Embodiments of the present disclosure are directed towards a back pressure valve configured to mount in a mineral extraction system. The back pressure valve includes a body comprising a venting port coaxial with a longitudinal axis of the body, a plunger configured to be in sealing engagement with the body to seal the venting port, and a lock ring disposed about the body, wherein the lock ring is configured to automatically expand radially upon removal of a tool.

A system includes a choke valve, an actuator configured to adjust a position of the choke valve, a variable frequency drive configured to adjust a speed at which the actuator adjusts the position of the choke valve, and a controller configured to receive first feedback indicative of a fluid pressure upstream of the choke valve, compare the first feedback to a first predetermined pressure range, and instruct the variable frequency drive to send electricity to the actuator at a first frequency when the first feedback is outside of the first predetermined pressure range, where the variable frequency drive is configured to control a speed and a direction of the actuator such that the actuator adjusts the position of the choke valve to a first position at a first speed, and where the first speed is based at least on a difference between the first feedback and the first predetermined pressure range.

Disclosed herein are various embodiments of methods and systems for drilling an oil or gas well safely and efficiently using underbalanced or near-balanced drilling techniques, wherein the primary means of pressure control is a Annular Pressure Control Diverter positioned below the BOP stack, with a return flow pattern where no drilling fluid returns up the (traditional) annulus between the drill pipe and the production casing and instead drilling fluid returns up the annulus between the production casing and intermediate casing. Drilling fluid returns flow through a wellhead, instead of a flow spool conventionally located below an upper RCD, and hence to the drilling choke. This drilling approach eliminates the need for hydraulic fracturing and preserves the natural fracture system of the producing formation while providing additional safety measures. It also prevents the accidental or deliberate discharge or flaring of methane during drilling and production.

Electro-responsive hydrogel particles are flowed into a first wellbore formed in a subterranean formation. An electric circuit is established between the first wellbore and a second wellbore formed in the subterranean formation. An electric current is applied through the electric circuit, thereby exposing the electro-responsive hydrogel particles to an electric field and causing at least one of swelling or aggregation of the electro-responsive hydrogel particles to form a flow-diverting plug within the subterranean formation. Water is flowed into the first wellbore to increase hydrocarbon production from the second wellbore.

A choke includes a cage having a plurality of openings extending therethrough, a first fluid port and a second fluid port, the openings in the cage fluidly interposed between the first and second fluid ports, and a selectively positionable blocking member positioned with respect to the openings to selectively overlie all of a portion of the openings, wherein the surface of the opening extending through the cage are a single crystal material. The single crystal material may be provided as an insert, having an opening therethrough, secured in position with respect to the cage.

A frac tree coupled to a wellhead is connected to either flowback equipment or zipper modules using a single straight-line connection of pipes, valves, and/or frac iron that define a straight-line pathway for fluid, gas, or flowback materials. The disclosed single straight-line connections referenced herein may be used in pressure pumping operations to deliver hydraulic fracturing fluid (“frack fluid”) to a frac tree for delivery to a wellhead or for carrying flowback from the wellhead to a flowback-collecting equipment. To dramatically reduce the wear-and-tear on the frac tree, blocks at or near the top of the frac trees are strategically lined with a high-strength wear-resistant material internally at points where frack fluid or flowback changes direction to flow toward or away from the single straight-line connections.

A fast-acting managed pressure drilling rig is disclosed. A main valve configured as an alternative for a conventional rotating control device is provided to control drilling of a wellbore. A second valve is configured to trap pressure in the wellbore. A choke valve maintains well bottomhole pressure within specified limits by trapping pressure or by releasing trapped pressure within the wellbore. A pressure relief choke is configured to provide fine pressure stability control within the well and to act as a pressure relief valve in response to wellbore overpressure. A controller is configured with at least one processor to affect operation of the main valve, the second ratio valve, the choke valve, and the pressure relief choke in response to information received by the controller representing operation of the managed pressure drilling rig.

A choke may include an inlet for receiving a flow stream. The choke may also include a valve assembly configured to receive the flow stream from the inlet and control the flow stream. The valve assembly may include a cage element, an external sleeve adapted for selectively and controllably articulating over the cage element to control the flow stream through the valve, and an impact screen surrounding both the cage element and the external sleeve and adapted to protect the cage element and the external sleeve from impacts from large objects in the flow stream. The choke may also include an outlet for delivering the flow stream from the valve assembly.

Embodiments of the present disclosure relate to an apparatus, a system and a process for regulating a wellhead control mechanism. The apparatus is configured to control actuation of a 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 and when the apparatus is in the second position the valve actuator is physically interfered from actuating. 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. Other embodiments of the present disclosure relate to a system that directly controls actuation of a wellhead actuation mechanism.

A hydraulic fracturing system can include valve apparatuses that control the delivery of fluid to high-pressure pumps that supply the fluid to a wellhead. The valve apparatuses can receive electronic signals from a control system to regulate the flow rate of the fluid to the high-pressure pumps. In one or more examples, the flow rate of the fluid can be controlled such that proppant in the fluid remains in solution.