Abstract: A method and system for a rotary steerable system (RSS). The method may comprise disposing the RSS into a borehole, identifying a failure from the one or more tracking measurements, the mechanical operation of the RSS, or the one or more sensors from a diagnostic review. Additionally, the method may further comprise flagging the failure with a failure code and reporting the failure and its mitigation actions to personnel in real time. The system may comprise one or more sensors configured to measure a location the RSS in a formation from one or more tracking measurements and monitor a mechanical operation of the RSS. The system may further comprise an information handling system.

Abstract: Two control strategies may be implemented to optimize mud circulation in a drilling mud circulation system. In a networked control strategy, the mud circulation system does not involve any centralized controller yet all the local controllers can exchange information in real-time via a central data storage. The master-slave control strategy involves a centralized optimizer, and the subsystems are treated as slave systems and are driven by a visual master control system.

Abstract: A system and method for implementing a neural network based vehicle dynamics model are disclosed. A particular embodiment includes: training a machine learning system with a training dataset corresponding to a desired autonomous vehicle simulation environment; receiving vehicle control command data and vehicle status data, the vehicle control command data not including vehicle component types or characteristics of a specific vehicle; by use of the trained machine learning system, the vehicle control command data, and vehicle status data, generating simulated vehicle dynamics data including predicted vehicle acceleration data; providing the simulated vehicle dynamics data to an autonomous vehicle simulation system implementing the autonomous vehicle simulation environment; and using data produced by the autonomous vehicle simulation system to modify the vehicle status data for a subsequent iteration.

Abstract: Systems and methods for generating a curtain plot that includes two inverted parameters based on the formation boundaries and the formation resistivity, the uncertainties of the formation boundaries, and the uncertainties of the drilled well-path, generating an updated curtain plot that includes two projected inverted parameters based on updated formation boundaries and updated formation resistivity, the projected uncertainties of the updated formation boundaries, and the projected uncertainties of the planned well-path, and avoiding, by the drilling operations, the uncertainties of the formation boundaries of the curtain plot and the updated curtain plot based on the two inverted parameters and the two projected inverted parameters to maintain or adjust the planned well-path within the projected uncertainties of the planned well-path.

Abstract: A method can include, during drilling operations at a wellsite, receiving operational data, where the data include hookload data, surface rotation data and block position data; training a controller using the hookload data, the surface rotation data and the block position data for determination of one or more transition thresholds, where the transitions thresholds include an in-slips to out-of-slips transition threshold and an out-of-slips to in-slips transition threshold; during the drilling operations, receiving additional operational data that include additional hookload data; and storing at least a portion of the additional operational data in association with slips state as determined based at least in part on a comparison of at least a portion of the additional hookload data and at least one of the determined transition thresholds.

Abstract: A system and method for determining an uncertainty of a distance to bed boundary (DTBB) inversion of a geologic formation. The system or method includes receiving logging data from a borehole tool, performing a first DTBB inversion using the logging data to calculate first DTBB solutions, adding quantified noise to the logging data to produce an adjusted signal, performing a second DTBB inversion using the adjusted signal to calculate second DTBB solutions, comparing the first DTBB solutions to the second DTBB solutions to determine an uncertainty of the first DTBB solutions based on a relationship of the quantified noise and the difference between the first DTBB solutions and the second DTBB solutions.

Abstract: Embodiments of the present disclosure are directed towards systems and method for characterizing wettability. Embodiments may include acquiring, using at least one processor, multi-physics data and transforming the multi-physics data into transformed data that is more sensitive to wettability than the multi-physics data. Embodiments may further include processing, using a data processing engine, the acquired and transformed data using at least one of a data correlation technique and an inversion technique.

Abstract: Example implementations involve a mechanism of distribution of products and services, which may have early signals of demand when such products are consumed by project based activities. By offering flexible demand and supply matching, an analytics engine platform predicts such demand, and constructs micro-contracts to match suppliers with project operators, anticipating their demand needs. The mechanisms can be applied to distribution of any kind of products or services in a supply chain which demand arises by planned projects.

