Abstract: A system for designing a casing string for an oil well, a gas well, an oil and gas well, and/or a geothermal well. The system comprises a processor, a non-transitory memory storing a casing string design, wherein the casing string design comprises at least one section of UOE-type pipe, a downhole environment simulation application stored in the non-transitory memory that, when executed by the processor determines downhole conditions based on the casing string design, wherein the downhole conditions comprise a downhole temperature, and a casing collapse strength modeling application stored in the non-transitory memory that, when executed by the processor, analyzes collapse strength of the casing string based on the downhole temperature and based on a UOE-type pipe collapse strength model and presents a collapse strength report on the casing string design based on analyzing the collapse strength of the casing string.

Abstract: A method for assessing an integrity of metal tubular structures may comprise receiving one or more inputs, applying an algorithm to automatically select an appropriate model for a given corrosion scenario, applying a combined model including semi-empirical and multiphase flow corrosion characteristics to the one or more inputs, determining one or more corrosion parameters of either an internal pipe wall, an external pipe surface, or both, applying a corrosion correlation value to the one or more corrosion parameters to produce one or more correlated corrosion parameters, and storing the one or more correlated corrosion parameters on a computer readable medium. A system may comprise an information handling system which may comprise at least one memory operable to store computer-executable instructions, at least one communications interface to access the at least one memory, and at least one processor.

Abstract: The disclosure presents processes and methods for determining an adjusted drag friction factor, where the adjusting utilizes a hole cleaning function. In some aspects, the drag friction factor utilizes viscous drag. In some aspects, the drag friction factor utilizes viscous torque. In some aspects, the drag friction factor can be utilized to determine one or more decomposed friction factors. The decomposed friction factors or the adjusted drag friction factor can be utilized in a friction processor to improve the efficiency of borehole operations. The hole cleaning function can utilize various parameters, for example, a cuttings density, a cuttings load, a cuttings shape, a cuttings size, a deviation, a drill pipe rotation rate, a drill pipe size, a flow regime, a hole size, a mud density, a mud rheology, a mud velocity, a pipe eccentricity, and other parameters. A system is disclosed that is capable of implementing the processes and methods.

Abstract: A method for calculating wellbore casing wear is provided that includes determining a wellbore boundary for an open hole wellbore segment, calculating a casing shape within the open hole wellbore segment based on one or more casing attributes, determining whether or not the casing shape exceeds the wellbore boundary, calculating casing wear based on the boundary of the open hole wellbore segment if the casing shape is determined to exceed the wellbore boundary, otherwise calculating the casing wear parameter based on the casing shape if the casing shape is determined not to exceed the wellbore boundary, and storing the casing wear parameter on a computer readable medium.

Abstract: The disclosure presents processes and methods for utilizing one or more micro-services to generate a calibration of a factor of a borehole operation or to generate an optimization adjustment to the borehole operation. The micro-services selected for execution can be selected by an optimization workflow, where each type of borehole operation can have its own set of micro-services. The micro-services can be part of one or more computing systems, such as a downhole system, a surface system, a well site controller, a cloud service, a data center service, an edge computing system, other computing systems, or various combinations thereof. Also disclosed is a system for implementing micro-services on one or more computing systems to enable a light weight and fast response, e.g., real-time or near real-time response, to borehole operations.

Abstract: The disclosure presents processes and methods for decomposing friction factors and generating a calibrated friction factor and adjusted input parameters. The calibrated friction factor and adjusted input parameters can be utilized by a borehole system as an input to adjust borehole operations to improve the operational efficiency. The friction factors can be decomposed by type, such as geometrical, geomechanical, mechanical, and fluid. The disclosure also presents processes and methods for identifying an outlier portion of a friction factor, as identified by a deviation threshold that can be used to identify adjustments to borehole operations in that portion of the borehole. A system is disclosed that is capable of implementing the processes and methods in a borehole operation system, such as a downhole system, a surface system, or a distant system, for example, a data center, cloud environment, lab, corporate office, or other location.

Abstract: Methods and systems for determining wellpath tortuosity are disclosed. In accordance with an embodiment, a tortuosity of a borehole segment is determined and a tortuosity of a casing associated with the borehole segment is determined based, at least in part, on the tortuosity of the borehole segment and a path conformity characteristic of the casing. A tortuosity variation factor is generated based on a value of the tortuosity of the casing relative to a value of the tortuosity of the borehole segment.

Abstract: A well operation simulator predicts temperature and pressure profiles of a multi-tubing completion well for well design. The simulator is comprised of modules, which when executed, determine a first set of design limits based on stress conditions arising from the temperature and pressure profiles from a multi-tubing drilling module and a multi -tubing production module for drilling and production operations. A multi-tubing multi-string module predicts the annular fluid expansion (AFE) and annular pressure buildup (APB) of the multi-tubing well from the previously calculated temperature profile, pressure profile, and stress conditions and determines a second set of design limits with the AFE/APB effects in addition to the temperature profile and pressure profile predicted from multi-tubing drilling module and multi-tubing production module.

