Abstract: A method of actuating a subsea tree comprising opening a valve assembly by transferring a first volume of fluid into a first chamber and closing the valve assembly from the open position to a shear position via a gas charged valve actuator in response to the transfer of fluid out of the first chamber. Shearing a workstring positioned within an axial bore of the valve assembly with the valve via the gas charged valve actuator. Closing the valve from the shear position to a closed position with one or more gas charged push rods to isolate the wellbore above from the wellbore below the closed valve. The shearing force generated from the gas charged valve actuator is greater than the closing force of the one or more push rods.

Abstract: A shift uphole-to-open sleeve assembly is provided for insertion along a tubular string for multi-stage, selectable wellbore treatment. The sleeve assemblies are very short in length, being too short for in-sleeve engagement, and instead have a downhole shoulder engageable for opening using dogs of a conventional shifting tool. Use of a common J-mechanism having four axial inappropriately places the sealing packer of a downhole tool above the sleeve ports. Multiple extra J-mechanism cycles are required to position the packer downhole thereof. Herein a modified downhole tool is disclosed including a biased repositioning sub to eliminate many of the extra tool cycles. In embodiments the short sleeve can replace casing collars.

Abstract: A fitting assembly for fluid device is provided, which includes a first port, a second port, a first annular member, a second annular member, and a connector. The first port is annular and installed at a first fluid device to be connected with its first fluid channel. The second port is annular and installed at a second fluid device to be connected with its second fluid channel. The first annular member is installed at the first port and has a first coupler. The second annular member is installed at the second port and has a second coupler to be coupled with the first coupler to fix the second annular member to the first annular member. The connector is installed between the first port and the second port and seals gaps between the connector and the first and second ports.

Abstract: A rotary joint capable of lubricating a sealing surface of a mechanical seal forming a fluid passage through which a gas flows using a liquid even when the liquid flows through only one fluid passage is disclosed. A rotary joint includes a plurality of mechanical seals provided in an axial direction in an annular space between a case body and a shaft body to form a first intermediate flow passage that connects a first outer flow passage and a first inner flow passage of a first fluid passage through which a liquid flows to each other and form a second intermediate flow passage that connects a second outer flow passage and a second inner flow passage of a second fluid passage through which a gas flows to each other.

Abstract: A quick connector for establishing a snapping connection between a tubular male part (50) and a female part (40) of a fluid connection system. The connector has a retainer (10) adapted to be set within the mouth portion (41) of the female part (40) and having a resilient member (20) for snapping engagement with both a thickened portion (52) of the male part (50) and an annular groove (42) in the mouth portion (41) of the female part (40) when the resilient member (20), which is held by the a retainer (10) in an axially fixed position, is stretched in the radial direction due to the snapping engagement with the male part (50).

Abstract: Connectors may include a first part and a second part that are adapted to be locked together. The first and second parts may include compatible features that provide one or more connections, such as electrical and hydraulic connections, when the first and second part are secured together.

Abstract: A fluid rotary joint assembly capable of high rotational speed exceeding a maximum rotational speed of a single rotary joint is disclosed herein. For example, the fluid rotary joint may be capable of exceeding rotational speeds greater than 1500 RPM. The fluid rotary joint assembly may have several single-stage fluid rotary joints and multiple gear devices wherein a relative speed between the first and second rotary parts of each single stage fluid rotary joint does not exceed a maximum rotary speed (e.g., 500 rpm). The fluid rotary joint assembly incorporates speed reduction within each stage through the gear device. By controlling the relative speed between the first and second parts of each of the fluid rotary joints to be less than or equal to a maximum allowable rotational speed (e.g., less than or equal to 500 RPM), the fluid rotary joint assembly provides for reliable operation at high rotational speeds between the first stage and the last stage.

Abstract: This application discloses an improved downhole assembly for separating oil and gas in an oil well. A flow through assembly is disclosed wherein separated gas may pass an anchoring device with less restriction. The improved flow through assembly allows for separated gas to pass through the center flow channel of an anchoring device.

Abstract: A method for coupling a fitting to a tubing end includes pressing a collar over the outer surface of the tubing until the strain on the collar in the hoop direction is at a predetermined level, or pressing a collar with a predetermined axial load.

Abstract: Systems and methods for operating hydraulic fracturing units to pump fracturing fluid into a wellhead may include receiving a target flow rate and/or a target pressure for fracturing fluid supplied to the wellhead. The systems and methods may increase a flow rate from the hydraulic fracturing units according to a controlled increasing flow rate schedule toward the target flow rate and/or target pressure. When it has been determined the target flow rate and/or target pressure has been achieved, the systems and methods also may include operating the hydraulic fracturing units to maintain the target flow rate and/or target pressure. When the target flow rate has not been achieved, the systems and methods also may include generating notification signals, and/or when the target pressure has not been achieved, the systems and methods further may include operating the hydraulic fracturing units to maintain a maximum flow rate.

