| 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 | USING AMPLITUDE RATIO CURVES TO EVALUATE CEMENT SHEATH BONDING IN MULTI-STRING DOWNHOLE ENVIRONMENTS | US15515786 | 2014-10-31 | US20170248003A1 | 2017-08-31 | Gary James Frisch; Philip Edmund Fox |
| A method for evaluating a cement sheath in a wellbore, in some embodiments, comprises transmitting sonic or ultrasonic waves from a logging tool disposed in a wellbore, receiving reflected waves at the logging tool and recording waveforms based on the received waves, processing the waveforms to determine average absolute value amplitude data for each of a plurality of zones, and determining a number using average absolute value amplitude data for a first of the plurality of zones and average absolute value amplitude data for a second of the plurality of zones. | ||||||
| 182 | METHOD FOR DETERMINING A THERMAL CONDUCTIVITY PROFILE OF ROCKS IN A WELLBORE | US15037996 | 2014-11-18 | US20170226850A1 | 2017-08-10 | Valery Vasilyevich SHAKO; Vyacheslav Pavlovich PIMENOV; Anton Vladimirovich PARSHIN |
| A casing with temperature sensors attached to its outer surface is lowered into a borehole and a cement slurry is injected into an annulus between the casing and a borehole wall. During injecting and hardening of the cement temperature is measured and thermal conductivity of the rock formation surrounding the borehole is determined. | ||||||
| 183 | Gamma analysis of cement | US15126484 | 2015-03-17 | US09726623B2 | 2017-08-08 | Weijun Guo; Da Luo |
| A method and logging tool for evaluating the cement behind casing. In an embodiment, a collimated source emits gamma rays at selectable elevation angles. A fixed collimated detector received reflected gamma rays. Reflected calibration gamma rays are measured in a wellbore section having a cement layer of known condition. Backscattered evaluation gamma rays are measured in a section of wellbore to be analyzed and are compared with the backscattered calibration gamma rays to provide an indication of the quality of the cement layer at that location. | ||||||
| 184 | 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. | ||||||
| 185 | Optimizing Running Operations | US15328834 | 2014-12-31 | US20170218728A1 | 2017-08-03 | Jason D. Dykstra; Zhijie Sun |
| A system for optimizing a running operation includes an interface to equipment and sensors for performing the running operation. The interface supplies control signals to the equipment and obtains measurement signals from the sensors. The system further includes a short-term optimizer that derives a current job state based at least in part on the measurement signals, and that further adjusts the control signals to optimize a short-term cost function. The short-term cost function includes a difference between the current job state and a desired job state derived from optimized values of a set of decision variables. The system further includes a long-term optimizer module that determines the optimized values based on a long-term cost function, the long-term cost function accounting for at least a long-term reward and a final state cost. | ||||||
| 186 | Reflection-only sensor at multiple angles for near real-time determination of acoustic properties of a fluid downhole | US14339240 | 2014-07-23 | US09720122B2 | 2017-08-01 | Rocco DiFoggio |
| Methods, systems, and devices for determining a parameter of interest of downhole fluid using an acoustic assembly comprising a single solid acoustic transmission medium having a face immersed in the downhole fluid. Methods include using characteristics of a plurality of acoustic pulse reflections from a solid-liquid interface at the face of the solid acoustic transmission medium to estimate the parameter of interest in near real-time. The characteristics may comprise a corresponding reflection amplitude and the corresponding unique angle of reflection for each acoustic pulse reflection. Methods may include generating a two dimensional data set from measured characteristics, generating a curve by performing data fitting on the two dimensional data set, and using the reciprocal slope of the curve to estimate the parameter of interest. Methods may include estimating time-dependent values for the parameter of interest substantially continuously while the acoustic assembly is on a single logging run in the borehole. | ||||||
| 187 | Determining locations of acoustic sources around a borehole | US14647811 | 2014-07-18 | US09714566B2 | 2017-07-25 | Batakrishna Mandal |
| Systems, methods, and computer-readable storage devices for determining a location of an acoustic source outside of a borehole. The method relates to indicating a radial distance to the borehole, an offset along the borehole, and an azimuthal position around the borehole, of the acoustic source. The method includes receiving acoustic signals from respective acoustic sensors spaced along a tool lowered within the borehole. Using the acoustic signals and a borehole model, stacked energies are calculated for different radial distances from the borehole. At least one of the stacked energies is translated to an indication of a radial distance of the acoustic source from the borehole. The stacked energy for a radial distance is computed by offsetting the acoustic data signals in time in accordance the borehole model, summing the offset acoustic data signals to produce a stacked signal, and evaluating energy of the stacked signal over a time window. | ||||||
