Abstract: A method comprises retrieving geoscience data of a subsurface formation into which a wellbore is being drilled and retrieving drilling operation data for drilling the wellbore. The method includes determining at least one of an optimized target trajectory of a path of the wellbore to be drilled or a series of control operations for the drilling in order to follow the path of the wellbore to be drilled, independent of using waypoints as input and based the geoscience data and the drilling operation data. The method includes modifying geosteering of the drilling of the wellbore based on the at least one of the optimized target trajectory or the series of the control operations.

Abstract: A computer-implemented method for drilling a curve section of a wellbore in a subsurface formation. The method comprises obtaining a curvature setpoint. The method comprises obtaining drilling process feedback from a drilling assembly drilling the curve section of the wellbore. The method comprises updating a scheduling parameter vector based on the drilling process feedback. The method comprises updating a controller, wherein the controller is configured with the scheduling parameter vector. The method comprises determining an error based on the curvature setpoint and the drilling process feedback. The method comprises inputting the error into the controller. The method comprises determining, via the controller, steering decisions based on the error and the scheduling parameter vector.

Abstract: A method and system for measuring health in a rotary steerable system (RSS). The method may include forming a bottom-hole assembly (BHA) model, taking a bending moment on bit (BOB) measurement from a sensor disposed in a BHA, and comparing the BOB measurement to the BHA model to determine if a steering actuator is malfunctioning, wherein the steering actuator is disposed on the BHA. The system may include at least one sensor disposed on the BHA, wherein the at least one sensor takes at least one bending moment on bit (BOB) measurement. Further, the system may include a plurality of steering actuators disposed on the BHA and an information handling system in communication with the BHA.

Abstract: Systems and methods for characterizing a subterranean formation that include a drill bit for drilling a deviated wellbore through the formation and that repeatedly changes direction. Also included is a directional drilling system and measurement equipment to detect a property of the formation. A trajectory control system is operable to: receive a well log; determine a property of the wellbore; segment the well log based on the property; and correlate one of the segments with the well log previous to the segment to determine a matching score for the segment. If the matching score is equal to or greater than a minimum threshold, the segment was taken in the formation and at the same stratigraphical true vertical depth (“STVD”). If the matching score is less than the minimum threshold, the segment was not taken in the formation and not at the same STVD and the STVD is estimated.

Abstract: Systems, methods, and apparatus, including computer programs encoded on computer-readable media, for detecting downhole measured depth of a borehole are disclosed. A downhole imaging tool of a drilling system may obtain azimuthal borehole images from at least a first sensor and a second sensor of the downhole imaging tool. Image cross-correlation is performed on the azimuthal borehole images. A time delay is determined based on the image cross-correlation on the azimuthal borehole images. A velocity of the downhole imaging tool is determined based on the time delay. A downhole measured depth of the downhole imaging tool within the borehole is determined based on the velocity. The downhole measured depth may be determined dynamically downhole by the downhole imaging tool without communications with surface equipment of the drilling system.

Abstract: Systems and methods for characterizing a subterranean formation that include a drill bit for drilling a deviated wellbore through the formation and that repeatedly changes direction. Also included is a directional drilling system and measurement equipment to detect a property of the formation. A trajectory control system is operable to: receive a well log; determine a property of the wellbore; segment the well log based on the property; and correlate one of the segments with the well log previous to the segment to determine a matching score for the segment. If the matching score is equal to or greater than a minimum threshold, the segment was taken in the formation and at the same stratigraphical true vertical depth (“STVD”). If the matching score is less than the minimum threshold, the segment was not taken in the formation and not at the same STVD and the STVD is estimated.

Abstract: A geosteering subsystem has been designed to detect patterns in measurements that correlate to geological events and use statical analysis to interpret the geological events corresponding to control points and update a geological model based on the statistical analysis-based interpretations. The subsystem evaluates obtained measurements against predetermined patterns that correlate to geological events. If a pattern is detected, the subsystem labels the corresponding wellbore position and/or measurements as a control point and passes on the measurements for interpretation. The subsystem generates interpretations of the control point based on the measurements and historic control points. For each interpretation, the subsystem generates a pseudo log based on offset logs. The subsystem then generates a posterior probability for each interpretation based on evaluating the corresponding pseudo log with respect to the measurements and formation knowledge.

Abstract: A method may include dividing a wellplan into one or more section using a section detection algorithm, receiving a depth measurement of a drill bit or a bottom hole assembly located in a wellbore, utilizing the section detection algorithm and the depth measurement to identify a section of the wellplan from the one or more sections of the wellplan, and identifying a target based at least in part on the identified section. The method may further include determining one or more steering commands based at least in part on the target and a control algorithm and steering the bottom hole assembly to the target using the one or more steering commands.

Abstract: A system for regulating a pump down operation may include a controller, a motor drive, a parameter estimation unit and a controller design unit. In examples, the controller may be configured to identify a difference between a downhole tension set-point to an actual downhole tension. The motor drive may be configured to adjust a line speed set point of the motor drive based at least in part on the difference from the controller to create an actual line speed from the motor drive to follow the downhole tension set-point. The parameter estimation unit may be configured to produce a fluid drag coefficient, a friction coefficient, and a line speed delay constant. The controller design unit may be configured to send one or more control gains to the controller based at least in part on the fluid drag coefficient, the friction coefficient, and the line speed delay constant.

