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.

Abstract: Systems and methods are disclosed that provide highly accurate and controllable measurements of rock formation properties in a wellbore. The systems and methods utilize a prescribed input signal to mechanically perturb a drill string in contact with a rock formation in order to elicit a mechanical response. Based on the input signal and the mechanical response, a transfer function is computed and analyzed, wherein the analysis uses estimates of the drill string resonances to identify rock formation resonances, which are used, in turn, to determine the rock formation properties.

Abstract: A method for selecting drilling parameters for drilling a borehole penetrating the earth with a drill string includes: varying a frequency of an excitation force applied to the drill string using an excitation device controlled by a drill string controller and measuring vibration-related amplitudes of the drill string due to the applied excitation force using a vibration sensor to provide amplitude measurements. The method further includes determining one or more modal properties comprising one or more eigenfrequencies of the drill string using the amplitude measurements and selecting drilling parameters that apply an excitation force at a frequency that avoids a selected range of frequencies that bound the one or more eigenfrequencies.

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 method, comprising acquiring annular pressure data from a wellbore where the annular pressure data is acquired over a time interval and at least a portion of the annular pressure data is acquired during a pumps-off period. At least first and second values are identified from the annular pressure data and the variation between the first and second values are compared to a first threshold. Drilling equipment is operated based on the comparison with the first threshold.

Abstract: Systems, methods, and devices for evaluation of an earth formation intersected by a borehole using a logging tool. Tools include sensor assemblies with permanent magnets mounted at a first radial distance from an axis of rotation of the sensor assembly, as well as receiver sensors. The sensor assembly is configured to generate an alternating current in a volume of interest of the formation surrounding the borehole with a time varying magnetic field in the volume produced by rotating the sensor assembly about the axis of rotation. Methods include making EM signal measurements or magnetic field measurements with receiver sensors responsive to the alternating current and estimating at least a formation property of the volume using the measurements.

Abstract: A method for drilling a well includes prescribing a drill recipe with a drill analysis engine based on a field-specific model. The drill recipe identifies prescribed segments, mud flow parameters, and drill parameters. Each prescribed segment of the prescribed segments includes a start depth. The method further includes initiating drilling of the well based on the drill recipe; receiving a drill log in narrative text format; detecting a drill event inconsistent with the drill recipe by analyzing the drill log with a log analysis engine; prescribing an adjusted drill recipe with the drill analysis engine based on the field-specific model in response to the drill event, the adjusted drill recipe including adjusted prescribed segments; and drilling the well based on the adjusted drill recipe.

Abstract: The present disclosure generally relates to a real-time synthetic logging method for optimizing one or more operations in a well. The method generally includes receiving measurements of one or more parameters in real time while performing operations in the well, the measurements being captured without using tools that include active nuclear sources. The method further includes providing the measurements as input to a machine learning algorithm (MLA) that is trained using historical or training well data. The method further includes generating, using the MLA and based on the measurements, a synthetic mechanical property log of the well. The method further includes generating, based on the synthetic mechanical property log, optimized parameters for at least one operation selected from the following list: drilling the well in real-time; steering the well in real-time; and stimulating a reservoir in real-time.

Abstract: A method for monitoring performance of an electric submersible pump. The method includes receiving data indicating a plurality of observable parameters from one or more sensors, generating a reduced set of components representative of at least some of the observable parameters and the reduced set having a dimensionality less than the plurality of observable parameters, identifying one or more components of the reduced set that captures a total variance of the plurality of observable parameters above a predetermined threshold, constructing at least one manifold of normal operation of the electric submersible pump in a reduced component space, receiving additional data from the sensors, transforming the additional data into the identified components establishing an electric submersible pump performance, and detecting whether a deviation of the electric submersible pump performance from a normal mode of operation of the electric submersible pump exceeds a predetermined threshold.

