Halliburton Energy Services, Inc.

Qiuying Gu

Jason Daniel Dykstra

Zhijie Sun

Yuzhen Xue

Robert Phillip Darbe

Umut Zalluhoglu

Julien Christian Valery Marek

Techniques for estimating a current inclination and azimuth of a drill bit of a wellbore drilling system are described. The estimates for the current inclination and azimuth are generated using measurements obtained for one or more parameters associated with the drilling process performed by the drill bit and taken over a range of the wellbore falling within a sliding window having a predefined distance D extending along the wellbore.

Sensor fusion and model calibration for bit attitude prediction

A method and system for dampening a stick-slip vibration. The method may comprise determining at least one frequency of a stick-slip vibration; determining mechanical properties of the drilling system; producing a torque signal from a controller having at least a second order; controlling a rotational speed of a top drive from the torque signal produced by the controller; and damping stick-slip vibration of the drilling system. The system may further comprise a drill string and a bottom hole assembly may be connected to the drill string. A drill bit may be connected to the bottom hole assembly and an information handling system may be connected to the drilling system.

Method and system for stick-slip mitigation

Methods and systems are presented in this disclosure for evaluating whether to apply fluid flowback during a fracture closure stage of a hydraulic fracturing operation of a reservoir formation. Information collected prior to the fracture closure stage of the hydraulic fracturing operation can be first gathered. Based on the collected information, it can be determined whether to perform fluid flowback during the fracture closure stage following a treatment stage of the fracturing operation. Based on the determination, a rate of the fluid flowback can be adjusted and optimized in real-time during the fracture closure stage.

Structure for fluid flowback control decision making and optimization

A drilling apparatus including plurality of subsystems, each subsystem includes a subsystem controller, one or more sensors, and one or more actuators. Each subsystem controller is configured to determine a local subsystem state from measurements received from the one or more sensors and further configured to receive global state estimates and updated control strategies. Each subsystem controller is configured to send command signals to one or more actuators based at least in part on the local subsystem state, global state estimates, and updated control strategy. A method and system for coordinating the control of a plurality of drilling subsystems during drilling operations is provided. A method of drilling subsystem controller decision-making based on a co-player inference playing strategy is further provided.

Game theoretic control architecture for drilling system automation

In some aspects, the present disclosure includes systems and methods for determining and delivering diverting material to dominant fractures in a stage of a subterranean formation. The method includes creating or extending a plurality of fractures in a stage of a subterranean formation; pumping fracturing fluid to the plurality of fractures; identifying dominant fractures among the plurality of fractures; determining a desired amount of diverters to deliver to the dominant fractures; and pumping the determined amount of diverters to the dominant fractures so as to redistribute the flow of fracturing fluid between the plurality of fractures.

Real-time control of diverters

Techniques for managing a hydraulic fracturing operation include receiving a selection of a proxy model that represents a first principles model of a hydraulic fracturing operation, the proxy model including at least one property of a plurality of properties of the first principles model associated with the hydraulic fracturing operation; simulating the selected proxy model to generate a modeled output based on the property; and determining a value of a control setpoint for hydraulic fracturing operation equipment based on the modeled output.

Managing a wellsite operation with a proxy model

A mud sag monitoring system may be configured for real-time evaluation of sagging potential of a circulating mud. The monitoring system may include both physics-based sagging prediction models and data-driven sagging detection classifiers that allow for predicting the sagging potential. The sagging potential may also be quantified with a sagging severity index and associated with a specific location within the mud circulation system. The sagging severity and location predictions may provide a framework for mitigation of mud sagging using automatic control techniques.

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Humble, TX, United States of America

Qiuying Gu