Patent application number | Description | Published |
20080215244 | Making Directional Measurements using a Rotating and Non-Rotating Drilling Apparatus - A system and method to determine directional measurements for a drilling tool that at times rotates and at other times does not rotate. The method comprises making a first set of measurements when the apparatus is rotating, making a second set of measurements when the apparatus is not rotating, and combining the first and second sets of measurements to obtain the directional measurements. The system comprises a transmitter-receiver pair wherein the transmitter has a magnetic dipole moment parallel to a longitudinal axis of the apparatus and the receiver has a magnetic dipole moment that is tilted relative to the longitudinal axis of the apparatus, an electronics module to excite the transmitter and detect a receiver signal to make a first set of measurements when the apparatus is rotating and a second set of measurements when the apparatus is not rotating, and a processor to combine the first and second sets of measurements to obtain the directional measurements. | 09-04-2008 |
20090015261 | DETERMINING FORMATION PARAMETERS USING ELECTROMAGNETIC COUPLING COMPONENTS - A method to determine one or more parameters of a formation traversed by a borehole, at least a portion of the formation having substantially parallel boundaries, the method comprising disposing a tool in the borehole, wherein the tool includes a transmitter having a dipole moment at an angle θ | 01-15-2009 |
20100030477 | ELECTROMAGNETIC DIRECTIONAL MEASUREMENTS FOR NON-PARALLEL BED FORMATIONS - An orientation vector, referred to hereinafter as the “geosteering vector,” is directed to the more conductive formation area within the DOI of the tool and away from the more resistive formation areas. Accordingly, drilling in a direction opposite the geosteering vector leads to more resistive formation. Also, the disclosed geosteering vectors obtained from the real and imaginary components will not align with each other for non-planar formations and therefore the misalignment of the geosteering obtained from real and imaginary components is indicative of a non-planar formation. A superposition method is disclosed which can be used to calculate electromagnetic (EM) couplings in a non-planar geometry formation (as well as in a planar geometry formation) in real time, without requiring two or three dimensional modeling calculations. | 02-04-2010 |
20100122847 | METHODS FOR VISUALIZING DISTANCES BETWEEN WELLBORE AND FORMATION BOUNDARIES - A method for displaying a formation model while drilling a wellbore in the formation includes operating a well logging instrument at a measurement point in the formation along a wellbore while the wellbore is being drilled. Measurement data regarding the formation are obtained from the well logging instrument. An actual orientation of a geological structure is determined from the measurement data. A trajectory of the wellbore is displayed in three dimensions as it is being drilled through the formation. While drilling the wellbore, the geological structure is displayed along the trajectory of the wellbore according to the determined actual orientation of the geological structure. The actual orientation reflects an azimuth angle of planes corresponding to the geological structure. The trajectory of the wellbore is changed in response to displaying the determined actual orientation of the geological structure relative to the trajectory. | 05-20-2010 |
20100201540 | SYSTEM AND METHOD FOR USING DUAL TELEMETRY - A system and a method use dual telemetry for tools located in a wellbore. A first telemetry system and a second telemetry system coordinate communication with the tools. Both the first telemetry system and the second telemetry system may transmit data regarding the tools and/or drilling conditions from the tools to a surface location simultaneously. The first telemetry system or the second telemetry system may communicate with the surface location if communication using the other telemetry system is interrupted. The first telemetry system and the second telemetry system may have a master/slave relationship so that data requests from a specific telemetry system do not interfere with data requests from the other telemetry system. | 08-12-2010 |
20100271233 | SURFACE COMMUNICATION APPARATUS AND METHOD FOR USE WITH DRILL STRING TELEMETRY - An operation of drilling an earth borehole uses a drilling rig, a drill string of drill pipes having its generally upper end mechanically coupleable with and suspendable from the drilling rig, a drive string portion of the drill string, mechanically coupleable with the topmost drill pipe of said drill string, and a drive mechanism mechanically coupleable with the drive string for rotating the drive string and the drill string. A system for generating electric power in the region of the drive string includes an electric generator, which includes a rotating generator component mounted on said drive string for rotation therewith and a stationary generator component mounted on a stationary portion of the drilling rig. The rotating generator component produces electric power in the region of the drive string. | 10-28-2010 |