Abstract: Tools and method for automatically controlling torque when making-up and/or breaking-down threaded connections between downhole assets such as drill pipe, drill collars, and BAH components. An iron roughneck may be controlled by, for instance, automatically monitoring and adjusting the fluid pressure of cylinders that ultimately provide the torque to the downhole assets. The torque may further be automatically controlled by automatically identifying the downhole assets and selecting a corresponding torque profile or target torque. Clamping force may also be controlled, and is optionally proportional to the target torque.

Abstract: A control system for controlling stick-slip oscillations in a drilling system is disclosed. The control system includes a processor and a memory communicatively coupled to the processor with computer program instructions stored therein. The instructions are configured to, when executed by the processor, cause the processor to receive a communication including a value of a drilling system parameter, determine based on the value of the drilling system parameter, a value for a torque to be applied to a drill string to reduce the effect of stick-slip oscillations, and transmit to a drive system the value for the torque to be applied by the drive system. The value for the torque to be applied by the drive system is determined by solving a set of linear matrix inequalities including a disturbance minimization linear matrix inequality, a first magnitude constraint linear matrix inequality, and a second magnitude constraint linear matrix inequality.

Abstract: A method may include providing a drill string positioned in a wellbore including a measurement tool. The method may include taking a measurement with the measurement tool at a first location; coupling a pipe stand including a first selected number of tubular segments to the drill string, the first selected number being two or more; lowering or advancing the drill string into the wellbore the length of the pipe stand; taking a measurement with the measurement tool at a second location; raising the drill string the length of a tubular segment; removing a second selected number of tubular segments from the drill string; taking a measurement with the measurement tool at a third location; raising the drill string the length of the first selected number of tubular segments; removing the first selected number of tubular segments; and taking a measurement with the measurement tool at a fourth location.

Abstract: A method of drilling a well within a target stratum. The method can include drilling based upon a target window created from previously collected and/or extrapolated data. Data is collected while drilling and the target window can be adjusted “on the fly” as well as updating and correcting previously collected data. The method can be repeated to ensure optimal drilling efficiency and minimal down time while drilling.

Abstract: Embodiments of systems and methods to control directional drilling in borehole drilling for hydrocarbon wells are disclosed. An actual toolface orientation measurement value and an actual downhole torque on bit (DTOB) or actual downhole weight on bit (DWOB) measurement value for a drill string positioned in a borehole are determined. Responsive to a comparison of target measurement values and actual measurement values, error values are determined. A control command for one or more of a top drive, a drawworks, and a mud pump responsive to the DTOB or DWOB error value and the toolface orientation error value is determined. Additionally, one or more of the top drive, the drawworks, and the mud pump are operated responsive to the control command thereby to correct a toolface orientation of the drill string.

Abstract: Methods and control systems for optimizing production of a hydrocarbon well with a local controller in communication with a supervisory control and data acquisition (SCADA) system are disclosed. The presently disclosed methods may include calculating, at the local controller, optimal targets for one or more well parameters using measured values associated with operation of the hydrocarbon well; obtaining, at the local controller, a model that comprises a relationship between an operation of a gas injection choke and an operation of a production choke with the one or more well parameters based on the measurement values and received model parameters from the SCADA system; determining, at the local controller, operating set points based on the model for control of at least one of the production choke and the gas injection choke; and operating at least one of the production choke and the gas injection choke for optimized production.

Abstract: Mud pulse telemetry. The various embodiments are directed to methods and systems of encoding data in a mud pulse telemetry system, where at least a portion of the data is encoded the time between pressure transitions. Moreover, the various embodiments are directed to detection methods and systems that detect the pressure transitions at the surface.

Abstract: A drilling system and associated systems and methods for monitoring, controlling, and predicting vibration of a drilling operation. The vibration information can include axial, lateral or torsional vibration of a drill string.

Abstract: A fitness system for enhancing the effectiveness and efficiency of physical training and/or exercise by a user comprises uses (1) a plurality of sensors that are worn by an exercising user and which generate data concerning monitored body processes pertaining to the exercise's effects on the user's body, (2) a processor operates under software control for processing, storing, and analyzing the data, and sending the processed data to a host device using a wireless communication protocol to communicate desired adjustments to the exercise in real time. The host device can be a smartphone, tablet computer or other web accessible device that can display and communicate bilaterally with the processor.