Abstract: A system for optimizing a geothermal heating and cooling system operation comprises a drill rig and a processor. The drill rig is configured to construct a geothermal borehole according to operational parameters and deploy a coiled tubing or joint drill pipes enabled drill bit. The processor is configured to receive user specification of (i) one or input parameters and (ii) a first coefficient of performance (COP) of a heat pump for constructing the geothermal borehole. The processor is configured to apply a model to determine the set of operational parameters for constructing the first geothermal borehole. The processor is configured to collect, in real time during the construction, sensor data from sensors positioned on the drill bit, update the model according to the sensor data, update the operational parameters according to the updated model, and control the construction of the first geothermal borehole according to the updated operational parameters.

Abstract: A method may include obtaining, by the computer processor, rig operation data regarding various drilling rigs at different geographic locations. The method may further include generating, using the rig operation data, a model that identifies a level of risk associated with various rig operations. The method may further include simulating, by the computer processor and using the geographic location data and the model, a sequence of rig operations for constructing a portion of a wellbore drilled by a drilling rig at the desired geographic location.

Abstract: A system for communicating between equipment on a plurality of skids associated with a drill rig and a database server remote from the drill rig includes a data acquisition board on the drill rig. A plurality of sensors on the drill rig are configured to transmit data associated with the equipment on the plurality of skids to the data acquisition board. A processor in communication with the data acquisition board is configured to execute a first logic that causes the processor to receive the data from each sensor within a project area defined by a predetermined distance from an predefined reference point or a predetermined list, format said received data, and transfer the received data to the database server.

Abstract: In an embodiment, a method is performed by a computer system. The method includes integrating a series of data inputs related to a well. The series of data inputs includes at least one real-time data input and at least one non-real-time data input. The method further includes based, at least in part, on a result of the integrating, facilitating a real-time display of performance data for the well. The real-time display includes information related to at least one of hydraulic surveillance and torque-and-drag surveillance.

Abstract: Systems, computer-readable media, and methods for performing a reservoir simulation by obtaining reservoir data; translating the reservoir data into grid properties to create a grid; dividing the grid into domains; generating coarse grids corresponding to each domain; processing the domains, where processing a domain includes: calculating pressure for the domain using a coarse grid corresponding to the domain, calculating flux for the domain using a coarse grid corresponding to the domain, and calculating transport of fluids for the domain using a coarse grid corresponding to the domain; and generating a reservoir simulation corresponding to the grid based on processing each domain. The domains can be processed in parallel on different computer systems, different processors, or different cores.

Abstract: A program content for execution at a system that is a part of a user's internal computer network is received, wherein the program content specifies data to be logged. It is determined that a data item identified by the program content belongs to a specific type. In response to the determination that the data item belongs to the specific type, it is determined whether the data item identified by the program content meets a filter specification separate from the program content. In response to a determination that the data item meets the filter specification, a log item of the data item is automatically sent to a remote system that is not a part of the user's internal computer network.

Abstract: Disclosed are methods for transmitting data to a downhole tool. The methods include the option of confirming receipt and implementation of the transmitted data by the downhole tool. The disclosed methods utilize changes in RPM of the tool to convey the data through three separate changes in RPM. The changes in RPM are used to generate pulses suitable for identifying preprogrammed actions found within the memory of the downhole tool.

Abstract: The disclosed embodiments include a method, apparatus, and computer program product configured to performing automated downhole wellbore trajectory control for correcting between an actual wellbore trajectory path and a planned wellbore trajectory path. For example, in one embodiment, a PID controller is configured to obtain real-time data gathered during the drilling operation, determine whether the actual wellbore trajectory path deviates from the planned wellbore trajectory path, and automatically initiate the downhole wellbore trajectory control to change the actual wellbore trajectory path to a modified correction path that is determined using a minimum incremental wellbore energy method.

Abstract: The accuracy of directional surveys may be improved using accelerometers, magnetometers, or both. A control system containing accelerometers is configured specifically to correct errors in bias and gain of each accelerometer by requiring the measured field strengths to be as constant as possible over several tool face angles over multiple points in a wellbore, even when all measurements are within a tangent or lateral section of a wellbore. Corrections for the bias and gain errors determined based on one or more measurements from the accelerometers are applied to measurements at other survey points to improve the accuracy of surveys and the efficiency of drilling operations.

Abstract: A cutting tool for a tunnel boring machine, including a tool head equipped with a wear sensor detachably connectable to a tool holder. A line arrangement having a wireless, connector-free coupling module between the tool head and the tool holder is provided for connecting the wear sensors to an evaluation module. In the event of wear, a tool head to be replaced may be removed from the tool holder and a new tool head may be connected to the tool holder.

