A frac sand separator system includes a sand separator having an inlet fluidly connected to a well for receiving a fracking return mixture from the well. The sand separator is configured to separate water of the fracking return mixture from particulate matter of the fracking return mixture. The sand separator includes an outlet. The frac sand separator system includes a collection container fluidly connected to the outlet of the sand separator for receiving the particulate matter from the sand separator. At least one outlet valve is fluidly connected between the outlet of the sand separator and the collection container. The frac sand separator system includes a computing device operatively connected to the at least one outlet valve. The computing device includes a processor configured to automatically open the at least one outlet valve such that the particulate matter is released from the sand separator into the collection container.

A frac sand separator system includes a sand separator having an inlet fluidly connected to a well for receiving a fracking return mixture from the well. The sand separator is configured to separate water of the fracking return mixture from particulate matter of the fracking return mixture. The sand separator includes an outlet. The frac sand separator system includes a collection container fluidly connected to the outlet of the sand separator for receiving the particulate matter from the sand separator. At least one outlet valve is fluidly connected between the outlet of the sand separator and the collection container. The frac sand separator system includes a computing device operatively connected to the at least one outlet valve. The computing device includes a processor configured to automatically open the at least one outlet valve such that the particulate matter is released from the sand separator into the collection container.

A method to manipulate a well, comprising running an apparatus (60a) having a container (68a) with a volume of gas at a higher pressure than a surrounding portion of the well. The well is isolated, and a wireless control signal, such as an electromagnetic or acoustic signal, is sent to operate a valve assembly (62a) to selectively allow or resist fluid exit from a portion of the container (68a), via a port (61a). Some of the pressurised gas may itself be expelled in to the surrounding portion of the well, or it may be used to drive a fluid out of the container, such as an acid.

A method to manipulate a well, comprising running an apparatus (60a) having a container (68a) with a volume of gas at a higher pressure than a surrounding portion of the well. The well is isolated, and a wireless control signal, such as an electromagnetic or acoustic signal, is sent to operate a valve assembly (62a) to selectively allow or resist fluid exit from a portion of the container (68a), via a port (61a). Some of the pressurised gas may itself be expelled in to the surrounding portion of the well, or it may be used to drive a fluid out of the container, such as an acid.

A method, system and apparatus of optimizing operation of one or more tubing strings in a hydrocarbon well are provided. Each tubing string is located in a hydrocarbon well and has a plurality of valves. Each valve is actuatable between a fully open position and a fully closed position and is in communication with a respective zone of a formation defining a reservoir containing hydrocarbon material. The method includes characterizing an injectivity of one or more zones of the formation and determining an optimal operating schedule in accordance with the characterization. The optimal operating schedule comprises one or more valve configurations and an operating duration for each of the one or more valve configurations.

A method, system and apparatus of optimizing operation of one or more tubing strings in a hydrocarbon well are provided. Each tubing string is located in a hydrocarbon well and has a plurality of valves. Each valve is actuatable between a fully open position and a fully closed position and is in communication with a respective zone of a formation defining a reservoir containing hydrocarbon material. The method includes characterizing an injectivity of one or more zones of the formation and determining an optimal operating schedule in accordance with the characterization. The optimal operating schedule comprises one or more valve configurations and an operating duration for each of the one or more valve configurations.

An electric bonnet includes a housing; a guide piston disposed in the housing; an electric motor having a motor shaft; a rear housing connected to the housing; a gearbox assembly disposed in the rear housing, the gearbox assembly being coupled to the motor shaft of the electric motor; and a roller screw assembly disposed in the rear housing. A first end of the roller screw assembly is connected to the gearbox assembly, and a second end of the roller screw assembly is connected to the guide piston. Rotation of the motor shaft of the electric motor transmits rotary motion to the gearbox assembly, which transforms the rotary motion into linear motion using the roller screw assembly. The linear motion of the roller screw assembly actuates the guide piston.

A control system automatically operates a subsea well control device on detecting that a load in an Intervention Riser System (IRS) coupled to the subsea well control device has reached a threshold. The control system has a first control unit to detect that the load in the IRS has reached the threshold and a second control unit triggering actuation of the subsea well control device. The first control unit is in communication with the second control unit and issues an activation command to the second control unit to cause it to trigger actuation of the subsea well control device. The first control unit automatically issues the activation command to the second control unit upon detecting that the load in the IRS has reached the threshold, to trigger actuation of the subsea well control device prior to structural failure of an IRS.

A control system for automatically operating a well control device located in a subsea blow-out preventer (BOP), has a first control unit and a second control unit. The first control unit is connected to the second control unit and issues an activation command to the second control unit to cause it to trigger actuation of the well control device, and the first control unit is configured to automatically issue the activation command to the second control unit on detecting issue of the signal indicative of a requirement to trigger actuation of the subsea BOP shear mechanism.

A method includes obtaining a reservoir model for a subsurface reservoir, identifying a current state of the subsurface reservoir using the reservoir model, and a computer processor selecting an optimization function from multiple optimization functions according to the current state of the reservoir to obtain a selected optimization function. The method further includes the computer processor calculating valve positions of physical devices using the selected optimization function. The valve positions are implemented.