A composite fracturing tree includes an operating valve and a master valve in fluid communication with the operating valve. The master valve includes an inlet portion in fluid communication with the operating valve, an outlet portion, and a gate portion. The gate portion is disposed between the inlet portion and the outlet portion. The gate portion is moveable between a flow position and an occluding position. In the flow position, the gate portion permits flow between the inlet portion and the outlet portion. In the occluding position, the gate portion prevents flow from the inlet portion to the outlet portion. The gate portion is actuated from the flow position to the occluding position with a closing force and from the occluding position to the flow position with an opening force. The master valve allows for the closing force to reduced compared to conventional fracturing valves.

A composite fracturing tree includes an operating valve and a master valve in fluid communication with the operating valve. The master valve includes an inlet portion in fluid communication with the operating valve, an outlet portion, and a gate portion. The gate portion is disposed between the inlet portion and the outlet portion. The gate portion is moveable between a flow position and an occluding position. In the flow position, the gate portion permits flow between the inlet portion and the outlet portion. In the occluding position, the gate portion prevents flow from the inlet portion to the outlet portion. The gate portion is actuated from the flow position to the occluding position with a closing force and from the occluding position to the flow position with an opening force. The master valve allows for the closing force to reduced compared to conventional fracturing valves.

A valve assembly is installed within a wellhead such as a conventional tubing hanger or casing hanger used to suspend pipe or other tubular goods in a well. A seal bushing assembly is installed in a tubing head assembly or other wellhead component. A hanger valve assembly is stung into the seal bushing assembly and includes a valve that can be selectively opened or closed. In the open position, the valve does not restrict a central flow path diameter through the hanger and wellhead. In the closed position, the valve contains pressure and/or fluid flow and fully seals against wellbore pressure acting on the valve. A wellhead adapter covers the hanger valve assembly and provides an attachment point for a conventional Christmas tree or other wellhead equipment.

A valve assembly is installed within a wellhead such as a conventional tubing hanger or casing hanger used to suspend pipe or other tubular goods in a well. A seal bushing assembly is installed in a tubing head assembly or other wellhead component. A hanger valve assembly is stung into the seal bushing assembly and includes a valve that can be selectively opened or closed. In the open position, the valve does not restrict a central flow path diameter through the hanger and wellhead. In the closed position, the valve contains pressure and/or fluid flow and fully seals against wellbore pressure acting on the valve. A wellhead adapter covers the hanger valve assembly and provides an attachment point for a conventional Christmas tree or other wellhead equipment.

A method and apparatus are disclosed for reducing flow induced vibration in at least one subsea structure. The method comprises the steps of, via at least one subsea acoustic sensor (190), detecting at least one characteristic associated with acoustic energy in sea water proximate to the sensor (190), responsive to the detected characteristic, varying at least one operational parameter of a fluid flowing along a fluid flow pathway associated with a pipe member (160).

A method and apparatus are disclosed for reducing flow induced vibration in at least one subsea structure. The method comprises the steps of, via at least one subsea acoustic sensor (190), detecting at least one characteristic associated with acoustic energy in sea water proximate to the sensor (190), responsive to the detected characteristic, varying at least one operational parameter of a fluid flowing along a fluid flow pathway associated with a pipe member (160).

A check valve bleed assembly eliminates the requirement for a person to enter the red zone when bleeding the grease out of a gate or other valve. A gas or other fluid is provided to the check valve bleed assembly. The gas or other fluid acts upon the surface driving a pin into the associated check valve with sufficient force to overcome the resistance of the object sitting on a seat and moves the object off of the seat. The force is maintained as long as is necessary. Usually, the check valve is held open until the gate transitions into the gate's associated gate recess thereby displacing the grease within the gate recess through the check valve, into the check valve bleed assembly, and finally to a waste collection tube. In some embodiments a gate valve greasing access port is included in the check valve bleed assembly such that grease may be injected into the check valve bleed assembly.

A large diameter injection water well is drilled using a drilling derrick and rotary drilling techniques. After snubbing in and drilling a short distance with drilling mud, a temporary drilling header is installed below the blowout preventers. Extending downward from the temporary drilling header is a drop pipe with a valve on the lower end thereof. Drilling pipe with attachments on the lower end thereof, are lowered into the drop pipe with the valve closed. After sealing to the drilling pipe, the valve is opened and the drilling pipe and attachments are lowered to the bottom of the well for the normal drilling operation. Thereafter, the drilling pipe and attachments are removed reversing the process of retracting into the drop pipe and closing the valve before removing the seal from the drilling pipe. The repeated insertion of the drilling pipe with various attachments on the end thereof in the drilling procedure occurs without having to kill or suppress the well until the final step when removing the drop pipe. Large diameter drillable centering guides insures pilot holes are being drilled in the bottom center of the large diameter injection water well.

A large diameter injection water well is drilled using a drilling derrick and rotary drilling techniques. After snubbing in and drilling a short distance with drilling mud, a temporary drilling header is installed below the blowout preventers. Extending downward from the temporary drilling header is a drop pipe with a valve on the lower end thereof. Drilling pipe with attachments on the lower end thereof, are lowered into the drop pipe with the valve closed. After sealing to the drilling pipe, the valve is opened and the drilling pipe and attachments are lowered to the bottom of the well for the normal drilling operation. Thereafter, the drilling pipe and attachments are removed reversing the process of retracting into the drop pipe and closing the valve before removing the seal from the drilling pipe. The repeated insertion of the drilling pipe with various attachments on the end thereof in the drilling procedure occurs without having to kill or suppress the well until the final step when removing the drop pipe. Large diameter drillable centering guides insures pilot holes are being drilled in the bottom center of the large diameter injection water well.

Embodiments of systems and methods for generating power in the vicinity of a drilling rig are disclosed. During a drilling operation, heat generated by drilling fluid flowing from a borehole, exhaust from an engine, and/or fluid from an engine's water (or other fluid) jacket, for example, may be utilized by corresponding heat exchangers to facilitate heat transfer to a working fluid. The heated working fluid may cause an ORC unit to generate electrical power.