A system for determining completion parameters for a wellbore includes a sensor and a computing device. The sensor can be positioned at a surface of a wellbore to detect data prior to finishing a completion stage for the wellbore. The computing device can receive the data, perform a history match for simulation and production using the sensor data and historical data, generate inferred data for completion parameters using the historical data identified during the history match, predict stimulated area and production by inputting the inferred data into a neural network model, determine completion parameters for the wellbore using Bayesian optimization on the stimulated area and production from the neural network model, profit maximization, and output the completion parameters for determining completion decisions for the wellbore.

A system for determining completion parameters for a wellbore includes a sensor and a computing device. The sensor can be positioned at a surface of a wellbore to detect data prior to finishing a completion stage for the wellbore. The computing device can receive the data, perform a history match for simulation and production using the sensor data and historical data, generate inferred data for completion parameters using the historical data identified during the history match, predict stimulated area and production by inputting the inferred data into a neural network model, determine completion parameters for the wellbore using Bayesian optimization on the stimulated area and production from the neural network model, profit maximization, and output the completion parameters for determining completion decisions for the wellbore.

A downhole tool for cleaning and sealing a wellbore includes a wash tool configured at a downhole end of the downhole tool to generate pulses of a first fluid at a first frequency and a first pressure for washing a target interval of a wellbore. The downhole tool further includes a plugging tool configured uphole or downhole from the wash tool to generate pulses of a second fluid at a second frequency and a second pressure for depositing a sealing plug at the target interval of the wellbore. The second fluid has a higher viscosity than the first fluid, the second frequency is lower than the first frequency, and the second pressure is higher than the first pressure.

Aspects of the subject technology relate to systems and methods for improving cluster and surface efficiency in hydraulic fracturing by utilizing a stage optimization tool. Systems and methods are provided for receiving one or more perforation parameters of a wellbore, generating a perforation schema based on the one or more perforation parameters, training a stage optimization model based on the perforation schema to generate an optimized perforation schema, estimating a pressure of the wellbore based on the optimized perforation schema, and updating the optimized perforation schema until the estimated pressure is less than a predetermined pressure limit.

Wellbore isolation devices, methods of use, and downhole tools and systems comprising the wellbore isolation devices. A wellbore isolation device comprises a component selected from the group consisting of a mandrel, a packer element, a sealing ball, a wedge, a slip, a mule shoe, a wiper element, a wiper body, and any combination thereof; wherein the component comprises a degradable non-metallic material that degrades upon exposure to a wellbore environment; and wherein the degradable non-metallic material is a composite material comprising a non-epoxy matrix material and a reinforcing material.

Wellbore isolation devices, methods of use, and downhole tools and systems comprising the wellbore isolation devices. A wellbore isolation device comprises a component selected from the group consisting of a mandrel, a packer element, a sealing ball, a wedge, a slip, a mule shoe, a wiper element, a wiper body, and any combination thereof; wherein the component comprises a degradable non-metallic material that degrades upon exposure to a wellbore environment; and wherein the degradable non-metallic material is a composite material comprising a non-epoxy matrix material and a reinforcing material.

A system and methods according to which a controller communicates control signals to a first frac leg, which includes a wellhead operably associated with a first wellbore, a valve operably coupled to the wellhead, opposite the first wellbore, a frac line operably coupled to the wellhead, and a zipper module operably coupled to the frac line, opposite the wellhead. The first frac leg includes a first sub-controller that receives control signals from the controller. A grease system lubricates the first frac leg and the zipper module. The grease system includes a second sub-controller that receives control signals from the controller. A second frac leg is operably associated with a second wellbore. The second frac leg includes a third sub-controller that receives control signals from the controller. The first, second, and/or third sub-controllers may receive control signals from the controller via a communication bus.

A system and methods according to which a controller communicates control signals to a first frac leg, which includes a wellhead operably associated with a first wellbore, a valve operably coupled to the wellhead, opposite the first wellbore, a frac line operably coupled to the wellhead, and a zipper module operably coupled to the frac line, opposite the wellhead. The first frac leg includes a first sub-controller that receives control signals from the controller. A grease system lubricates the first frac leg and the zipper module. The grease system includes a second sub-controller that receives control signals from the controller. A second frac leg is operably associated with a second wellbore. The second frac leg includes a third sub-controller that receives control signals from the controller. The first, second, and/or third sub-controllers may receive control signals from the controller via a communication bus.

A method of using a hybrid tool to perforate a formation comprising the steps of deploying a hybrid tool into a wellbore positioned in the formation; activating a laser beam from the swivel laser head of the hybrid tool; and drilling a tunnel with the laser beam, Followed by, reducing a power of the laser; operating the laser beam at the heating power such that a first spherical heat zone expands from the first point; and drilling a second span of tunnel extending from the first point to a second point. Finally, reducing the power of the laser beam to the heating power; operating the laser beam at the heating power to increase the temperature at the second point such that a second spherical heat zone expands from the second point; and detonating the shaped charged aligned with a targeted perforation path with detonating cord.

A shaped charge assembly for selectively expanding a wall of a tubular includes first and second explosive units that are each symmetrical about an axis of revolution. Each explosive unit includes an explosive material that is liner-less. The first and second explosive units comprise a predetermined amount of explosive sufficient to expand, without puncturing, at least a portion of the wall of the tubular into a protrusion extending outward into an annulus adjacent the wall of the tubular.