Abstract: The embodiments include systems and methods to determine torque and drag of a string. A method includes analyzing a plurality of continuous segments of a string deployed in a wellbore, and determining a deflection of the plurality of continuous segments from a node of the string and a tortuosity deflection of the wellbore. In response to a determination that deflection of the plurality of continuous segments from the node of the string is greater than the tortuosity deflection of the wellbore, the method includes applying a soft string model to determine a torque and a drag of the string. In response to a determination that deflection of the plurality of continuous segments from the node of the string is not greater than the tortuosity deflection of the wellbore, the method includes applying a stiff string model to determine a torque and a drag of the string.

Abstract: The disclosed embodiments include well operation evaluation systems and methods to analyze a broomstick chart of a well operation. The method includes receiving data indicative of a well operation involving deploying a conveyance to a predetermined location. The method also includes determining one or more conditions that impact deployment of the conveyance to the predetermined location. The method further includes determining a likelihood of occurrence of the one or more conditions. The method further includes determining one or more operations which, when performed by one or more tools used during the well operation, overcome the one or more conditions.

Abstract: Drilling parameters for a wellbore operation can be determined based on resonance speeds. For example, a system can receive real-time data for a drilling operation that is concurrently occurring with receiving the real-time data. The system can determine, for a drilling depth, a rotations-per-minute (RPM) value corresponding to a resonance speed based on a weight-on-bit (WOB) value and the real-time data. The system can generate a plot of the WOB value and the RPM value corresponding to the resonance speed. The system can determine drilling parameters for the drilling operation based on the plot. The drilling parameters can exclude, for the WOB value, the RPM value corresponding to the resonance speed.

Abstract: The disclosed embodiments include well operation evaluation systems and methods to analyze a broomstick chart of a well operation. The method includes receiving data indicative of a broomstick chart of a well operation. The method also includes diagnosing an issue during the well operation based on the broomstick chart. The method further includes predicting an impact on the well operation as a result of the issue. The method further includes determining a likelihood of occurrence of the impact. The method further includes determining a solution to overcome the issue.

Abstract: A system can be used to analyze a wellbore operation using symbolic dynamics. The system can receive baseline data and subsequent data about a downhole tool. The system can transform the baseline data and the subsequent data into symbolic representations thereof. The system can determine, using symbolic dynamics to compare the symbolic representations, a degree of difference between the symbolic representations. The system can provide the degree of difference between the symbolic representations via an output device. The degree of difference can be used to control the wellbore operation.

Abstract: Processes to receive user input parameters and system input parameters associated with a borehole undergoing active drilling operations to continually update drilling directions with wholistically applied optimizations to bring the actual borehole trajectory closer to the planned borehole trajectory. The processes can project ahead of the drilling assembly to determine the actual trajectory of the borehole and generate corrections to reduce the gap between the actual and planned trajectory paths. Various optimizations can be applied to the corrections to avoid overstressing systems or reducing the borehole productivity. Conflicts between optimizations can be resolved using a weighting or ranking system. More than one set of corrections can be determined and a user or a machine learning system can be used to select the one set of corrections to use as the results to be communicated and applied to the drilling operation plan or a borehole system, such as a geo-steering system.

Abstract: In some embodiments, a method comprises quantifying a condition of a wellbore into which a string is to be deployed, wherein quantifying the condition of the wellbore comprises, determining at least one geometrical parameter of the wellbore; and determining at least one mechanical parameter of the string that is caused by deploying the string downhole into the wellbore. The method also comprises determining a string runnability index for running the string into the wellbore based on the quantified condition of the wellbore.

Abstract: Systems, methods, and computer-readable media for an integrated and comprehensive hydraulic, environmental, and mechanical tubular design analysis workflow and simulator for complex well trajectories. An example method can include obtaining data defining a configuration of a wellbore having a complex well trajectory, one or more operations to be performed at the wellbore, and one or more loads associated with the wellbore; calculating environmental conditions associated with a set of wellbore components along the complex well trajectory based on the data defining the configuration of the wellbore, the one or more operations, and the one or more loads; calculating stress conditions associated with the set of wellbore components based on the environmental conditions and the data defining the configuration of the wellbore, the one or more operations, and the one or more loads; and presenting the environmental conditions and the stress conditions via a graphical user interface.

Abstract: A system can receive data relating to a tubular of a well system. The system can execute a first module to determine first outputs. The system can execute a second module to determine second outputs based on the first outputs. The system can execute a third module to determine third outputs based on the first outputs. The second outputs can include a crack-initiation fracture pressure, and the third outputs can include a crack-propagation fracture pressure. The system can identify a brittle-burst strength of the tubular from among the second outputs, the third outputs, and a standard burst strength of the tubular. The system can provide the brittle-burst strength of the tubular to facilitate an adjustment to the tubular to optimize a wellbore operation associated with the well system.

Abstract: A system for drilling a borehole at a wellsite, the system including a BHA with a drill bit and operable to drill the borehole as part of a borehole drilling operation using a modeled operational parameter. The system also includes a sensor located in the borehole and operable to measure an actual operational parameter in real-time. A controller including a processor performs operations that include: determining a modeled result for the borehole drilling operation using a well engineering model; receiving the measurement of the actual operational parameter from the sensor; determining an actual result for the borehole drilling operation using the well engineering model; automatically calibrating the well engineering model using the modeled result and the actual result to produce a calibrated well engineering model; and adjusting the modeled operational parameter of the drilling operation based on the calibrated well engineering model.