Abstract: Threaded joint for oil and gas pipes, including a female part and a male part, the female part being a joint tubular body including a threaded coupling section, a seal section which prolongs the coupling section, the male part including a tubular body which includes a first section which external surface is threaded, a second sealing section including a seal surface which cooperates with the female part seal surface for sealing the joint, the sealing surface of the female part being made of conical sections, the sealing surface of the male part includes a proximal portion closer to the first section and a distal portion, the proximal section portion being a conical surface which forms a first seal with the sealing surface of the female part and the distal portion having a convex surface which forms a second seal with the sealing surface of the female part.

Abstract: A sealing cover with quick-plug interface, comprising: cover body, above which a through hole is arranged, and in which a communication hole is arranged, and said through hole is connected with said communication hole; an annular sealing member and an annular fixing sleeve are arranged in said through hole, and said sealing member is arranged at the bottom of said through hole, and said fixing sleeve is arranged above said sealing member; said sealing member and said fixing sleeve are both clipped to an inner wall of the through hole, and said sealing member is made of a flexible material. There is no metal material in contact with the fluid inside the sealing cover with quick-plug interface, so there is no hidden danger of corrosion in long-term use, and the defect that the metal material is not resistant to corrosive fluids is avoided.

Abstract: Systems and methods for operating hydraulic fracturing units to pump fracturing fluid into a wellhead may include receiving a target flow rate and/or a target pressure for fracturing fluid supplied to the wellhead. The systems and methods may increase a flow rate from the hydraulic fracturing units according to a controlled increasing flow rate schedule toward the target flow rate and/or target pressure. When it has been determined the target flow rate and/or target pressure has been achieved, the systems and methods also may include operating the hydraulic fracturing units to maintain the target flow rate and/or target pressure. When the target flow rate has not been achieved, the systems and methods also may include generating notification signals, and/or when the target pressure has not been achieved, the systems and methods further may include operating the hydraulic fracturing units to maintain a maximum flow rate.

Abstract: A suspension head (11) is provided for connection between a high pressure riser (8) and a subsea wellhead (9), for use in drilling and completion operations in which a jack-up rig (1) is employed and a blowout preventer (7) is installed on the jack-up rather than on the wellhead. The use of the suspension head (11) offers improved safety and convenience, allowing the riser (8) to be isolated from the wellhead (9) in emergencies or for carrying out certain operations which would otherwise require the installation of a temporary plug. (FIG.

Abstract: A one-touch high-pressure fluid fitting using a spring, in which the spring is used to press a sealing ring and simultaneously elastically support an inward inclined surface of a fitting cap, and the fitting cap is expanded upon unfastening so as to maintain an internal airtightness of a fitting body and allow a detachable structure between the fitting body and the fitting cap to be smoothly implemented.

Abstract: A connector system includes a first riser joint configured to form part of a riser. The first riser joint includes a pin. The connector system also includes a connector configured to couple to a wellhead assembly. The connector includes multiple collet segments that are configured to move radially-inwardly to engage the pin of the first riser joint.

Abstract: An expansion loop for a piping system. The expansion loop has a first flexible conduit with a first end and a second end and a second flexible conduit with a first end and a second end. A first rigid conduit is connected between the first ends of the first and second flexible conduits. Additional rigid conduits are connected to both of the second ends of the flexible conduits. These additional rigid conduits include a stainless-steel elbow, a conversion conduit, and a copper conduit. The expansion loop may be installed wherein the flexible conduits are bent, when fluid flows, the flexible conduits straighten out and are not bent.

Abstract: A method of using a mechanical joint restraint includes inserting an end of a pipe length into a gland bore of a gland, a ring bore of a gripping ring, and a gasket bore of a gasket, the gland, the gripping ring, and the gasket together forming the mechanical joint restraint; inserting at least a portion of the gasket of the mechanical joint restraint into a socket of a piping element; inserting the end of the pipe length into the socket of the piping element; and drawing the gland towards a flange of the piping element to compress the gasket into sealing engagement with the piping element and the pipe length.

Abstract: A coupling comprising a receiving element, a securing element, a retaining element and an insertion element, wherein the securing element is adapted to be displaceable between a release position and a locking position along a displacement axis, the securing element being adapted to engage the at least one retaining element in such a manner that a displacement of the securing element from the release position in the direction of the locking position is prevented, and wherein the insertion element is adapted to interact with the at least one retaining element upon insertion of the insertion element into the receiving space of the receiving element in such a way that a displacement of the securing element from the release position into the locking position is enabled.

Abstract: A gland includes an annular ring, the annular ring defining a gland bore, the gland bore defining a gland axis extending through the annular ring; and a joint restraint assembly, the joint restraint assembly including a restraint base, the restraint base attached to the annular ring, the restraint base defining a restraint pocket, the restraint base including a structural rail; a gripper, the gripper disposed within the restraint pocket and configured to move in the restraint pocket; a spring biasing the gripper to move inwards towards the gland axis; and a cover contacting at least a portion of the restraint base.