A high-integrity pressure protection system Christmas tree is provided. In one embodiment, an apparatus includes a Christmas tree, a choke coupled to receive fluid from the Christmas tree, and a high-integrity pressure protection system. The high-integrity pressure protection system includes pressure sensors downstream of the choke, valves upstream of the choke, and a logic solver connected to control operation of the valves of the high-integrity pressure protection system that are upstream of the choke. Further, the valves of the high-integrity pressure protection system that are upstream of the choke include at least two valves of the Christmas tree. Additional systems, devices, and methods are also disclosed.

There is provided systems, methods and apparatus for the use of directed energy, including high power laser energy, in conjunction with mechanical shearing, sealing and closing devices to provide reduced mechanical energy well control systems and techniques.

An apparatus that includes a chemical injection management system. The chemical injection management system may include an interface configured to couple the chemical injection management system to a mineral extraction system. In addition, the chemical injection management system may include an ultrasonic flow meter.

An apparatus that includes a chemical injection management system. The chemical injection management system may include an interface configured to couple the chemical injection management system to a mineral extraction system. In addition, the chemical injection management system may include an ultrasonic flow meter.

A christmas tree assembly for a subsea hydrocarbon extraction facility, the christmas tree assembly includes a fluid pipeline and a sensor assembly comprising a plurality of sensors configured to monitor a plurality of properties relating to hydrocarbon fluid flow through the fluid pipeline. The sensor assembly includes a differential pressure sensor that is disposed at one or more of across a choke, around a bend or restriction in the pipeline or a dedicated flow restrictor integrated within the pipeline, and a bulk density sensor that is disposed in one or more of a blind T, before or after a choke or in an upwards section of the flow pipeline.

A load transfer profile for connection of two bodies without preloading uses a horizontal force couple instead of a vertical force couple for maximum efficiency. The load transfer profile includes a series of tapers and/or diameters that create a radial force couple separated by an axial distance. In particular, the load transfer profile includes at least a first horizontal contact and a second horizontal contact, where each contact is a landing shoulder followed by a stop shoulder or a radial protrusion. The first and second horizontal contacts are offset by the axial distance to accommodate a force-determined bending moment such that system structural fatigue capacity is optimized. A lock mechanism assists with resisting axial loads without creating preload stresses and with locking the bodies together.

Coating compositions for coating an oilfield operational component, and related methods, may include in some aspects a coating composition having a trifunctional silane, a silanol, and a filler. The coating composition may be applied to a surface of the oilfield operational component that is configured to be exposed to a fluid. The coating composition may be applied to at least partially cover or coat the surface. The coating composition may be configured to chemically bond with a cured primer composition that includes an epoxy.

An arrangement is for providing a flowable solidifier into a subsea hydrocarbon well comprising a valve assembly with an opening to a well bore. The arrangement has a connection device comprising a well control unit with a lubricator device with a first through opening, an inlet connector with an inlet for the flowable solidifier to a second through opening. The arrangement further has an elongated injection tubing with a third through opening. The injection tubing is adapted to be displaced through the lubricator device to a certain position enabling the third through opening to receive the flowable solidifier from the inlet of the inlet connector and extending into the opening of the valve assembly so that one or more valves of the valve assembly are shielded from interaction with the flowable solidifier.

A modular hydraulic intensification system includes a housing configured to be deployed within a subsea landing string. The modular hydraulic intensification system also includes multiple hydraulic intensifiers positioned within the housing, wherein each hydraulic intensifier includes a first chamber configured to fluidly couple to a hydraulic fluid supply and a second chamber configured to fluidly couple to one or more landing string valves within a lower portion of the subsea landing string. The modular hydraulic intensification system further includes a shuttle valve fluidly coupled to the respective second chambers of the multiple hydraulic intensifiers, wherein the shuttle valve is configured to enable flow of an output fluid across the shuttle valve from the respective second chambers of the multiple hydraulic intensifiers and to block backflow of the output fluid across the shuttle valve toward the respective second chambers of the multiple of hydraulic intensifiers.

A safety valve for extraction wells, configured to be installed on a well head and to enclose a tubular material portion inserted inside the well. The tubular material is internally hollow to contain and transport substances extracted from the well. The safety valve includes: a central hole through which the tubular material passes; a blocking system configured to keep the tubular material to be cut fixed with respect to the safety valve; a cutting and closing group configured to cut and close the well under certain operative conditions; and a sealing mechanism configured to effect watertight closing of the well, after the cutting. The cutting and closing group includes a hole saw housed in a respective chamber of the cutting and closing group, rotated by a motorized actuator, and configured to move in a controlled mode along a substantially orthogonal direction with respect to a development direction of the well.