Abstract: Data collected during reservoir monitoring may include fiber optic measurements utilizing a distributed sensing system. Downhole monitoring with the distributed sensing system may generate large amounts of data. For example, the system may be capable of producing the functional equivalent of tens, hundreds, or even thousands of sensors along a length of a wellbore. Continuous monitoring of various properties, including temperature, pressure, Bragg gradient, acoustic, and strain, may create a large volume of data, possibly spanning into several gigabytes. Embodiments of the present invention provide techniques for analyzing a large volume of measurements taken in a wellbore without compromising on the integrity of data.

Abstract: A blowout rate correction system comprises a sensor and a processor in communication with the sensor. The sensor is to measure sound characteristics associated with an exit point of a borehole. The processor is to determine a blowout rate of hydrocarbons exiting the borehole based on the sound characteristics. In some embodiments, the processor activates a device when the blowout rate exceeds a selected threshold. Additional apparatus, methods, and systems are disclosed.

Abstract: Method for estimating porosity and water saturation or other geological parameters of a subsurface region when the lithology of the region is unknown, requiring only geophysical data from remote surveys. The geophysical data are inverted (14-18) treating lithology as a third, and discrete, unknown model parameter (12) to be solved for in the inversion. A technique for solving mixed integer non-linear programs may be used. Suitable rock physics relationships (13) are used to relate the desired geological parameters to the geophysical model parameters required for simulating the geophysical data in the inversion process.

Abstract: A tool for use in a borehole penetrating a formation method and a method for using the tool is disclosed. The tool includes a gyroscope for obtaining a first measurement of a rotation rate of the apparatus and at least one accelerometer for obtaining a second measurement of the rotation rate of the apparatus. A processor generates an estimate of the rotation rate using at least one of the first measurement of rotation rate and the second measurement of rotation rate. The estimate of the rotation rate is sued to determine a rotational position of a formation parameter measurement obtained during rotation of the apparatus in the borehole.

Abstract: Examples of techniques for monitoring a component used in well operation are disclosed. In one example implementation according to aspects of the present disclosure, a method may include: receiving, by a processing system, sensor data from a sensor, wherein the sensor collects data relating to a component used in the well operation; analyzing, by the processing system, the sensor data to determine whether the component used in the well operation is experiencing an error condition; and alerting, by the processing system, a user of the error condition when it is determined that the component used in the well operation is experiencing an error condition.

Abstract: A method for drilling a well includes prescribing a drill recipe using a drill analysis engine based on a field-specific model. The drill recipe identifies prescribed segments. Each prescribed segment of the prescribed segments includes a start depth. The method further includes initiating drilling of the well based on the drill recipe; detecting a drill event inconsistent with the drill recipe; prescribing an adjusted drill recipe using the drill analysis engine based on the field-specific model in response to the drill event, the adjusted drill recipe including adjusted prescribed segments; and drilling the well based on the adjusted drill recipe.

Abstract: Methods for drilling a wellbore within a subsurface region and drilling assemblies and systems that include and/or utilize the methods are disclosed herein. The methods include receiving a plurality of drilling performance indicator maps, normalizing the plurality of drilling performance indicator maps to generate a plurality of normalized maps, adaptive trending of the plurality of drilling performance indicator maps to generate a plurality of trended maps, summing the plurality of trended maps to generate an objective map, selecting a desired operating regime from the objective map, and adjusting at least one drilling operational parameter of a drilling rig based, at least in part, on the desired operating regime.

Abstract: Systems and methods for controlling a drilling rig. The system includes a first layer including a plurality of subsystem controllers coupled with a plurality of rig subsystems, the plurality of subsystem controllers being configured to control operating parameters of the plurality of rig subsystems. The system also includes a second layer configured to receive information from the first layer based on an operation of the plurality of rig subsystems, and to provide control of the plurality of rig subsystems. The system further includes a third layer configured to execute one or more process applications and to provide a task-based command to the second layer.