20110140701 | DETERMINING PROPERTIES OF EARTH FORMATIONS USING THE ELECTROMAGNETIC COUPLING TENSOR - A system and method to determine earth formation properties by positioning a logging tool within a wellbore in the earth formation, the logging tool having a tool rotation axis and a first, a second, and a third tilted transmitter coil, and a tilted receiver coil; rotating the logging tool about the tool rotation axis; energizing each transmitter coil; measuring a coupling signal between each transmitter coil and the receiver coil for a plurality of angles of rotation; determining a coupling tensor; and determining the earth formation properties using the coupling tensor. | 06-16-2011 |
20110231098 | MULTILEVEL WORKFLOW METHOD TO EXTRACT RESISTIVITY ANISOTROPY DATA FROM 3D INDUCTION MEASUREMENTS - A method is provided for determining formation resistivity, anisotropy and dip from wellbore measurements includes moving a well logging instrument through subsurface formations. The instrument includes longitudinal magnetic dipoles and at least one of tilted and transverse magnetic dipoles. Formation layer boundaries and horizontal resistivities of the formation layers are determined from longitudinal magnetic dipole measurements. Vertical resistivities of the formation layers are determined by inversion of anisotropy sensitive measurements. Improved vertical resistivities of the formation layers and dips are determined by inverting symmetrized and anti-symmetrized measurements. Improved vertical resistivities, improved boundaries and improved dips are determined by inversion of the all dipole measurements. Improved horizontal resistivities, further improved layer boundaries and further improved dips are determined by inversion of all dipole measurements. | 09-22-2011 |
20120166086 | TRIAXIAL ANTENNA ELECTROMAGNETIC MEASUREMENTS - The present disclosure relates to a method to determine a formation property of a subsurface formation. A downhole logging tool having two or more antennas, at least one of the antennas being a non-co-located triaxial antenna, is provided. Azimuthally sensitive measurements are obtained using the antennas of the downhole logging tool. The measurements are fitted to a Fourier series having Fourier coefficients and the non-co-location of the triaxial antenna is compensated for by adjusting the Fourier coefficients. Compensated measurements are determined using the adjusted Fourier coefficients and the formation property of the subsurface formation is determined using the compensated measurements. The compensating may use one or more scale factors that depend on an amplitude, phase, and/or frequency of the received signal, and an alignment angle between the triaxial antenna and another of the antennas of the logging tool. | 06-28-2012 |
20120192640 | Borehole Imaging and Formation Evaluation While Drilling - A logging tool having a plurality of different sensor types having close spacings mounted on an articulated or extendible pad, a sleeve, a mandrel, a stabilizer, or some combination of those is provided and used to make measurements in a wellbore in a single logging run. Those measurements are used to create images of the wellbore and the images are used to deduce the local geology, optimize well placement, perform geomechanical investigation, optimize drilling operations, and perform formation evaluation. The logging tool includes a processor capable of making those measurements, creating those images, performing those operations, and making those determinations. The plurality of different sensors may be one or more resistivity sensors, dielectric sensors, acoustic sensors, ultrasonic sensors, caliper sensors, nuclear magnetic resonance sensors, natural spectral gamma ray sensors, spectroscopic sensors, cross-section capture sensors, and nuclear sensors, and they may be “plug-and-play” sensors. | 08-02-2012 |
20120286790 | Determining Formation Parameters Using Electromagnetic Coupling Components - A method and a downhole tool determine one or more parameters of a formation traversed by a borehole where at least a portion of the formation has substantially parallel boundaries. A tool is disposed in the borehole that includes a transmitter having a dipole moment at an angle θ | 11-15-2012 |