Abstract: A method includes comparing a natural frequency of a tubular with a frequency of each of at least two pulse generating devices positioned adjacent each other on the tubular, the tubular and the at least two pulse generating devices comprising an energy system; adjusting the frequency of at least one of the at least two pulse generating devices when the frequency is equal to the natural frequency of the tubular and obtaining an adjusted frequency different from the natural frequency; calculating an energy distribution in the energy system based on the natural frequency and the adjusted frequency of the at least one of the at least two pulse generating devices; and determining a new location on the tubular for positioning one or more of the at least two pulse generating devices such that energy introduced into the energy system is less than energy dissipated from the energy system.

Abstract: Certain aspects and features relate to a system that selects an output value for controlling a drilling tool using dynamic force analysis coupled to fluid effects as part of a model that estimates projected torque and drag. A drilling model according to aspects and features of the present disclosure takes into account pipe axial elasticity as it relates to dynamic, time-based, force analysis and couples this relationship with drilling fluid effects over time. In some examples, a system calculates at least one dynamic sideforce and at least one dynamic, hydraulic force for each interval of time. An equilibrium solution for an output value using the dynamic sideforce and dynamic, hydraulic force for each time interval can be applied to the drilling tool for each time interval during drilling operations.

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: 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 method may comprise drilling a wellbore penetrating a subterranean formation; collecting drill time data for the drilling; converting the drill time data into segmented drill time data; decomposing the segmented drill time data into intrinsic mode functions (IMFs) using an empirical mode decomposition; reconstructing the segmented drill time data by combining the IMFs with different weights, thereby producing modified segmented drill time data; and calculating an invisible lost time for the drilling based on the segmented drill time data and the modified segmented drill time data.

Abstract: A system is described for calculating and outputting micro invisible lost time (MILT). The system may include a processor and a non-transitory computer-readable medium comprising instructions that are executable by the processor to cause the processor to perform various operations. Time-stamp data that includes values of drilling parameters may be received about a drilling operation, and the values of drilling parameters may be classified into a rig state that includes rig activities. For each rig activity, an actual completion time may be determined and compared to an expected completion time for determining a deviation. At least one deviated activity, in which the deviation is greater than a threshold, may be determined. Deviations may be combined into MILT that can be output for controlling the drilling operation.

Abstract: This disclosure provides an agitator system that includes an agitator assembly of concentric power-sections, (one power-section inside another power-section both of which comprise stators and rotors). The agitator system includes a controller configured to control a valve assembly of the agitator assembly to selectively open and close the valve assembly to allow fluid to selectively flow between the power-sections of the agitator assembly that generates pressure fluctuations or pressure pluses in the fluid pressure, which increases the speed of the rotor or rotors, and thus, the vibrational frequency of the agitator. The controller can be used to increase the vibrational frequency of the agitator assembly when necessary to prevent the drill string from becoming lodged in a wellbore.

Abstract: Vibrations occurring during downhole drilling operations can be predicted and reduced according to some examples. One particular example includes a system that can receive drilling parameter values associated with a drilling operation involving drilling a wellbore through a subterranean formation using a drill string. The system can receive a depth value associated with the drilling parameter values. The system can provide the drilling parameter values as input to a drill string model to receive a critical speed prediction as output from the drill string model. The system can then generate a speed-depth mapping based on the critical speed prediction and the depth value. The speed-depth mapping can be used to avoid the critical speed at the depth in the wellbore, which may prevent a failure of the drill string resulting from associated vibrations.

Abstract: A method for calculating wellbore casing wear is provided that includes determining a wellbore boundary for an open hole wellbore segment, calculating a casing shape within the open hole wellbore segment based on one or more casing attributes, determining whether or not the casing shape exceeds the wellbore boundary, calculating casing wear based on the boundary of the open hole wellbore segment if the casing shape is determined to exceed the wellbore boundary, otherwise calculating the casing wear parameter based on the casing shape if the casing shape is determined not to exceed the wellbore boundary, and storing the casing wear parameter on a computer readable medium.

Abstract: Multiple projected rate of penetration (ROP) values can be determined for purposes of adjusting well tools and well characteristics. For example, surface data can be determined based on a surface sensor signal. Downhole data can be determined based on a downhole sensor signal. A first value indicating a first projected ROP of a drill bit can be determined by providing the surface data as input to a first machine-learning model. A second value indicating a second projected ROP of the drill bit can be determined by providing the downhole data as input to a second machine-learning model. A third value indicating a third projected ROP of the drill bit can be determined by providing the first value and the second value input to a third machine-learning model. An operating characteristic of a well tool can be adjusted based on the third value.

Abstract: A drilling device may use a concurrent path planning process to create a path from a starting location to a destination location within a subterranean environment. The drilling device can receive sensor data. A probability distribution can be generated from the sensor data indicating one or more likely materials compositions that make up each portion of the subterranean environment. The probability distribution can be sampled, and for each sample, a drill path trajectory and drill parameters for the trajectory can be generated. A trained neural network may evaluate each trajectory and drill parameters to identify the most ideal trajectory based on the sensor data. The drilling device may then initiate drilling operations for a predetermined distance along the ideal trajectory.

Abstract: A system is described for controlling wellbore drilling operations autonomously using satisficing parameters. The system can determine a wellbore-drilling envelope defining a zone for satisficed values of drilling parameters for a drilling operation. The system can receive real-time data for the drilling parameters and can compare the real-time data to the wellbore-drilling envelope. The system can output a command for automatically controlling the drilling operation in response to comparing the real-time data to the wellbore-drilling envelope.