Methods and systems are provided for optimizing a drill path from the surface to a target area below the surface. A method for operating an automated drilling program may comprise drilling to a target location along a drill path, updating a drilling path model based at least on data obtained during the state of drilling to the target location, creating a modified drill path to the target location based on at least the drilling path model in real-time as the step of drilling to the target location along the drill path is being performed, and drilling to the target location along the modified drill path.

An embodiment includes a method of monitoring a fluid pump that includes receiving time domain measurement data indicating vibrations occurring in a fluid pump, and filtering the measurement data to remove measurement data components having frequencies below a threshold frequency, the removed measurement data components associated with cyclical motions of the fluid pump. The method also includes dividing the filtered measurement data into a plurality of subsets, each subset corresponding to a pump cycle, and estimating a peak count for each subset, the peak count being a number of peaks having an amplitude that exceeds a selected amplitude threshold, the amplitude threshold associated with impacts between internal components of the pump. The method further includes comparing the peak count with an expected peak count, and determining whether the pump is in a condition selected from at least one of a wear condition and a failure condition based on the comparison.

A system and method can include a module including at least one actuation assembly configured to transition between an inactive configuration and an active configuration. The system include at least one sensor configured to obtain data that is indicative of an operating parameter, and at least one processor configured to be electronically coupled to the guidance module and the at least one sensor. The at least one processor is configured to, in response to 1) input received from the at least one sensor that is indicative of the measured operating parameter, and 2) received input that is indicative of an actual drilling direction that is deviated from the predetermined drilling direction, adjust an extent that the actuation assembly is in the active configuration.

Real-time data from one or more sensors can be received about one or more active wellbore operations. A blended data set can be generated that includes the real-time data combined with historical data about previously completed wellbore drilling operations, and associated with performance attributes. Additionally, identification of a criteria of focus, types of parameters for optimization, and operation groupings for the blended data set can be received. Further, the criteria of focus, types of parameters for optimization and operation groupings for the data can be applied to the blended data set to determine an adjustment for an active wellbore drilling operation of interest. The adjustment for the active wellbore drilling operation of interest can be outputted.

An embodiment includes a method of monitoring a fluid pump that includes receiving time domain measurement data indicating vibrations occurring in a fluid pump, and filtering the measurement data to remove measurement data components having frequencies below a threshold frequency, the removed measurement data components associated with cyclical motions of the fluid pump. The method also includes dividing the filtered measurement data into a plurality of subsets, each subset corresponding to a pump cycle, and estimating a peak count for each subset, the peak count being a number of peaks having an amplitude that exceeds a selected amplitude threshold, the amplitude threshold associated with impacts between internal components of the pump. The method further includes comparing the peak count with an expected peak count, and determining whether the pump is in a condition selected from at least one of a wear condition and a failure condition based on the comparison.

System and methods disclosed herein store sizing parameters for sized members used with downhole components and stores dimensions of the downhole components to be handled at the wellsite. The sizing parameter for a respective sized member defines how the respective sized member is sized for use with the downhole components. Machine-readable indicia is encoded with the sizing parameters and physically associated with the sized members. When handling a current downhole component, the sizing parameter associated with current sized member is determined by reading the machine-readable indicia The sizing parameter associated with the read indicia is then compared to the stored the dimensions of the downhole components to be handled. An automated response is then produced based on the comparison. The sized members can be gripping elements used in a spider or an elevator, jaws used on a power tong, or features disposed on a downhole tool.