20130038463 | Interactive Display of Results Obtained from the Inversion of Logging Data - An interactive display of results obtained from the inversion of logging data is produced by obtaining and inverting the logging data using a Monte-Carlo inversion. An interactive plot having a percentile scale plotted against a location parameter is produced and a particular percentile is selected using the interactive plot. A cross-section plot for the particular percentile using the results of the Monte-Carlo inversion is produced. The particular percentile can be a curve representing a best-fit solution or a polyline representing selected solutions. Background color/shading can be displayed on the interactive plot to indicate user-defined constraints have been applied. Uncertain features can be plotted on a corresponding cross-section display using fading. Clusters of solutions that are substantially equally likely, given the measurements at a particular drill location, can be identified and plotted. A cross-section constructed from the layered models belonging to a particular cluster can be overlaid on another cross-section. | 02-14-2013 |
20140055277 | System and Method for Using Dual Telemetry - A system and a method use dual telemetry for tools located in a wellbore. A first telemetry system and a second telemetry system coordinate communication with the tools. Both the first telemetry system and the second telemetry system may transmit data regarding the tools and/or drilling conditions from the tools to a surface location simultaneously. The first telemetry system or the second telemetry system may communicate with the surface location if communication using the other telemetry system is interrupted. The first telemetry system and the second telemetry system may have a master/slave relationship so that data requests from a specific telemetry system do not interfere with data requests from the other telemetry system. | 02-27-2014 |
20140149040 | Multilevel Workflow Method To Extract Resistivity Anisotropy Data From Three-Dimensional Induction Measurements - A multi-step electromagnetic inversion method is provided for determining formation resistivity, anisotropy and dip. An electromagnetic logging tool is used to obtain non-directional, anisotropy, and directional (including symmetrized and anti-symmetrized resistivity measurements) in a formation using an electromagnetic logging tool. Bed boundaries of the formation are first identified. A horizontal resistivity profile is obtained using the non-directional resistivity measurements, and a vertical resistivity profile is obtained using the anisotropy resistivity measurements. The vertical resistivity profile is improved using the directional resistivity measurements, while dip values are also obtained via an inversion using the directional resistivity measurements. Then, an inversion for each of vertical resistivity, horizontal resistivity, dip values, and bed boundaries is performed using all of the non-directional, anisotropy, and directional resistivity measurements to obtain a formation model. | 05-29-2014 |
20140285204 | RESTORABLE ANTENNAE APPARATUS AND SYSTEM FOR WELL LOGGING - An apparatus includes a sub with recesses along an exterior wall to receive inserts, an antennae case including a coil surrounded by a sacrificial wear portion of a material through which signals between the coil and a formation of interest may pass. An eroded outer wall of the sacrificial wear portion is restorable by application of an uncured restorative material to the antennae case. A method includes securing an antennae case having a coil there within onto a sub, surrounding the coil with a metal sleeve shield, and radially receiving and securing a multi-piece sacrificial wear member intermediate the antennae case and a retainer ring having a threaded bore. The multi-piece sacrificial wear member is replaceable after use by unthreading the retainer ring to release the sacrificial wear member for radial removal from the sub. | 09-25-2014 |
20140285205 | WELL LOGGING APPARATUS AND SYSTEM - A system and apparatus for configuring a well logging assembly having an elongate sub with a bore therethrough, a leading end connection and a trailing end connection, a plurality of sets of recesses in an exterior wall of the sub to receive a plurality of sets of inserts, each having a threaded exterior surface, a plurality of internally threaded retainer rings, and a plurality of well logging devices securable to the exterior wall of the sub using the retainer rings to threadably engage the inserts received in the recesses. The system enables convenient configuration and reconfiguration of the well logging assembly by enabling convenient securing of a first well logging instrument to the sub at a variety of spacings from a second well logging instrument to provide a variety of depths of investigation into a geologic formation penetrated by a drill string containing the well logging assembly. | 09-25-2014 |