method can also include in an interrogation mode, measuring a shear velocity of the shear wave in the medium with the ultrasonic transducer array. The shear velocity may be used to determine whether the medium is solid or liquid. | ||||||
| 173 | CAPTURE GAMMA RAY SPECTROSCOPY FOR ANALYZING GRAVEL-PACKS, FRAC-PACKS AND CEMENT | US15594036 | 2017-05-12 | US20170329041A1 | 2017-11-16 | Qianmei (Jeremy) ZHANG; Harry D. SMITH, JR. |
| Methods of using capture gamma-ray spectroscopy for analyzing gravel-packs, frac-packs, and cement are disclosed herein. The methods can include distinguishing particles placed in a borehole region from particles placed in a subterranean formation outside of the borehole region, by utilizing a slurry comprising a liquid, particles, and a thermal neutron absorbing material to place the particles into the borehole region. The methods can also include obtaining first and second data sets by lowering into a borehole traversing the borehole region a pulsed neutron logging tool comprising a pulsed neutron source and a detector, emitting pulses of neutrons from the pulsed neutron source into the borehole region at intervals of one pulse per about 1,000 μsec for the first data set and about one pulse per about 100 μsec for the second data set, and detecting capture gamma rays resulting from nuclear reactions in the borehole and the subterranean formation. | ||||||
| 174 | WELL MONITORING WITH AUTONOMOUS ROBOTIC DIVER | US15515974 | 2014-11-13 | US20170299758A1 | 2017-10-19 | Michael T. Pelletier; David L. Perkins; Li Gao |
| A monitoring apparatus for use in a well can include multiple segments, the segments comprising at least one buoyancy control device, at least one communication device, and at least one well parameter sensor. A method of communicating in a subterranean well can include installing at least one monitoring apparatus in the well, the monitoring apparatus including a communication device, a well parameter sensor and a buoyancy control device, and the communication device communicating with another communication device. A well monitoring system can include at least one monitoring apparatus disposed in a wellbore, the monitoring apparatus comprising multiple segments, the segments including at least one buoyancy control device, at least one well parameter sensor, and at least one communication device. | ||||||
| 175 | BIPOLAR ACOUSTIC HYPERLENS FOR DUAL-STRING THRU-CASING ULTRASONIC SENSORS | US15130312 | 2016-04-15 | US20170299752A1 | 2017-10-19 | Dwight W. Swett |
| Apparatus, systems, and methods for investigating a subsurface volume of interest from a borehole. Apparatus comprise an enclosure configured for conveyance along the borehole; an acoustic source in the enclosure configured to generate acoustic signals; a lens assembly disposed in the enclosure and next to the acoustic source, the lens assembly being formed of a plurality of lens elements; wherein each lens element comprises a plurality of cells arranged in a curvilinear cell array, each cell formed as a column oriented transverse to a direction of travel of the acoustical signals. The plurality of cells may be arranged according to a conformal mapping geometry, including a canonical Bipolar conformal mapping transformation of constant [u,v] contour lines to [x,y] Cartesian coordinates. A portion of the cells are scaled down in size by a scale factor. The scale factor corresponding to each cell of the portion varies non-monotonically along periodicity lines. | ||||||
| 176 | Multi-sensor workflow for evaluation of gas flow in multiple casing strings with distributed sensors | US15111932 | 2015-09-04 | US09784884B2 | 2017-10-10 | Luis F. Quintero |
| A gas presence and distance thereof are calculated using pulsed neutron data. A distance of a gas flow path and a velocity of the gas flow therein are calculated using distributed acoustic sensors. The gas saturation and distance, and gas velocity and distance obtained from the noise data are correlated to obtain a first calculated distance and velocity values. The distance and the velocity of the gas flow are calculated using distributed Doppler sensors. The distance and velocity values are compared with the first calculated distance and velocity values to obtain a second calculated distance and velocity values. The distance of the gas flow and the velocity of the gas flow are calculated using distributed temperature sensors. The distance and velocity values are compared with the second calculated distance and velocity values to determine a distance of a cement interface, and a velocity of a gas flow therein. | ||||||
| 177 | Method to estimate cement acoustic wave speeds from data acquired by a cased hole ultrasonic cement evaluation tool | US14612101 | 2015-02-02 | US09784875B2 | 2017-10-10 | Smaine Zeroug; Jiaqi Yang; Sandip Bose |
| Embodiments of the disclosure may include systems and methods for estimating an acoustic property of an annulus in a cement evaluation system. In one embodiment, a casing arrival signal is acquired at acoustic receivers a cement evaluation tool. A spectral amplitude ratio is calculated based on the casing arrival signal. The spectral amplitude ratio is scanned to detect and identify discontinuities. If discontinuities are detected, the frequency at the discontinuity may be used to estimate a wavespeed of the annulus. If discontinuities are not detected, attenuation dispersions are calculated and estimated, and an estimated wavespeed and parameters are updated until the calculated and estimated attenuation dispersions match. | ||||||
| 178 | Multi-Tool Analysis of Annuluses in Cased Holes | US15119369 | 2015-09-14 | US20170261638A1 | 2017-09-14 | Gordon L. Moake |
| A method for determining a material in an annulus between two objects disposed in a borehole includes positioning logging tools in the borehole, each of the logging tools being oriented at a different angle. The method also includes measuring a property of the material in the annulus using the logging tools and determining the material in the annulus based on the measured property. | ||||||
| 179 | Method and apparatus for downhole photon imaging | US14758695 | 2013-12-30 | US09759834B2 | 2017-09-12 | Dongwon Lee; Weijun Guo |
| Method and apparatus for downhole photon imaging. The downhole photon imaging apparatus includes a photon source that emits photons; a scintillation device that generates a light signal in response to received photons; a light sensing device coupled with the scintillation device for generating an electronic signal in response to a received light signal; and a collimator coupled with the scintillation device which has a design that allows photons with single Compton backscattering and backscattered at a pre-determined backscattering angle to be detected by the scintillation device. | ||||||
| 180 | Well Monitoring with Optical Electromagnetic Sensing System | US15511215 | 2014-10-17 | US20170254191A1 | 2017-09-07 | David A. Barfoot; Peter J. Boul; Tasneem A. Mandviwala; Leonardo de Oliveira Nunes |
| A method of monitoring a substance in a well can include disposing at least one optical electromagnetic sensor and at least one electromagnetic transmitter in the well, and inducing strain in the sensor, the strain being indicative of an electromagnetic parameter of the substance in an annulus between a casing and a wellbore of the well. A system for monitoring a substance in a well can include at least one electromagnetic transmitter, and at least one optical electromagnetic sensor with an optical waveguide extending along a wellbore to a remote location, the sensor being positioned external to a casing in the wellbore. | ||||||
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