Abstract: A method for enhanced dispersion analysis begins with obtaining a plurality of measured waveforms, for example from two or more receivers of an acoustic logging tool placed in a borehole. The measured waveforms are divided into common gathers, and waveforms of each common gather are enhanced. The enhancement begins by calculating a travel time curve for a selected target mode of the common gather waveforms. Using the travel time curve, waveforms of the selected target mode are aligned to have zero apparent slowness. The aligned waveforms are filtered to suppress non-target mode waves. The aligned waveforms are then enhanced, and used to generate an enhanced dispersion curve of the selected target mode.

Abstract: A method for generating acoustic images corrected for distortions caused by attenuation of the ultrasonic signal by the mud may comprise disposing a downhole tool into a borehole, transmitting a pressure pulse from at least one transducer into the borehole, recording an echo with the at least one transducer, measuring a travel time, measuring an amplitude, determining a geometry of the borehole, determining a location of the downhole tool in the borehole, calculating an incident angle, mapping a mud attenuation, and correcting an image. A system for generating acoustic images corrected for distortions caused by attenuation of the ultrasonic signal by the mud comprising a downhole tool that may comprise a measuring assembly, wherein the measuring assembly comprises at least one transducer and wherein the at least one transducer is configured to emit a pressure pulse and record an echo. The system may further comprise an information handling system.

Abstract: Systems including a plurality of sensors disposed on a bottom hole assembly (BHA) configured to provide data to a controller, wherein a drill bit is connected to a bottom of the BHA; and a controller configured to: receive a well plan; receive, at a first stationary survey station, locational data and directional data of the BHA from the plurality of sensors; create steering instructions based on the well plan, historical drilling data, and the locational and directional data; generate a predicted future position of the drill bit for each of a plurality of stationary survey stations subsequent to the first stationary survey station assuming implementation of the steering instructions; display the predicted future position of the drill bit for each stationary survey station on a graphical user interface; receive directions to implement, reject, or revise the steering instructions; and execute the received directions. Methods and machine-readable media are also included.

Abstract: A supervisory control system for a well construction rig operable to perform well construction operations to construct a planned well at a wellsite. The supervisory control system may be installable in association with the well construction rig. The supervisory control system may comprise a supervisory controller communicatively connectable with a central controller of a rig control system of the well construction rig. The rig control system may be communicatively connected with and operable to control well construction equipment of the well construction rig. The supervisory controller may be operable to control the well construction equipment via the rig control system to cause the well construction equipment to perform the well construction operations. The central controller may be operable as an I/O interface for matching inputs and outputs of the supervisory controller with corresponding inputs and outputs of at least one piece of the well construction equipment.

Abstract: A drill head position determination system may include a mast, a drill head movably attached to the mast, and a drill drive assembly configured to move the drill head up and down along a length of the mast. The drill head may be configured to rotate a drill string. The drill drive assembly may include at least one sheave and a cable system wound about the at least one sheave. The drill head position determination system may further include a sheave sensor operatively coupled to the at least one sheave and configured to determine a position of the drill head based on a measured rotational position of the at least one sheave.

Abstract: A system 10 for controlling a drilling operation by a drill rig 12 includes a receiver 16 for receiving sensed data related to the drilling operation. A processor 18 is in communication with the receiver 16, the processor 18 processing the sensed data to estimate at least one geological property of interest of a zone 20 in which the drill rig 12 is active. The processor 18 is configured to operate as a decision engine 22 to optimize the drilling operation automatically by changing at least one drilling related parameter during the drilling operation based on the at least one geological property of interest.

Abstract: A method is described for determining a measure of geo-mechanical strength of subterranean rock at the cutting surface of a drill bit during drilling using a single measurement related to mechanical power at the drill bit. This measurement in combination with a measure of volumetric rate of rock failure defines an expression for mechanical specific energy (SMSE). SMSE is the mechanical power at the drill bit divided by volumetric rate of rock failure over any time interval. A method is described for predicting geo-mechanical and physical properties (lithology) of subterranean rock at the cutting surface of a drill bit during drilling operations using machine learning (data analytical) model(s). Said models are driven by a set of subterranean measurements related to the structural, physical response of subterranean rock mechanical failure in combination with the measure of SMSE.

