A method includes positioning a completion assembly in a wellbore penetrating a subterranean formation and conveying a frac plug through the completion assembly. The completion assembly may provide a fracturing assembly. The method further includes detecting a wireless signal provided by the frac plug with a sensor included in the fracturing assembly, actuating a sliding sleeve of the fracturing assembly based on detection of the wireless signal and thereby moving the sliding sleeve to expose one or more flow ports, setting the frac plug in the wellbore downhole from the fracturing assembly, conveying a wellbore projectile through the completion assembly, receiving the wellbore projectile with the frac plug, and thereby sealing the wellbore at the frac plug, and injecting a fluid under pressure into the subterranean formation via the one or more flow ports.

Systems and methods for monitoring a hydrocarbon reservoir for escaped CO.sub.2 are disclosed. The methods include deploying a plurality of CO.sub.2 i-Bot sensors downhole into an observation well located above a CO.sub.2 injection zone, establishing communication among the plurality of CO.sub.2 i-Bot sensors, between the plurality of CO.sub.2 i-Bot sensors and a base station, and between the base station and a central processing location. The methods also include collecting a plurality of environmental data and sensor data from the plurality of CO.sub.2 i-Bot sensors, and training a machine learning algorithm to predict the plurality of environmental data and sensor data of the plurality of CO.sub.2 i-Bot sensors. Furthermore, the methods include determining an optimized number of CO.sub.2 i-Bot sensors that minimizes a quantity of power consumption and maximizes an area of coverage of the hydrocarbon reservoir by the plurality of CO.sub.2 i-Bot sensors using the trained machine learning algorithm.

This disclosure discusses methods and apparatus for generating vertical seismic profiles of a subsurface formation though deploying an untethered downhole tool into a wellbore, the untethered tool including at least one seismic sensor, a ballast, and a first electromagnet in the untethered downhole tool to attach the untethered downhole tool to a casing of the wellbore at a predetermined depth. The method further includes transmitting a seismic signal into the subsurface formation from a source located above the subsurface formation, receiving the seismic signal with the at least one seismic sensor, deactivating the first electromagnet to release the untethered downhole tool from the casing of the wellbore, releasing the ballast from the untethered downhole tool such that buoyancy effects move the tool uphole, and retrieving the untethered downhole tool from the wellbore.

A method for evaluatingproductivity of a vertically heterogeneous gas reservoir considering interlayer crossflow is disclosed in the invention, and includes: (1) dividing a heterogeneous gas reservoir into multiple thin layersvertically; (2) obtaining the productivity of each thin layer according to data obtained through wireline formation test; (3) superimposing the productivity of all thin layers based on the water-electricitysimilarityprinciple to obtain the superimposed productivity of the heterogeneousgas reservoir; and (4) using an interlayer crossflow correction coefficient considering influence caused by the interlayer crossflow to obtain the corrected productivity of the heterogeneousgas reservoir. Specific to the vertically heterogeneous characteristics of the gas reservoir, a gas reservoir section is divided into several different flow units, such that a reservoir with strong heterogeneity is converted into relatively homogeneous reservoir sections, and the productivity thereof is determined using the data obtained through wireline formation test, considering the influence of the interlayer crossflow in a vertically heterogeneous reservoir on productivity prediction, which has more accurate prediction results.

An activation device is disclosed that can activate multiple downhole tools in a wellbore. The activation device is cost effective and easy to produce. A method for activating multiple downhole tools in a wellbore is described where at least one downhole tool is activated by magnetic field, while at least one additional downhole tool is activated by mating of the activation device with the downhole tool.

High temperature miniature mobile device includes a power generator including a first material of one polarity and a second material that is fixed in position and is of opposite polarity of the first material, wherein the first material is propelled towards or slid against the second material based on motion of the miniature mobile device so that the two materials have a maximized point of contact to generate maximum power, an electrode that is connected to the first material or second material, a bridge rectifier connected to the electrode to transform the power generated into direct current from alternating current, a storage unit for storing the power generated by the power generator, a sensor that gathers information concerning a downhole environment, and a microcontroller and transceiver unit to manage the power generated by the power generator and transmit information gathered by the sensor.

A method for constructing docking stations for downhole robots is disclosed. The method includes determining locations and respective dimensions along a sidewall of a wellbore for drilling tunnels, constructing, based on the locations and respective dimensions, the tunnels extending from the sidewall of the wellbore, installing a downhole robot docking station in a first where the downhole robot docking station is disposed external to the wellbore, installing a power source in a second tunnel where the power source is disposed external to the wellbore, and connecting the downhole robot docking station and the power source via an electrical connection disposed along at least the sidewall of the wellbore.

A device for wellbore operations is configured to self-determine its downhole location in a wellbore in real-time and to self-activate upon arrival at a preselected target location. In embodiments, the device is configured to self-determine its direction of travel and self-deactivates if the device determines that it is not travelling in the downhole direction. In embodiments, the device has a flowback valve that blocks fluid flow therethrough when the device is inactivated but permits fluid flow through the device to exit at the device's trailing end when the device is activated. In embodiments, at least a portion of the device is dissolvable in the presence of wellbore fluids. In embodiments, at least a portion of the device is coated with a protective coating to shield the device from treatment fluids. A downhole tool having a pass-through constriction configured to be overcome by the device is also disclosed.

A computer-implemented method/arrangement for rapidly assessing operable conditions of each constituent tool of a MWD tool string between two consecutive downhole runs of a drill string. The method includes filtering binary data downloaded from a recently pulled MWD tool string for data sets that each represent conditions indicative of the operational condition of each of the several tools of the MWD tool string. For each of the data sets, a processing algorithm is selected from a store of predetermined algorithms, based on characteristics of the respective data set. Each data set is substantially simultaneously processed with the algorithm selected for that data set. Based on respective tool-condition data output by each algorithm-processed data set, determining whether the tool that corresponds to the respective data set meets a predetermined operational capability requirement or threshold to be operated in a subsequent run downhole with the drill string.

Systems and methods for wireless downhole telemetry are provided. The system includes a tubular located in a wellbore; a pressure controller located at or near a surface of the wellbore to send a digital command via a change in a pressure applied to the tubular; and a receiver disposed in the wellbore, wherein the receiver includes a mechanical pressure switch to detect the change in the pressure applied to the tubular.