| 188 | REAL-TIME ADAPTIVE MINIMUM PHASE WAVELET GENERATION FOR DOWNHOLE TOOLS | US15312748 | 2016-04-28 | US20170205524A1 | 2017-07-20 | Batakrishna MANDAL; Yinghui LU |
| An example method may include selecting a proposed pulse. A minimum phase wavelet may be generated based, at least in part, on the proposed pulse. A pulse signal within a wellbore may be generated based, at least in part, on the minimum phase wavelet. An echo signal corresponding to the pulse signal from at least a portion of the wellbore may be received, wherein the echo signal is indicative of a wellbore property | ||||||
| 189 | Determining whether a wellbore sealing operation has been performed correctly | US14127066 | 2012-05-16 | US09708904B2 | 2017-07-18 | Bruce McGarian; William Brown-Kerr |
| The invention relates to methods of determining whether a wellbore sealing operation has been performed correctly, and to wellbore-lining tubing which facilitates the determination of whether a wellbore sealing operation has been performed correctly. The invention has a utility in determining whether cement has been correctly supplied into an annular region defined between an internal wall of a wellbore and an external surface of a wellbore-lining tubing located in the wellbore, or whether a packer has been properly set to seal such an annular region. One disclosed method comprises the steps of: locating a wellbore-lining tubing (140) in a wellbore (100), said tubing having at least one pressure sensor (80); performing a wellbore sealing operation in an annular region (178) defined between an external surface of said tubing and an internal surface (130) of a wall of the wellbore, or between an external surface of said tubing and an internal surface of another wellbore-lining tubing (118) in which said tubing is located, to seal said tubing in the wellbore; monitoring the pressure of fluid in the annular region using the at least one pressure sensor; and recovering data concerning the pressure of the fluid monitored by the sensor to surface, the pressure data indicating whether the wellbore sealing operation has been performed correctly. | ||||||
| 190 | ACOUSTIC CALIPERING AND ANALYSIS OF ANNULUS MATERIALS | US15314737 | 2014-07-15 | US20170199295A1 | 2017-07-13 | Batakrishna Mandal |
| An apparatus and method may operate to mount acoustic sensors, azimuthally offset from each other, to the exterior of a casing. After the casing and acoustic sensors are in the borehole, signals are provided to the acoustic sensors to cause the acoustic sensors to emit acoustic signals into the annulus around the casing. The method further includes detecting reflected compression waves, shear waves or a combination or conversion thereof at the acoustic sensors to generate a set of two]way travel times of the acoustic signals. The method can further include generating distance measurements of a distance between corresponding acoustic sensors and points on the borehole wall based on the two]way travel times, to determine a position of the casing within the borehole. The method can further include identifying fluids based on the two]way travel times. Additional apparatus, systems, and methods are disclosed. | ||||||
| 191 | CASING AND CEMENT EVALUATION TOOL WITH REDUCED TRANSMITTER RINGING | US15311636 | 2016-04-28 | US20170175514A1 | 2017-06-22 | Peng Li; Zheng Chen; Batakrishna Mandal |
| An example cement and casing evaluation tool includes an amplifier and a filter coupled an output of the amplifier. A transducer may be coupled to the output of the filter. A ringing reduction system may be coupled to at least one of the amplifier, the filter, and the transducer, wherein the ringing reduction system selectively dissipates energy from at least one of the amplifier, the filter, and the transducer in response to a control signal. | ||||||
| 192 | METHOD TO DENOISE PULSE ECHO MEASUREMENT USING TOOL RESPONSE IN FRONT OF COLLARS | US15338865 | 2016-10-31 | US20170168184A1 | 2017-06-15 | Jean-Luc Le Calvez; Sylvain Thierry |
| A method includes performing pulse echo measurements using a pulse echo tool. The method also includes detecting a casing collar using the pulse echo measurements performed by the pulse echo tool. The method further includes estimating a tool response of the pulse echo tool response at the casing collar using one or more processors based on the pulse echo measurement at the casing collar. The method also includes and removing the pulse echo tool response estimation from at least some of the pulse echo measurements not at the casing collar. | ||||||
| 193 | CEMENT EVALUATION WITH NEUTRON-NEUTRON MEASUREMENT | US15039366 | 2013-12-30 | US20170167243A1 | 2017-06-15 | Weijun Guo; Daniel F. Dorffer |
| Various embodiments include apparatus and methods to conduct neutron-neutron measurements and to evaluate quality of cement between a casing and a formation. A tool can include a neutron source, a far detector, and a near detector, where the far detector and the near detector detect neutrons in response to activation of the neutron source. Measured counts of the detected neutrons can be compared with respect to expected counts of neutrons. From one or more comparisons, the quality of the cement can be evaluated. Additional apparatus, systems, and methods are disclosed. | ||||||