Abstract: Disclosed are methods, systems, and computer-readable medium to perform operations including: receiving a real-time density log comprising bulk density readings of a subterranean formation, where a well is being drilled in the subterranean formation; aggregating density readings over a first threshold distance from a current drilling depth in the subterranean formation; calculating a minimum formation density and a maximum formation density in the aggregated density readings; calculating a difference between the maximum formation density and the minimum formation density; in response to determining that the difference is greater than a field threshold, determining whether a previous kick alert occurred at least a second threshold distance from the current drilling depth; and in response to determining that the previous kick alert occurred at least the second threshold distance from the current drilling depth, detecting a kick in the well.

Abstract: The present disclosure describes computer-implemented method for monitoring a well operation, the method including: accessing a plurality of streams of data received from multiple sources during the well operation, wherein: the multiple sources include a well testing process, a biosteering process, a geosteering process, and a drilling process, and the well operation includes sidetracking and drilling one or more laterals from a motherbore; combining the plurality of streams of data on a single montage with a common horizontal axis to track the one or more laterals from the motherbore; and presenting the single montage on a display device to an operator running the well operation.

Abstract: Methods, systems, and apparatus, including computer programs encoded on a computer storage medium, for improving wellbore stability and minimizing wellbore failure issues. In one aspect, a method includes receiving, for a well site, post-drilling parameters; clustering the received post-drilling parameters into groups based on an information type of each post-drilling parameter; generating a correlation model by applying a numerical analysis or a statistical analysis to the post-drilling parameters included in each of the groups; determining a resolution to avoid wellbore failure at a new well site by processing information regarding the new well site through the correlation model; and transmitting the resolution for implementation at the well site.

Abstract: Raw, real-time drilling data is pulled from a centralized database for processing. The raw, real-time drilling data is re-formatted into a format required for processing by one or more predictive models. Real-time processing is performed with respect to one or more drilling parameters associated with the re-formatted data using the one or more predictive models to generate output data. The output data received from the one or more predictive models is re-formatted for storage in the centralized database. The reformatted output data is retrieved from the centralized database for analysis with respect to visualization, generating alerts, or generating recommendations.

Abstract: A system and a method for a look-ahead drill bit. The system may comprise an ultra-deep transmitter operable to transmit a low frequency signal into a formation, a shallow tool operable to transmit a high frequency signal into the formation, at least one ultra-deep receiver operable to record a reflected low frequency signal, and at least one pair of collocated receivers, wherein the at least one pair of collocated receivers are operable to record a reflected high frequency signal. A method may comprise transmitting a high frequency signal from the shallow tool into the formation, transmitting a low frequency signal from the ultra-deep transmitter into the formation, evaluating the reflected high frequency signal and the reflected low frequency signal on an information handling system with a look-ahead inversion, and steering the bottom hole assembly in the formation based on the subterranean formation property.

Abstract: Provided is a method for selecting one of a plurality of convergence paths that may be drilled by a bottom hole assembly (BHA) comprising identifying, by a computer system, a plurality of geometric convergence paths, wherein each of the geometric convergence paths provides a convergence solution from a defined bottom hole assembly (BHA) location to a target drilling path of a well plan. An offset distance is calculated for drilling by the BHA each of the geometric convergence paths connecting the BHA location to the target drilling path. A drill path curvature associated with drilling each of the geometric convergence paths by the BHA is determined by the computer system. A time required for drilling each of the geometric convergence paths by the BHA is determined by the computer system.

Abstract: A rotary steerable system (RSS) including an upper stabilizer connected to a collar of a drill string, an articulated section connected by a flexible joint to the collar, a drill bit connected to the articulated section opposite from the flexible joint, a lower stabilizer located proximate to the flexible joint and an actuator located with the articulated section and selectively operable to tilt an axis of the drill bit and the articulated section relative to the collar. A method includes drilling with the RSS a bias phase of a drilling cycle on a demand tool face and drilling a neutral phase of the drilling cycle on a 180 degree offset tool face from the demand tool face.

Abstract: The present invention relates to a method of determining present-day horizontal stresses in geological formations. The method comprises dividing the received well data in a plurality of contiguous sets of data i, a set of data For each set of data i in the plurality of sets of data, determining, at least parameters Pi, a pressure in subsoil i, bi, a Biot coefficient i, ?i, a Poisson's ratio i, ??i, a vertical constraints in subsoil i, Ei, a Young's modulus i, ?i, a thermal expansion coefficient, and Ti, and a subsoil temperature i. The method further comprises, i, computing and outputting the horizontal constraints.

