Aspects of the disclosure relate to seal assemblies, and associated components thereof, and methods of using the same for use in pressure containing bodies, such as choke valves. In one example, a sensor is used with the seal assemblies. In one implementation, a pressure containing body apparatus includes a pressure containing body including a central opening and a central axis extending through the central opening. The pressure containing body apparatus includes a sleeve disposed in the central opening of the pressure containing body. The pressure containing body apparatus includes an angled seal disposed about the sleeve at an angle relative to the central axis of the pressure containing body. The angle is greater than 0 degrees and less than 90 degrees.

A managed pressure drilling (MPD) manifold has one or more valves that are operable by one or more actuators configured to synchronize the opening of one or more passageways in the valves with the closing of one or more of the other passageways in the valves, in order to minimize the likelihood of error and reduce response time. The valves are configured to transition smoothly between positions without fully blocking fluid flow in the manifold while changing the flow direction. The synchronization may be achieved mechanically, electrically, hydraulic, and/or pneumatically. The actuators may be remotely controlled by a control unit having a processor and control logic software, based on data collected by one or more sensors in the MPD manifold. The positions of the valves of the MPD manifold may be automatically adjusted by the control unit via the actuators.

A system and method for carbon capture and storage in a depleted hydrocarbon reservoir or dedicated aquifer is disclosed. A wellhead block includes or supports therewith a barrier subsystem having one or more of at least one isolation gate valve or one or more plugs. The barrier subsystem is to allow access to a well that is associated with the depleted hydrocarbon reservoir or dedicated aquifer. The system includes modulation valves to modulate an injection of a wellhead fluid that includes a carbon component into the wellhead block.

A closed-loop hydraulic drilling system generates choke characteristic curves or data that more accurately reflects the relationship between the commanded choke valve position and the resulting pressure drop across the choke valve for a given flow rate and fluid density. The choke characteristic curves may be generated through a calibration procedure and then used during normal operations to more accurately monitor return flow and manage wellbore pressure. The specific gravity of an injected calibration fluid and pressure drop across the choke valve may be determined and correlated to the current choke valve position to reflect the choke characteristic curve in situ, thereby providing for more precise control of wellbore pressure and enabling condition monitoring of the choke valve. In addition, an improved closed-loop hydraulic drilling system does not require a flow meter, enabling the adoption of MPD systems in low-specification and economically constrained applications.

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.

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.

Systems and methods for generating and a controller for controlling generation of geothermal power in an organic Rankine cycle (ORC) operation in the vicinity of a wellhead during hydrocarbon production to thereby supply electrical power to one or more of in-field operational equipment, a grid power structure, and an energy storage device. In an embodiment, during hydrocarbon production, a temperature of a flow of wellhead fluid from the wellhead or working fluid may be determined. If the temperature is above a vaporous phase change threshold of the working fluid, heat exchanger valves may be opened to divert flow of wellhead fluid to heat exchangers to facilitate heat transfer from the flow of wellhead fluid to working fluid through the heat exchangers, thereby to cause the working fluid to change from a liquid to vapor, the vapor to cause a generator to generate electrical power via rotation of an expander.

An insertable flow meter assembly includes a flow measuring device configured to be inserted into a flow passage of a receiving structure. The flow measuring device is configured to enable determination of a flow rate of fluid through the flow passage, the flow measuring device is formed as a single continuous structure, and an outer cross-section of at least a portion of the flow measuring device is configured to be substantially the same as an inner cross-section of the flow passage. The insertable flow meter assembly also includes an end cap configured to engage an exterior surface of the receiving structure and to couple to the receiving structure at an end of the flow passage. The end cap is configured to block movement of the flow measuring device out of the end of the flow passage.

A subplate mounted valve is disclosed having an open position and a closed position. The valve includes at least one pilot pressure intake port, a plurality of functional fluid ports, a spool movable between the open position and the closed position, and spring biasing the spool to either the open position or the closed position. To reduce water hammer due to quickly opening or quickly closing the valve, a flow regulation assembly is positioned at the pilot pressure intake port and has a chamber with a larger inlet channel at the intake position and transitioning to a smaller channel at the outlet position such that fluid flow at the intake port is reduced, thereby slowing the transition between the open position and the closed position and the transition between the closed position and the open position.

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.