A pumping system includes a primary suction tank including a first pressure sensor operatively connected to a first portable suction control for measuring a first pressure of a fluid coming from the primary suction tank, and a first flow meter operatively connected to the first portable suction control for measuring a first flow rate of the fluid coming from the primary suction tank, wherein an output of the primary suction tank is controlled by a first valve, a secondary suction tank, a rig pump operatively connected to the primary suction tank, and the secondary suction tank, and a rig stand pipe connected to a drilling well, and a controller operatively connected to the first portable suction control, the first valve, and a second flow meter configured to measure a second flow rate of the fluid coming out of the rig pump.

Systems and methods for extracting hydrocarbon gas utilize a vacuum chamber with a mud chamber portion that is expandable and contractible. Gas is extracted at vacuum pressures.

A fluid flow system may comprise an input line connected to a drilling system, one or more fluid flow lines connected to the input line, and an output line connected to the one or more fluid flow lines. The system may further include one or more valves disposed in each of the one or more fluid flow lines and one or more pressure sensors disposed in each of the one or more fluid flow lines. A method for controlling a fluid flow system may comprise moving a drilling fluid from a borehole into an input line of the fluid flow system, directing the drilling fluid through the input line into a fluid flow line, measuring a first pressure at a first pressure sensor in the fluid flow line, and measuring a second pressure at a second pressure sensor in the fluid flow line.

Disclosed is a manifold implemented in multi-channel system deployed in an oil well for controlling flow of fluids. The multi-channel system includes plurality of passageways to transport one or more fluids from the oil well. The manifold includes body having plurality of inlet ports and plurality of outlet ports, and a flow control arrangement provided in the body. The flow control arrangement including a channel formed between each one of the inlet ports and one of the outlet ports, and a check valve arranged in the channel at each one of the inlet ports of the body. The channel is adapted to receive fluids through the inlet port of the body creating a differential pressure between the inlet ports and the outlet ports. The check valve is configured to regulate flow of fluids into the channel based on the created differential pressure.

A tool circulates drilling fluid through and rotates a pipe string while making up or breaking out a stand of pipe. The tool includes a clad configured to grip and seal around the RCCT sub. The clad includes a body portion, an inner ring configured to selectively rotate independently, an outer ring configured to be stationary with respect to the inner ring, the outer ring having at least two annular protrusions, a first arm configured to engage with a first annular protrusion, a second arm configured to engage with a second annular protrusion, and a stinger configured to latch into the at least one side entry port and allow the sub and the drill pipe string to rotate independent of the clad. The clad is configured to avoid or prevent stuck pipe incidents.

Described herein is a system for relieving pressure in a drillstring on a drilling rig. The system includes a remote switch which moves from a closed-valve position to an open-valve position. The system also includes a valve actuator which moves from a first valve actuator position to a second valve actuator position when the remote switch moves from the closed-valve position to the open-valve position. The system further includes a valve to route a drilling fluid from the drillstring to a flowline via a bleed-off line when the valve moves from a closed position to an open position as the valve actuator moves from the first valve actuator position to the second valve actuator position.

A method for maintaining a constant bottom hole pressure during wellbore drilling operations, the method comprising supplying drilling fluid to the drill string via a top drive at a first pressure while flow of drilling fluid out of a wellbore annulus is restricted by a choke to hold pressure in a wellbore annulus and supplying drilling fluid to the drill string via the top drive at a second pressure lower than the first pressure and to a circulation coupler at a third pressure while flow of drilling fluid out of a wellbore annulus is restricted by a choke to hold pressure in the annulus, wherein the sum of the second and third pressures is approximately the same as the first pressure. The method also comprises supplying drilling fluid to the drill string via the circulation coupler at the third pressure while pumping drilling fluid into the wellbore annulus by a back pressure pump, wherein the bottom hole pressure at the bottom of the wellbore is maintained substantially constant during all steps of supplying drilling fluid to the drill string.

An underbalanced drilling system is provided. A bottomhole assembly includes a drill bit drilling a wellbore in a formation underbalanced. The bottomhole assembly includes a telemetry sub. A telemetry component transmits signals in real-time between the telemetry sub of the bottomhole assembly and a controller on the surface. A drill string is coupled with the bottomhole assembly, and the drill string includes a plurality of drill collars. The drill collars form a channel through which drilling fluid flows from the surface to the bottomhole assembly. The drill string is inserted into the wellbore by a hydraulic work over unit. A continuous circulation component provides continuous circulation of the drilling fluid while a new drill collar is coupled to the drill string. The continuous circulation component substantially maintains a wellbore density at a predetermined density.

Described herein is a system for relieving pressure in a drillstring on a drilling rig. The system includes a remote switch which moves from a closed-valve position to an open-valve position. The system also includes a valve actuator which moves from a first valve actuator position to a second valve actuator position when the remote switch moves from the closed-valve position to the open-valve position. The system further includes a valve to route a drilling fluid from the drillstring to a flowline via a bleed-off line when the valve moves from a closed position to an open position as the valve actuator moves from the first valve actuator position to the second valve actuator position.

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.