Abstract: In one embodiment, a method includes facilitating a real-time display of drilling-performance data for a current well. The method further includes receiving new channel data for the current well from a wellsite computer system. The method also retrieving input data including historical drilling-performance data for an offset well relative to the current well. In addition, the method includes computing calculated data for the current well based on the channel data and the input data. Moreover, the method includes updating the real-time display with the calculated data.

Abstract: A method for detecting and predicting an epileptic seizure. The method includes preparing a plurality of electrical signals, extracting a plurality of patterns from the plurality of electrical signals, extracting a plurality of features from the plurality of electrical signals by applying the plurality of patterns on the plurality of electrical signals, optimizing the plurality of patterns and the plurality of features, and classifying each of the plurality of electrical signals in a plurality of classes by applying a plurality of classifiers on the plurality of features. The plurality of electrical signals include a plurality of samples. The plurality of classes include a seizure class and a non-seizure class, and the plurality of classifiers include a plurality of cascaded AdaBoost classifiers.

Abstract: An apparatus associated with a drilling rig includes a surface steerable system for controlling drilling direction of a bottom hole assembly (BHA). The surface steerable system is configured to receive drilling rig parameters from the BHA. A database stores historical data related to the drilling rig. The historical data relates to previously tracked operations of the drilling rig. The surface steerable system is further configured to perform a plurality of tracking functions with respect to the drilling rig parameters. The plurality of tracking functions cause the surface steerable system to track drilling rig parameters from sensors associated with the drilling rig, access the database of the historical data relating to previously tracked operations of the drilling rig and control operating functions of the drilling rig responsive to at least one of the drilling rig parameters from the sensors associated with the drilling rig and the historical data from the database.

Abstract: Systems and methods for displaying a preferred well on a mobile device displaying data for another well and reconfiguring a system based on geographical coordinates for the mobile device and/or the system.

Abstract: Various implementations described herein are directed to a method for surveying a wellbore. A statistical estimation process that combines magnetic survey measurement data and gyroscopic survey measurement data to form error estimates in a magnetic survey system is applied. The error estimates are used to correct magnetic survey data provided by the magnetic survey system. Magnetic only survey data is used when convergence of the error estimates has occurred. Information that facilitates drilling the wellbore is provided.

Abstract: A downhole closed loop method for controlling a drilling toolface includes measuring first and second attitudes of the subterranean borehole at corresponding first and second upper and lower survey stations. The first and second attitudes are processed downhole while drilling to compute an angle change of the subterranean borehole between the upper and lower survey stations. The computed angle change is compared with a predetermined threshold. This process may be continuously repeated while the angle change is less than the threshold. The first and second attitudes are further processed downhole to compute a toolface angle when the angle change of the subterranean borehole is greater than or equal to the threshold. The toolface angle may then be further processed to control a direction of drilling of the subterranean borehole.

Abstract: A measurement-while-drilling method and device assesses outburst risk and evaluates gas drainage performance of a coal seam. The device includes a compartment, a pressure sensor, a temperature sensor, a flow sensor, an electromagnetic sensor, an acoustic sensor, a wave velocity measurement module, a monitoring and control module, a power supply and a communication interface. These are installed between a drill bit and an inclinometer or a first drill pipe. Measurements are performed while drilling to obtain a real time gas parameter, lithologic and coal seam information, for on-site assessment of outburst risk. During drill bit replacement, gas pressure, temperature, flow velocity, wave velocity, electromagnetic radiation, and an acoustic signal are recorded in real time, to calculate stress of the coal seam and coal seam outburst risk. On-site measurement is done while drilling without sampling and can use multiple parameters to perform synchronous measurement to obtain a comprehensive evaluation.

Abstract: A method for wellbore construction management includes measuring at least one drilling operating parameter during drilling of a wellbore. At least one well state parameter is calculated from the measured drilling operating parameter. A difference between the calculated well state parameter and a predetermined value of the well state parameter is determined. When the difference exceeds a selected threshold a modified well plan is calculated comprising at least one drilling task to enable construction of at least part of the wellbore to conform to the modified well plan. The at least one drilling task is displayed to a user.

Abstract: The disclosed embodiments include a system, method, or computer-program product configured to performing automated wellbore trajectory control for correcting between an actual wellbore trajectory path and a planned wellbore trajectory path. For example, in one embodiment, a controller is configured to obtain real-time data gathered during the drilling operation, determine whether the actual wellbore trajectory path deviates from the planned wellbore trajectory path, and automatically initiate the wellbore trajectory control to change the actual wellbore trajectory path to a minimum-incremental wellbore energy correction path using provided correction constraints. The correction path may optionally include spline, catenary, circular arc, or clothoid curves.

