Embodiments include a choke system that passes enlarged debris despite having a relatively small diameter for an input port of the choke system. Embodiments also include systems to prevent dislodging of a choke seat when backpressure is supplied to the choke system. Embodiments also include sealing systems to prevent fluid leaks around the choke seat of the choke system.

Control of a drilling system drilling a wellbore is improved using a hydraulic model corrected for pressure losses. A surface backpressure of the outlet and a standpipe pressure of the inlet are measured with sensors in the system. An estimate of the standpipe pressure is calculated based integrating from the measured surface backpressure back to the inlet in the hydraulics model. The pressure loss increment in the hydraulics model is calculated based on a difference between the measured and estimated standpipe pressures. Meanwhile, a parameter in the drilling system is monitored during drilling so the parameter can be adjusted at least partially based on the hydraulics model corrected for the pressure loss.

The debris catch provides a strainer located downstream of a rotating control device (RCD) within a flow line. The strainer is located between the RCD and at least one protected component. The strainer limits the debris and other junk that flows to protected components located downstream of the strainer. A first sensor and a second sensor detect the pressure differential between a location before the strainer and at the strainer. The two sensors detect a clog in the strainer. The strainer is removable through an access outlet for clearing the clog and reinstalling a strainer for continued drilling operation. A purge valve located in the system also allows clearing of the strainer by releasing the debris through a purge outlet located on a pathway separate from the pathway to the protected component.

An automated drilling-fluid additive system and method for on-site real-time analysis and additive treatment of drilling fluid to be injected into a well. The drilling fluid includes returned drilling fluid intended to be re-used, which has a variety of viscosity and other qualities resulting from its various preceding use. The target drilling fluid will have a variety of viscosity and other qualities depending upon and changing with various phases of drilling operations and various conditions encountered. The drilling fluid is analyzed in real time as it flows into the automated drilling-fluid additive system, and various additives are added to and thoroughly blended with the drilling fluid as needed to achieve the desired result. The blended drilling fluid is discharged from the automated drilling-fluid additive system in the proper condition for injection into a well.

A method of controlling an influx in a petroleum well with a managed pressure drilling system can include directing mud into the well; regulating a pressure of the mud proximate to a surface of the well with a choke valve; detecting, with a computing device having one or more processors, an intrusion of the influx in the well; increasing, in response to the detecting, the pressure of the mud proximate to the surface to a first level of surface back pressure by controlling the choke valve; determining, with the computing device, a volume of the influx; ascertaining an intrusion depth substantially concurrent with the detecting; and evacuating the influx in response to a correlation between both of the first level of surface back pressure and the volume of the influx relative to the intrusion depth.

A rotational continuous circulation system and methods includes a circulation sub having an internal bore extending along a central axis. The circulation sub has an uphole body having a reduced outer diameter along a downhole length of the uphole body. A central valve selectively opens and closes the uphole internal bore. At least one check valve is located within a sidewall of the uphole body to selectively allow fluid to flow into the uphole internal bore through the at least one check valve. A downhole body has an uphole portion circumscribing a downhole portion of the uphole body. A sleeve assembly circumscribes the reduced outer diameter of the uphole body. The uphole body and the downhole body are configured to rotate about the central axis independently from the sleeve assembly. A side-entry port of the sleeve assembly provides a fluid flow path from an exterior of the sleeve assembly to the at least one check valve.

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 method and apparatus for transporting a capping stack for use in a subsea structure includes a capping stack having a capping stack spool, a connector body connectable to the capping stack spool and at least one diverter leg connectable to the capping stack spool. A first skid receives the capping stack spool on a floor thereof. A second skid receives the connector body on a floor thereof. A third skid receives the diverter leg thereon. The first, second and third skids are adapted to be received within an interior of an aircraft. The skids and the connected components can then be flown by the aircraft to a desired location so as to be assembled at a location near a wellhead.

A method of managing an influx encountered during a drilling operation conducted with respect to a wellbore includes drilling a wellbore into a subterranean formation. Drilling the wellbore includes circulating a drilling fluid through a wellbore while operating a drill bit and monitoring one or more parameters associated with the drilling operation for indicia of the influx within the wellbore. The method also includes, upon detecting the indicia of the influx, determining, via an influx management model, an initial influx volume.

A device (1) for ensuring continuous circulation in well drilling includes a tubular body (2), having an axial channel (2) with a lateral opening (3) which is closed by a removable plug (5). A tubular support (9) is placed in the axial conduit and supports a shut-off member (6) which is held in position by a retainer (14). The device (1) has an adjustment ring nut (50) which exerts a pressing action between the retainer (14) and the tubular support (9) to force the tubular support (9) in an axial limit-stop position against respective positioning and centering elements (11), to allow recovery of clearances during placement of the tubular support (9) and the valve (6) supported the tubular support inside the tubular body (2).