Abstract: A method comprising: disposing a bottom hole assembly (BHA) comprising a Rotary Steerable System (RSS) into a borehole, obtaining bending of the drill bit (BOB) data with a measurement assembly disposed on the BHA, classifying the BOB data into a neutral RSS configuration or a geostationary RSS configuration, determining t1 based at least on a neutral RSS configuration, wherein t1 is the total time during a neutral RSS configuration, determining t2 based at least on a neutral RSS configuration, wherein t2 is the total time during a geostationary RSS configuration, and determining a real time Duty Cycle based at least on t1 and t2. Additionally, a bottom hole assembly (BHA) comprising a Rotary Steerable System (RSS) disposed into a borehole, and a steering control system a configured to perform the method described above.

Abstract: A system and method for accessing drilling records. A semantic web for drilling records is built, wherein building includes converting drilling records retrieved from a database into a Resource Description Framework (RDF) format and storing the RDF formatted drilling records in the semantic web. Transfer learning is applied to drilling domain knowledge to obtain a large language model (LLM) with drilling domain knowledge. A schema is applied to unstructured records to extract information from unstructured records and the extracted information is then stored in RDF format to the semantic web. The LLM is configured to query the semantic web and to manipulate RDF formatted data within the semantic web.

Abstract: A method comprises generating, via a pulse generator, a first pressure pulse in a fluid in a pipe and detecting, via a transducer, a first reflected pressure pulse based on the first pressure pulse, wherein the first pressure pulse is reflected by a pipe feature to generate the first reflected pressure pulse. The method comprises generating, with the pulse generator, a second pressure pulse at a later time relative to generating the first pressure pulse, wherein timing of generating of the second pressure pulse is such that the second pressure pulse is superposed with the first reflected pressure pulse such that an amplitude of the second pressure pulse is greater than an amplitude of the first pressure pulse. The method comprises detecting, via the transducer, a second reflected pressure pulse based on the second pressure pulse, and detecting a pipe feature based on the second reflected pressure pulse.

Abstract: A method comprising: disposing an azimuthal borehole measurement tool into a borehole, obtaining an azimuthal borehole image with the azimuthal borehole measurement tool, running a pre-processing action on the azimuthal borehole image to obtain a smart gradient image, running a sinusoidal pattern search action on the smart gradient image to form a raw dip of the azimuthal borehole image, and running a dip post-processing action to form a final dip. Additionally, a system may include comprise: an azimuthal borehole measurement tool disposed in a borehole configured to obtain an azimuthal borehole image. The system may also comprise an information handling system configured to perform the method described above.

Abstract: A method comprises measuring, at a surface of a wellbore during drilling of the wellbore, at least one drilling operational parameter and determining at least one at-bit model parameter, at a drill bit used for drilling the wellbore, based on the at least one drilling operational parameter measured at the surface of the wellbore. The method comprises determining a drilling efficiency based on the at least one at-bit model parameter.

Abstract: A method comprises generating, via a pulse generator, a first pressure pulse in a fluid in a pipe and detecting, via a transducer, a first reflected pressure pulse based on the first pressure pulse, wherein the first pressure pulse is reflected by a pipe feature to generate the first reflected pressure pulse. The method comprises generating, with the pulse generator, a second pressure pulse at a later time relative to generating the first pressure pulse, wherein timing of generating of the second pressure pulse is such that the second pressure pulse is superposed with the first reflected pressure pulse such that an amplitude of the second pressure pulse is greater than an amplitude of the first pressure pulse. The method comprises detecting, via the transducer, a second reflected pressure pulse based on the second pressure pulse, and detecting a pipe feature based on the second reflected pressure pulse.

Abstract: The disclosed embodiments include systems and methods to perform automated drilling for both surface and downhole control. The method includes receiving a curvature reference set point, and calculating a curvature error with respect to the curvature reference set point. The method also includes providing the curvature error to a linear matrix inequalities based robust linear quadratic regulator controller. The method further includes determining one or more steering commands based on an output of the linear matrix inequalities based robust linear quadratic regulator controller. The method further includes providing the one or more steering commands to be implemented by a drilling tool during a drilling operation.

Abstract: Aspects of the subject technology relate to systems and methods for improving mud motor trajectory controls. Systems and methods are provided for receiving control data from a mud motor trajectory controller, predefining a plurality of control modes based on the control data from the mud motor trajectory controller, achieving desired slide rotate ratios and toolface angles by solving an established objective function that mathematically represents operational preferences and system constraints for a selected control mode of the plurality of control modes, generating a modulation procedure that converts the slide-rotate ratios to a binary slide and rotate control sequence, and applying the modulation procedure to generate the binary slide and rotate control sequence.

Abstract: A computer-implemented method for drilling a wellbore in a subsurface formation. The method comprises obtaining measurement data including a first measurement from a first sensor and a second measurement from a second sensor of a drilling assembly in the wellbore. The method comprises generating, based on the first measurement, a first control point indicating a geological feature and having a first confidence interval. The method comprises generating, based on the second measurement, a second control point indicating the geological feature and having a second confidence interval. The method comprises generating a curve indicating a formation bed boundary of the subsurface formation based on the first and second control points and the first and second confidence intervals. The method comprises performing a drilling operation in the wellbore based on the formation bed boundary.

Abstract: Methods and compositions for estimating one or more downhole qualities of a drilling apparatus by obtaining axial acceleration data. The axial acceleration data may be acquired by measuring an axial acceleration of a bottom hole assembly. The axial acceleration may then be used to estimate one or more of a downward weight on a drill bit of the drilling apparatus or a rate of penetration of the drill bit.

Abstract: A curvature cruise controller has been designed to maintain a desired curvature when drilling a curve section of a wellbore. The curvature cruise controller utilizes a model-based controller (such as an LQR controller) to generate steering inputs based on the desired curvature and attitude setpoints and real time measurements. The model-based controller is configured with a wellbore propagation model that characterizes the tool's response dynamics. The curvature cruise controller utilizes real time drilling operation parameters measurements to tune the model-based controller.