Abstract: A system and method for modeling seismic data using time preserving tomography including storing an initial set of parameter values representing an initial seismic data model. The initial seismic model may correspond to at least two or more ray pairs. Each ray pair may have a traveltime. An altered model may be generated by altering two or more parameter values in the initial set of parameter values for each of two or more ray pairs in the initial model. Altering one parameter value without altering the remaining of the two or more parameter values may correspond to a change in the traveltime of each of the ray pairs, while altering the two or more parameter values in combination typically corresponds to no net change in the traveltime of each of the ray pairs.

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: A method for optimizing drilling includes initializing values of a plurality of drilling operating parameters and drilling response parameters. In a computer, an initial relationship between the plurality of drilling operating parameters and drilling response parameters is determined. A drilling unit to drill a wellbore through subsurface formations. The drilling operating parameters and drilling response parameters are measured during drilling and entered into the computer. A range of values and an optimum value for at least one of the drilling response parameters and at least one of the drilling response parameters is determined in the computer. A display of the at least one of the plurality of drilling operating parameters and the at least one of the drilling response parameters is generated by the computer.

Abstract: A method of drilling a well within a target stratum. The method can include drilling based upon a target window created from previously collected and/or extrapolated data. Data is collected while drilling and the target window can be adjusted “on the fly” as well as updating and correcting previously collected data. The method can be repeated to ensure optimal drilling efficiency and minimal down time while drilling.

Abstract: Proposed is a system and a method for a parametric risk transfer system based on automated location-dependent probabilistic tropical storm risk and storm impact forecast, wherein weather measuring parameters of weather events are measured by means of a plurality of delocalized distributed weather flow stations and transmitted to a central system, and wherein the measured weather measuring parameters at least comprise measuring parameters of wind speed and/or maximum wind speed within a predefined time frame. A spatial high-resolution grid comprising grid cells is generated over a geographical area of interest, and a wind field profile is dynamically generated, wherein by triggering an indexed wind field parameter of the wind field profile exceeding a predefined trigger, an output activation signal is generated based on the wind field parameter and transmitted to an associated activation device, wherein the operation of the activation device is steered by the transmitted output activation signal.

Abstract: An embodiment of a method of performing an energy industry operation includes storing one or more sets of instructions at a storage location accessible by a controller configured to control aspects of an energy industry operation, the one or more sets of instructions retrieved from a library of sets of instructions, each set of instructions prescribing a standard procedure for performing a process forming part of the energy industry operation, the standard procedure based on best operating practices developed from previously performed operations independent of the process to be performed. The method also includes deploying a carrier in a borehole in an earth formation and performing an energy industry operation, monitoring the operation and, in response to detecting a condition associated with the process, automatically retrieving the set of instructions corresponding to the process, and automatically performing the process by the controller according to the retrieved set of instructions.

Abstract: The present disclosure generally relates to synthetic logging for reservoir stimulation. A synthetic logging method for stimulating a reservoir includes: training a machine learning algorithm using historical or exploratory data; and generating a synthetic elastic property log of the reservoir by supplying the trained machine learning algorithm with data acquired from a production wellbore.

Abstract: Various implementations directed to analyzing a reservoir using fluid analysis are provided. In one implementation, a method may include determining mud gas logging (MGL) data based on drilling mud associated with a wellbore traversing a reservoir of interest. The method may also include determining first downhole fluid analysis (DFA) data based on a first reservoir fluid sample obtained at a first measurement station in the wellbore. The method may further include determining predicted DFA data for the wellbore based on the first DFA data. The method may additionally include determining second DFA data based on a second reservoir fluid sample obtained at a second measurement station in the wellbore. The method may further include analyzing the reservoir based on a comparison of the MGL data and a comparison of the second DFA data to the predicted DFA data.