Abstract: Systems and methods for determining azimuth of a wellbore while drilling. A method of drilling a wellbore that includes rotating a drill bit to extend the wellbore into a subterranean formation. The method may further include measuring magnetic toolface with a first magnetometer while rotating the drill bit. The method may further include obtaining a cross-axial magnetic field measurement. The method may further include determining azimuth at a point in the wellbore using at least the magnetic toolface and the cross-axial magnetic field measurement. The method may further include using the azimuth as feedback in the drilling the wellbore.

Abstract: In accordance with some embodiments of the present disclosure, systems and methods for an advanced toolface control system for a rotary steerable drilling tool is disclosed. The method includes determining a desired toolface of a drilling tool, calculating a toolface error by determining a difference between a current toolface of the drilling tool and the desired toolface, decoupling a response of a first component of the drilling tool, calculating a correction to reduce the toolface error based on a model of the drilling tool containing information about a source of the toolface error, transmitting a signal to a second component of the drilling tool such that the signal adjusts the current toolface based on the correction, and drilling a wellbore with a drill bit oriented at the desired toolface.

Abstract: A method for operating a drilling plant machine includes providing a drilling plant machine which includes a sensor which measures a parameter which is indicative of a jarring load acting on the drilling plant machine from a drill string, providing a set of values representing readings from the sensor, identifying a jarring event, and determining a magnitude of the parameter from the set of values.

Abstract: The present disclosure describes methods and systems, including computer-implemented methods, computer program products, and computer systems, for determining a mudweight of drilling fluids in a hydrocarbon reservoir. One computer-implemented method includes: receiving pore pressure data of a rock formation in the hydrocarbon reservoir; determining permeability data of fractures of the hydrocarbon reservoir; determining Hoek-Brown failure criterion data; and determining a safe mudweight window based on the pore pressure data of the rock formation, the permeability data of the fractures, and the Hoek-Brown failure criterion data.

Abstract: Unwanted oscillations of a drill string while a borehole is being drilled are limited by adjusting a drilling parameter. Measurements related to oscillations of the drill string can be extrapolated by calculation to a position of interest along the drill string using a mode identified from one or more determined modes and a stability criterion that models the drill string. The stability criterion includes a specific modal damping for each of the one or more determined modes. The position of interest may correspond to a location of a tool or component that may be damaged by the unwanted oscillations. If the tool or component can be damaged by the oscillations as calculated, then the drilling parameter is adjusted to limit those oscillations.

Abstract: The invention relates to systems, processes and apparatuses for determining a rig-state of a drilling rig during a wellbore drilling operation and detecting and mitigating drilling dysfunctions. These systems, processes and apparatuses provide a computer with a memory and a processor, a plurality of sensors associated with a wellbore drilling operation for acquiring time series data wherein the data are formatted for sample and bandwidth regularization and time-corrected to provide substantially time-synchronized data, a processing graph of data-stream networked mathematical operators that applies continuous analytics to the data at least as rapidly as the data are acquired to determine dynamic conditions of a plurality of rig conditions associated with the wellbore drilling operation and determining a rig-state from the plurality of rig conditions.

Abstract: Technology for obtaining formation parameters of a geological formation includes measuring a resistivity image of the geological formation. The measured resistivity image is compared to a modelled resistivity image where the modelled resistivity image is generated based on estimated formation parameters. A cost function is calculated based on the measure resistivity image and the modelled resistivity image. The estimated formation parameters are adjusted based on minimizing the cost function in order to generate a set of final formation parameters that represents a modelled resistivity image having a smallest cost function.

Abstract: The current invention utilizes a downhole gamma ray counter having a processor and database to radially allocate gamma ray counts into buckets. Once a circumferential count is completed the buckets are utilized to form a pattern. The created pattern is then compared to various patterns within the database. Once a corresponding pattern is found within the database a value that is assigned to that pattern is transmitted to the surface. On the surface a surface processor compares the value to the values within the surface database finding the pattern assigned to that value. The surface processor and estimates the time of creation of the pattern downhole and uses the estimated time of creation and the pattern from the surface database to create an image of a portion of a wellbore.