Systems and methods can automatically and dynamically determine an optimum frequency for data being input into a drilling optimization tool in order to provide predictive modeling for well drilling operations. The methods and systems selectively input sets of data having different frequencies into the drilling optimization tool to build different predictive models at different frequencies. An optimization algorithm such as Bayesian optimization is then applied to the models to identify in real time an optimum frequency for the data sets being input into the drilling optimization tool based on current operational and environmental parameters.

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.

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.

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.

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.

Implementations described and claimed herein provide systems and methods for monitoring real-time drilling parameters. In one implementation, one or more measured parameters including at least a mud weight (MW) of a drilling fluid within a wellbore are received. At least one of a coefficient of performance (COP) cuttings transport ratio, a COP bit equivalent circulation density (ECD), a COP Wilcox ECD, a reverse circulation ECD, or a COP kill mud density (KMD) are determined from the one or more measured parameters. The at least one of the coefficient of performance (COP) cuttings transport ratio, the COP bit equivalent circulation density (ECD), the COP Wilcox ECD, the reverse circulation ECD, or the COP KMD are displayed. An alert is generated when the at least one of the COP cuttings transport ratio, the COP bit ECD, the COP Wilcox ECD, the reverse circulation ECD, or the COP KMD exceeds a predetermined threshold.

Implementations described and claimed herein provide systems and methods for monitoring real-time drilling parameters. In one implementation, one or more measured parameters including at least a mud weight (MW) of a drilling fluid within a wellbore are received. At least one of a coefficient of performance (COP) cuttings transport ratio, a COP bit equivalent circulation density (ECD), a COP Wilcox ECD, a reverse circulation ECD, or a COP kill mud density (KMD) are determined from the one or more measured parameters. The at least one of the coefficient of performance (COP) cuttings transport ratio, the COP bit equivalent circulation density (ECD), the COP Wilcox ECD, the reverse circulation ECD, or the COP KMD are displayed. An alert is generated when the at least one of the COP cuttings transport ratio, the COP bit ECD, the COP Wilcox ECD, the reverse circulation ECD, or the COP KMD exceeds a predetermined threshold.

A method of drilling includes obtaining historical data for historical wells in a field, determining a set of drilling parameters, and determining a set of hole section sizes defining a wellbore geometry. For each combination of a parameter in the set of parameters and a hole section size in the set of hole section sizes, historical wells having average values of the parameter exceeding a threshold for the hole section size from the historical surface drilling data are selected. An expected output for each of a model to be trained by each of the selected historical wells is derived based on a rate of penetration while drilling. A final model is trained with the selected historical wells and expected outputs. An operating envelope is determined for each of the parameters in the set of parameters from the trained model. The operating envelopes may be used to guide drilling of a well in the field.

A method of drilling includes obtaining historical data for historical wells in a field, determining a set of drilling parameters, and determining a set of hole section sizes defining a wellbore geometry. For each combination of a parameter in the set of parameters and a hole section size in the set of hole section sizes, historical wells having average values of the parameter exceeding a threshold for the hole section size from the historical surface drilling data are selected. An expected output for each of a model to be trained by each of the selected historical wells is derived based on a rate of penetration while drilling. A final model is trained with the selected historical wells and expected outputs. An operating envelope is determined for each of the parameters in the set of parameters from the trained model. The operating envelopes may be used to guide drilling of a well in the field.

A method for optimizing a drilling roadmap may include identifying an optimal bottom hole assembly (BHA) setup and drilling parameters for a well located in a field. The BHA setup may be based on historical simulation data of the field and drilling roadmap information. The drilling roadmap information may include initial drilling instructions for implementing the drilling roadmap. The method may include implementing and tracking the drilling roadmap at the well. The drilling roadmap may be based on a location of the well on the field and a type of other applications being performed on the field. The method may include obtaining sensor collected data to determine an accuracy of implementation of the drilling roadmap. The accuracy may be determined based on a comparison between tracked drilling parameters and simulated drilling parameters.