| 194 | Traceable Polymeric Additives for Use in Subterranean Formations | US15412875 | 2017-01-23 | US20170130118A1 | 2017-05-11 | Christopher Lynn Gordon; Craig Wayne Roddy; Jiten Chatterji |
| Disclosed are traceable polymeric additives that comprise a tagging material and methods of using the traceable polymeric additives in subterranean applications, such as cementing. An embodiment discloses a well treatment composition comprising a base fluid and a traceable polymeric additive comprising a polymer and a tagging material. | ||||||
| 195 | Multi-Sensor Workflow For Evaluation Of Gas Flow In Multiple Casing Strings With Distributed Sensors | US15111932 | 2015-09-04 | US20170123105A1 | 2017-05-04 | 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. | ||||||
| 196 | Total control perforator and system | US14756868 | 2015-10-23 | US20170114622A1 | 2017-04-27 | Don Umphries; Gabe Williger |
| A shaped charge carrier tool is provided that has particular utility for perforating well casing as a preparation for cement placement. A plurality, four or more elongated shaped charge carrier ribs having a high bending modulus are secured for radially expanded displacement around a central framing tube or rod. Radius rods link the ends of the carrier ribs to top and bottom hinge carriers. The hinge carriers encircle the framing tube and are free for axial translation along the framing tube. Articulating hinges connect the radius rods to the carrier ribs and to the hinge carriers. Opposed compressed coil springs provide a resilient bias on the hinge carriers to translate the carrier ribs radially outward against the interior surface of a well casing as the tool passes from a riser tube into a larger inside diameter well casing. | ||||||
| 197 | CIRCUMFERENTIAL ARRAY BOREHOLE EVALUATION TOOL | US15127992 | 2014-04-22 | US20170107809A1 | 2017-04-20 | Jim T. Hill; Philip E. Fox; Arthur Chuen Hon Cheng; Philip William Tracadas |
| An example apparatus for downhole cement inspection may include a tool body and an acoustic transmitter coupled to the tool body. An acoustic receiver may be coupled to the tool body at a first distance from the acoustic transmitter. A first array of acoustic receivers may be coupled to and positioned around a circumference of the tool body at a second distance from the acoustic transmitter. The second distance may be greater than the first distance. The acoustic receiver may be one receiver of a second array of acoustic receivers coupled to and positioned around the circumference of the tool body at the first distance. The first distance may be approximately three feet and the second distance may be approximately five feet. | ||||||
| 198 | METHOD AND SYSTEM FOR OPERATING AND MONITORING A WELL FOR EXTRACTING OR STORING FLUID | US15315872 | 2015-06-03 | US20170096888A1 | 2017-04-06 | Emeline Drouet; Louis Gorintin |
| The system for operating and monitoring a well for extracting or storing an operating fluid, such as natural gas, comprises a production column in which the operating fluid flows, a protective casing arranged around the production column, and a cement sheath interposed between the casing and a rock formation through which the well extends. The system further comprises, outside the casing, between the casing and the cement sheath, a series of electronic units distributed in predetermined positions in a succession of planes perpendicular to the casing and spaced apart axially along the casing. Each electronic unit comprises communication means enabling the electronic unit to communicate with another electronic unit or with a surface terminal, a power supply unit of the electronic unit, and at least one of the following elements: a) a detector unit comprising at least one sensor for sensing a physical or chemical magnitude, and b) a signal processor unit. | ||||||
| 199 | SYSTEMS, METHODS, AND COMPUTER-READABLE MEDIA FOR DETERMINING SHEAR-WAVE TO COMPRESSIONAL-WAVE VELOCITY RATIOS IN WELL CASINGS | US15270518 | 2016-09-20 | US20170090058A1 | 2017-03-30 | Thilo Michael Brill |
| Systems, methods, and computer-readable media for determining shear-wave to compressional-wave velocity ratios in well casings are provided. A logging tool may include one or more acoustic phased arrays, such as one or more transmitter arrays and one or more receiver arrays each having multiple transducer elements. Peak pulse amplitudes may be calculated from received acoustic signals, and the group velocity of the peak mode may be calculated. The peak amplitude from measurements over a suitable incidence angle range may be used to determine the value of the shear-wave to compressional-wave velocity ratio. | ||||||
| 200 | Determining cement impedance from a formation boundary | US14418737 | 2014-07-15 | US09606254B2 | 2017-03-28 | Arthur Chuen Hon Cheng; Mark Elliott Willis; Tatiana Gilstrap; Robert Eric Epstein |
| Systems, methods, and software for determining properties of a medium surrounding an exterior portion of a well casing are described. In some aspects, the properties of the medium are determined based on measurements of detected acoustic energy and distances between one or more acoustic transmitters and two or more acoustic receivers. The measurements are obtained based on operating the transmitters and the receivers within a wellbore that includes the well casing. | ||||||
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