Abstract: Systems, methods, and computer-readable media are provided for rig monitoring and in particular, to receiving data from a plurality of sensors in real-time, mapping the data from the plurality of sensors with a micro-activity and a macro-activity, generating a message based on the mapping of the data from the plurality of sensors with the micro-activity and the macro-activity, selecting a parameter to be compared with a bit depth, tuning the parameter and the bit depth with a corresponding model based on the message, generating a parameter uncertainty array and a bit depth uncertainty array based on the tuning of the parameter and the bit depth, and generating dynamic uncertainty ellipses based on the parameter uncertainty array and the bit depth uncertainty array.

Abstract: Aspects and features of this disclosure relate to projecting physical drilling parameters to control a drilling operation. A computing system applies Bayesian optimization to a model incorporating the input data using varying values for an adverse drilling factor to produce a target function. The computing system determines a minimum value for the target function. The computing system provides a projected value for the physical drilling parameters based on the minimum value. The computing system generates an alert responsive to determining that the projected value for the physical drilling parameters exceeds a prescribed limit.

Abstract: The disclosure presents apparatuses and systems to reduce drag and friction forces on a drill string located downhole a borehole. The drill string can have two or more movement isolators to allow a movement sensitive tool to be movement isolated from other portions of the drill string that have powered movement. The other drill string portions can be powered by a surface equipment or by a downhole movement motor attached to the drill string, such as a rotational mud motor, an agitator, a jar motor, or a rotary steerable. Portions of the drill string located further downhole than the movement sensitive tool can utilize a movement motor attached to the drill string to provide movement to reduce drag and friction force where the movement isolators can reduce the movement force experienced by the movement sensitive tool.

Abstract: A method for designing a borehole tubular for use in a borehole. The method may include defining tubular sections that make up the borehole tubular, defining a downhole operation that will be conducted using the borehole tubular at a first timestamp, determining loads that will be applied to each of the tubular sections at respective specific depths along the borehole during the downhole operation at the first timestamp, determining a design limit envelope for each of the tubular sections at the first timestamp based on design parameters of the tubular section and the specific depth of the tubular section at the first timestamp, and displaying a three-dimensional (3D) plot of the design limit envelopes of the tubular sections and the loads applied to the tubular sections as a function of depth within the borehole on a display.

Abstract: A system can receive data relating to a tubular of a well system. The system can execute a first module to determine first outputs. The system can execute a second module to determine second outputs based on the first outputs. The system can execute a third module to determine third outputs based on the first outputs. The second outputs can include a crack-initiation fracture pressure, and the third outputs can include a crack-propagation fracture pressure. The system can identify a brittle-burst strength of the tubular from among the second outputs, the third outputs, and a standard burst strength of the tubular. The system can provide the brittle-burst strength of the tubular to facilitate an adjustment to the tubular to optimize a wellbore operation associated with the well system.

Abstract: A system can generate, via a software model, downhole pressure estimations and downhole debris estimations using caving parameters. Additionally, the system can generate, via the software model, settled caving volume percent estimations using the caving parameters. The system can determine a pack off volume percent using the downhole pressure estimations, the downhole debris estimations, and the settled caving volume percent estimations. The system can output, via a user interface, the pack off indicator and a subset of the caving parameters for use in adjusting a wellbore operation. The user interface can provide a plot of the pack off volume percent horizontally offset with respect to a plot of the subset of the caving parameters and a depth of the wellbore.

Abstract: A method for determining annular fluid expansion (“AFE”) within a borehole with a sealed casing string annulus. The method may include defining a configuration of the borehole. The method may further include defining a production operation and a borehole operation. The method may also include determining AFE within the borehole when performing the production operation. The method may further include determining AFE within the borehole when performing the borehole operation based on the AFE within the borehole when performing the production operation.

Abstract: A method for controlling computerized operations related to a wellbore comprises drilling the wellbore in a subsurface formation with a drill string including a drill bit. The method comprises acquiring a plurality of drilling parameters while drilling the wellbore. The method comprises determining, based on the plurality of drilling parameters, solids properties for solids forming a cutting plug up hole of the drill bit. The method comprises determining a length of the cutting plug based on the solids properties. The method comprises determining a cutting plug friction force based on the cutting plug length and a pressure differential across the cutting plug. The method comprises performing a drilling operation based on the cutting plug friction force.

Abstract: A method for controlling computerized operations related to a wellbore comprises drilling the wellbore in a subsurface formation with a drill string including a drill bit. The method comprises acquiring a plurality of drilling parameters while drilling the wellbore. The method comprises determining, based on the plurality of drilling parameters, solids properties for solids forming a cutting plug up hole of the drill bit. The method comprises determining a length of the cutting plug based on the solids properties. The method comprises determining a cutting plug friction force based on the cutting plug length and a pressure differential across the cutting plug. The method comprises performing a drilling operation based on the cutting plug friction force.

Abstract: Processes to receive user input parameters and system input parameters associated with a borehole undergoing active drilling operations to continually update drilling directions with wholistically applied optimizations to bring the actual borehole trajectory closer to the planned borehole trajectory. The processes can project ahead of the drilling assembly to determine the actual trajectory of the borehole and generate corrections to reduce the gap between the actual and planned trajectory paths. Various optimizations can be applied to the corrections to avoid overstressing systems or reducing the borehole productivity. Conflicts between optimizations can be resolved using a weighting or ranking system. More than one set of corrections can be determined and a user or a machine learning system can be used to select the one set of corrections to use as the results to be communicated and applied to the drilling operation plan or a borehole system, such as a geo-steering system.