An apparatus, a system and a process may be used for regulating a wellhead control mechanism. The apparatus may control actuation of the wellhead control mechanism by moving a moveable body of the apparatus between a first position and a second position. When the apparatus is in the first position, a valve actuator is actuatable. When the apparatus is in the second position the valve actuator is physically interfered from actuating. Additionally, when the apparatus is in the second position, the wellhead control mechanism cannot be actuated and is held in either an open, a partially open or a closed position. Further, a system may directly control an actuation of a wellhead actuation mechanism.

A choke valve system operable to obtain sand production measurements from a sand production sensor, compare the sand production measurements to a target sand production range for a current setting of a choke valve, and, in response to determining that the sand production measurements are outside of the target sand production range, adjust the setting of the choke valve in an effort to bring the sand production of the well into a target sand production range, and generate an alert regarding the out of range sand production measurements and the corresponding adjustment of the choke valve.

A pressure bleed-off module for an oil well includes: an inlet receiving fluid from an annulus vent of the well; an outlet sending the received fluid to a kill valve of the well; and two paths coupled in parallel between the inlet and the outlet. Each path channels a flow of the received fluid from the inlet to the outlet and includes: a pressure relief valve dividing the path into an inlet side coupled to the inlet and an outlet side coupled to the outlet, opening when the pressure of the fluid in the inlet side exceeds a threshold, and closing when the inlet fluid pressure is below the threshold; pressure gauges measuring the inlet fluid pressure and the pressure of the fluid in the outlet side; a pressure recorder recording the measured inlet and outlet fluid pressures; and a sampling point for draining the fluid in the outlet side.

A drilling system includes a choke valve system in fluid communication with a wellbore via a fluid return line. The choke valve system is configured to receive a return fluid from the wellbore. The choke valve system includes a choke valve through which the return fluid flows and a valve position sensor configured to determine a position of the choke valve. The drilling system further includes a controller in signal communication with the valve position sensor. The controller is programmed to determine a flow rate of the return fluid through the fluid return line based on the determined position of the choke valve. The controller is further programmed to adjust the position of the choke valve in response to the determined flow rate of the return fluid.

Safe dynamic handover between MPD and well control operations provides the ability to automate MPD, well control, and transitions therebetween while maintaining the wellbore in a dynamic fluid state at all times. In the event a kick is taken, a safe dynamic handover from MPD to well control operations is made, unknown formation fluids within the wellbore are circulated out of the wellbore, and a safe dynamic handover from well control operations to MPD is made while maintaining the wellbore in dynamic fluid state, without ever going static with respect to fluids within the wellbore. Because the wellbore remains dynamic, the formation of gels is prevented, thereby preventing pressure spikes during the start-up of the mud pumps and improving pressure transmission throughout the well system. Pressure may be more precisely managed during all phases of MPD, well control, and transitions therebetween.

Provided is a hydrocarbon well choke system that includes a choke valve and a choke control system adapted to obtain production data from production sensors of the well (e.g., including flowrate, wellhead pressure, wellhead temperature, water cut and gas-oil-ratio (GOR) data obtained by way of respective sensors of the well), generate (based on the data) a well profile that is indicative of the flow of production from the well for different settings of the valve, receive (from a well control system) a target production rate, determine (based on the well profile) whether the rate is obtainable, in response to determining that the rate is obtainable, determine (based on the well profile) a choke setting that corresponds to the rate, and control the choke valve to operate at the setting, and, in response to determining that the rate is not obtainable, communicate (to the well control system) a corresponding alert.

An apparatus can include a choke with a flow restrictor member having at least two positions, a flow coefficient Cv of the choke with the flow restrictor member in one position being less than with the flow restrictor member in the other position, and an operational device that displaces the flow restrictor member at a variable actuation rate, the actuation rate with the flow restrictor member in one position being less than with the flow restrictor in the other position. A method can include displacing a flow restrictor member, thereby decreasing a flow coefficient Cv of a choke, and decreasing a rate of change of the flow coefficient Cv in response to decreasing the flow coefficient Cv. A drilling system can include a choke with a flow restrictor member, and a continuously variable transmission which causes an actuation rate to vary based on a position of the flow restrictor member.

Disclosed is an intermittent pressure switch for pneumatic valves to control pressure relief valves in oil and gas producing operations by directing the valve to open and close based on pressure parameters (pre)set by the user. This enables oil and gas wells to produce based on formation pressure buildup. The inventive switch consists of a box containing a pressure switch programmable from 0 to 5,000 psi, a 3-port solenoid valve, 24 volt battery system, solar panel, solar control charger, pressure gauge, circuit wiring, and pressure fittings.

A method for remotely signalling a downhole assembly comprising one or more downhole tools includes operating a choke arrangement configured to control production fluid flow from a wellbore to produce a first pressure signature in the fluid flow, the first pressure signature defining a trigger signal for the one or more downhole tools of the downhole assembly. The first pressure signature comprises at least a first pressure signal and a second pressure signal in the production fluid flow in the downhole assembly. Operating the choke arrangement to produce a second pressure signature in the production fluid flow in the downhole assembly at a predetermined time period following the first pressure signature, the second pressure signature defining a command signal for initiating operation of a predetermined one or more of the downhole tools of the downhole assembly.

An inventive lock open device for use with a poppet type check valve is disclosed. The device permits bidirectional flow of fluid or gas by defeating the check valve sealing device which permits hydrostatic testing without the need for check valve disassembly or the need for additional tooling.