An assembly and method for a choke valve body having a choke valve to control flow of fluids. A sleeve positioned in and attached to the choke valve body to flow the fluids through an inner sleeve region internal to the sleeve instead of an outer sleeve region external to the sleeve.

Embodiments of the present disclosure include a method including receiving first impact data. The method includes receiving second impact data. The method includes applying a first filter to both the first impact data and the second impact data. The method includes applying a second filter to both the first impact data and the second impact data. Filtering includes time and frequency based discriminating filter to isolate specific signatures that representatively indicate impact signatures generated by the sand on the interrogator. The method includes comparing the first impact data and the second impact data for corresponding signatures. The method includes identifying a corresponding signature in both the first impact data and the second impact data. The method includes determining the corresponding signature meets a threshold criterion. The method includes determining one or more particulate properties based at least in part on the corresponding peak.

Systems and methods for performing operations on a well include first and second flow control devices positioned between upper and lower sections of a conduit. An upper connector assembly engaged with the upper section includes connectors adapted for connection to a chemical stimulation device, a blowout preventer, or other well intervention apparatuses. A lower connector assembly engaged with the lower section includes connectors adapted for connection to a chemical stimulation device, a running tool, wellbore conduits, or other well intervention apparatuses. The two connector assemblies, above and below the flow control devices, enable sequential or simultaneous operations to be performed, and can enable operations to be performed independent of the state of the flow control devices.

A method and apparatus for controlling pressure in a drilling system that includes a drilling fluid return flow path. Steps include providing a choke system comprising a first flowline having an inlet and an outlet each connected to the drilling fluid return flow path, wherein the outlet connects to the return flow path downstream of the inlet connection, a first choke positioned on the flowline, a second choke positioned on the flowline downstream of the first choke, and a control module for controlling the first and second chokes; flowing drilling fluid through the first flowline while at least one of the first and second choke is partially closed so as to cause a pressure drop; in response to an input, opening the partially closed choke and partially closing the other choke so as to substantially maintain the pressure drop; returning the chokes to the original flow status.

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.

An assembly includes an inlet hub (112) coupled to a first flow passage (124) located within a flow control module, the first flow passage having a first flow bore, a flow meter (144) associated with the first flow bore and positioned for top-down fluid flow, a choke (109) disposed in a second flow passage (136) having a second flow bore, and an outlet hub (119) coupled to a distal end of the second flow passage. A system includes a flow control module assembly (902) having an inlet (912) and at least two outlets (914, 916), a main line (920) in fluid communication with the inlet, a first branch line (922) coupled to the main line and to a first outlet (916) of the at least two outlets, and a second branch line (924) coupled to the main line and to a second outlet (914) of the at least two outlets, and a tie-in connector (918) coupled to the inlet of the flow control module assembly.

A flow control module includes an inlet hub coupled to a first flow passage having a first flow bore, a flow meter associated with the first flow bore and positioned for top-down fluid flow, a choke disposed in a second flow passage having a second flow bore, the second flow passage coupled to a distal end of the first flow passage, and an outlet hub coupled to a distal end of the second flow passage, the outlet hub facing in a different direction from the inlet hub.

A method for remotely controlling services to a well during hydraulic fracturing operations includes generating a high pressure fluid and pumping the high pressure fluid into a subterranean geologic formation through a wellbore of a first well, the high pressure fluid being provided at a sufficient pressure to fracture the subterranean geologic formation. The method also includes performing a service on a second well, the second well being located within a pressure zone defined around the first well and the second well. The method further includes controlling the performance of the service from a remote operations hub.

The present invention provides an improved hydraulically activated clamping device for connecting a wellhead and or Christmas tree positioned on a wellhead to a fracing tree that may comprise a connector body; a mandrel body; two or more clamp segments; two or more actuating bolts; a seal ring to provide sealing engagement between said connector body and said mandrel body; one or more motors driving each of said two or more actuating bolts; and control means to reduce or retard the power to the first of said two or more actuating bolts to release and prevent its further movement until the other of said actuating bolts release also.

An apparatus includes a conduit forming part of a drilling fluid return path from a wellbore. The the conduit has at least one well outflow control in the conduit. The at least one well fluid outflow control has at least two annular flow restrictors each separately operable to close to a respective inner diameter.