The present disclosure provides an impact simulation device and simulation method for characteristics of a rock chip bed in a large displacement well. The device comprises a wellbore system, a drilling fluid circulation system, a rock chip transportation system, a drill pipe control system, a data acquisition system, and a data processing system. The wellbore system is configured to simulate a horizontal annulus environment for rock chip transportation during drilling. The drilling fluid circulation system is configured to provide drilling fluid to the wellbore system and collect flow data of the drilling fluid. The rock chip transportation system is configured to simulate an output of rock chips in the horizontal annulus environment during drilling and recover the rock chips. The drill pipe control system is configured to implement drilling simulation in the wellbore system. The data acquisition system is configured to collect monitoring data during the drilling simulation and to transmit the monitoring data to the data processing system. The data processing system is configured to determine ECD correction parameters based on the monitoring data.

The present invention relates to a remote control and monitoring system to improve the production efficiency of a hydrocarbon well, including a choke located between a wellhead production tree and the production line of hydrocarbons, an actuator operating the choke, the actuator being in communication with a remote control and monitoring unit, a power supply source supplying power to the control and monitoring unit, and a plurality of data acquisition means including transducers arranged upstream and downstream of the choke, where the data acquisition means sends information related to the wellhead pressure, the production line pressure, and optionally, the wellhead temperature to the control and monitoring unit, where the control and monitoring unit is configured to carry out well shut-in cycles and well opening cycles determined based on compliance with a plurality of well shut-in and opening criteria by which a measured or calculated value of a parameter is compared to a preset value for the parameter, where the measured or calculated parameters are selected from wellhead pressure, production line pressure, wellhead pressure to production line pressure ratio, shut-in or opening time of the well, flow rate and critical flow rate. A method for improving the production efficiency of a hydrocarbon well employing the same is also provided.

A method and system for determining a flow rate of at least a phase or a component of a fluid produced from an oil and gas well are presented hereinafter. The fluid is one of a multiphase and of a multicomponent fluid. The method comprises, in a training phase, collecting primary measurements of pressure, temperature, and additional flow parameter of the produced fluid. The primary measurements are carried out at the wellhead by a set of sensors installed in a flow line for the produced fluid. In the training phase, the method also comprises collecting a flow rate of at least one of the phases or components of the produced fluid simultaneously measured by a reference multiphase flow meter installed in the flow line. It also includes establishing a relationship between the pressure, temperature, and the additional flow parameter and the flow rate of the at least one of the phases or components of the produced fluid. The method also comprises, in a subsequent production phase, determining the flow rate of the at least one of the phases or components of the produced fluid based on the primary measurements of the pressure, temperature, and the at least one additional flow parameter and on the established relationship.

A system and methods for quantitative hydraulic fracturing surveillance from fiber optic sensing using machine learning is described herein. An exemplary method provides capturing distributed acoustic sensing (DAS) data, distributed temperature sensing (DTS) data, and microseismic data over monitored stages. Operation states and variables at a respective stage are predicted, based on, at least in part, the DAS data, DTS data, or microseismic data. At least one event associated with the predicted operation states and variables is localized at the respective stage.

A method includes receiving first training well logs, generating second training well logs by injecting one or more different types of systematic errors, random errors, or both into at least a portion of the first training well logs, training a machine learning model to correct well logs by configuring the machine learning model to reduce a dissimilarity between at least a portion of the first and second training well logs, receiving one or more implementation well logs, and generating one or more corrected well logs by correcting at least a portion of the one or more implementation well logs using the machine learning model that was trained.

A system can flush a drilling fluid sample with a hydrocarbon blend, which includes a determined concentration of at least one chemical species to generate a flushed drilling fluid sample. The system can extract a dissolved gas from the flushed drilling fluid sample. The system can determine a concentration over time of at least one chemical species of the dissolved gas. The system can generate an area per concentration curve based on the concentration over time of the at least one chemical species. The system can determine at least one concentration value of the at least one chemical species. The system can modify the at least one concentration value based on the area per concentration curve. The system can then correct bias caused by the gas extractor and fluid sampling system.

A straddle apparatus deploys in a borehole with tubing to treat different formation zones. The apparatus has packer elements and a flow element. The packer elements have fill ports in fluid communication with the tubing and have packer valves. These packer valves are biased to open fluid communication between the elements and the fill port so the elements can be inflated to seal off a borehole section. The flow unit has a flow port in fluid communication with the tubing and has a flow valve biased to close fluid communication between the flow port and the borehole. Once the elements inflate, a control unit electronically activate the packer valves to close fluid communication between the elements and the fill ports. Then, the control units electronically activates the flow valve to open fluid communication between the flow port and the borehole so treatment can be applied to the formation zone.

A system for operating a downhole tool includes a tag carrier; a RFID tag coupled with the tag carrier; and a control sub having a bore extending therethrough, the control sub comprising: an antenna located adjacent to the bore; and a stop for catching the tag carrier, wherein: the radio frequency identification tag is coupled with the tag carrier in relation to the stop and the antenna such that the radio frequency identification tag is aligned with the antenna when the tag carrier is caught in the stop, and the stop is operable to allow passage of the tag carrier through the stop after the tag carrier is caught by the stop.

An apparatus for operating a device in a wellbore is disclosed that in one non-limiting embodiment includes a drop device configured to be dropped into the wellbore that transmits a selected signal while the drop device is traveling in the wellbore, a control circuit in the wellbore that detects the transmitted selected signal and provides a control signal in response to the detected signal to operate the device in the wellbore.

A wellbore servicing system comprising a controller node disposed within a wellbore, and a tool node configured for movement through the wellbore, wherein the tool node communicates with the controller node via a near field communication (NFC) signal, wherein prior to communication with the controller node, the tool node will not perform at least one function and, after communication with the controller node, the tool node will selectively perform the at least one function.