Abstract: An apparatus for supporting a flywheel on a floating vessel includes a support for the flywheel; and a tilt sensor for measuring an angle of slope relative to the Earth, the tilt sensor being arranged to detect a change of an angle of slope of the floating vessel relative to the Earth. The apparatus further includes a driver for manoeuvring the support relative to the floating vessel, based on the measured angle of slope from the tilt sensor, wherein the driver is operable to manoeuvre the support so as to counteract a change of an angle of slope of the flywheel relative to the Earth due to the detected change of an angle of slope of the floating vessel.

Abstract: Described is a method for concentration and extraction of gas field chemicals. The method includes collecting produced water from a gas oil separation plant, treating the produced water to remove oil, and receiving a feed solution containing a gas field chemical and water. The treated produced water is used as a draw solution to concentrate and absorb water from the feed solution using a forward osmosis chamber. A concentrated feed solution containing the gas field chemical and a diluted draw solution is produced. The concentrated feed solution is extracted and stored for injection into gas wells.

Abstract: A cage for a down-hole valve for a hydrocarbon well has no internal guides for directing a ball as it travels from a closed position in which the ball is disposed against a ball seat to an open position where the ball is urged against a ball stop structure. The cage has an internal conical profile which inhibits ball sticking, reduces ball lift acceleration, and allows for a full-open flow area through the cage.

Abstract: An apparatus for recovering a core from an undersea formation. A coring tool adapted for being connected to a drill string includes a coring bit for recovering the core from the undersea formation. A catcher has a closed state for sealing the core in the coring tool. A retainer retains the collapsible catcher in an open state, and an actuator applies suction to the coring tool. The applied suction serves to move the retainer to allow the catcher to collapse for capturing the core, such as by releasing flexible fingers of the core catcher from a telescoping liner associated with the retainer. Related methods are also disclosed.

Abstract: An expandable reel for a well system includes a support frame configured to receive a torque from a motor a plurality of circumferentially spaced spokes each extending radially away from a central axis of the expandable reel, a core assembly configured to couple to the support frame and receive a tubular of the well system about an outer surface of the core assembly, wherein the core assembly includes a plurality of circumferentially spaced panel assemblies each extending longitudinally between opposed ends thereof that are in sliding engagement with the plurality of spokes, and a linear actuator coupled between the support frame and the core assembly and configured to actuate the core assembly, including the plurality of panel assemblies, between a first configuration providing a first outer diameter and a second configuration providing a second outer diameter that is different from the first outer diameter.

Abstract: A solution for injection to a formation containing hydrocarbons includes an ionic liquid and a brine having a salinity of at least 60,000 ppm total dissolved solids (TDS). The ionic liquid is configured to lower an interfacial tension between the solution and the hydrocarbons in the formation.

Abstract: A wellbore system includes a slip hanger arranged within a wellbore component, the slip hanger having a mechanical receptacle formed in a face of the slip hanger. The wellbore system also includes an adapter configured to couple to the slip hanger, the adapter having one or more engagement members arranged to engage the mechanical receptacle, wherein the one or more engagement members extend into the mechanical receptacle to secure the slip hanger to the adapter.

Abstract: An ingress-barrier assembly for use with pressure-operated downhole equipment can be used to limit hydraulic fluid flow in a wellbore environment for completions and operations through the life of a well. An assembly can comprise a first port to communicate hydraulic fluid with a first fluid conveyance line. The assembly can include a second port to communicate hydraulic fluid with a second fluid conveyance line. The assembly can further include a first-end stop, a second-end stop, and a moveable seal. The moveable seal can move within a bore of the assembly between the first-end stop and the second-end stop to communicate pressure between the first port and the second port.

Abstract: One illustrative production/annulus bore stab disclosed herein includes a one-piece body that comprises a first cylindrical outer surface and a second cylindrical outer surface and a plurality of individual fluid flow paths defined entirely within the one-piece body. In this illustrative example, each of the individual fluid flow paths is fluidly isolated from one another and each of the fluid flow paths comprise a first inlet/outlet at a first end of the fluid flow path that is positioned in the first cylindrical outer surface and a second inlet/outlet at a second end of the fluid flow path that is positioned in the second cylindrical outer surface.

Abstract: An installation for storing, metering, and dissolving water-soluble polymer particles, in particular for enhanced oil and/or gas recovery operations, includes a so-called “polymer dissolution” container A and at least one so-called “polymer storage and distribution” container B positioned upon container A. The bottom of container B and the roof of container A each have an opening facing one another allowing the passage of the polymer from container B into the supply mechanism of container A. The installation further includes a connection mechanism able to work with the polymer supply mechanism.

Abstract: A drilling and production system is provided. In one embodiment, such a system has a plurality of functions that are effectuated at least predominately without hydraulic fluid. The system can be a drilling system having a rig and a subsea stack for performing various drilling functions, in which a majority of the drilling functions are effected electrically without hydraulic control fluid. In another embodiment, the rig is coupled to a subsea wellhead assembly but is not connected so as to provide hydraulic control fluid from the rig to the subsea wellhead assembly to enable drilling functions of the subsea wellhead assembly. Additional systems, devices, and methods are also disclosed.

Abstract: An offshore vessel for performing offshore subsea wellbore related activities, for example for drilling a subsea wellbore includes a drilling tower. A method for drilling a subsea wellbore includes using an offshore vessel and a method for tripping a tubulars string is disclosed. The offshore vessel is provided with a hoisting system which has a first configuration, wherein a hoisting cable is connected to a working deck and a second configuration wherein said hoisting cable is connected to a traveling block. The system allows for efficient tripping in and tripping out.

Abstract: Aspects of the present disclosure relate to valve skid apparatus and related methods for wellhead systems. A check block of the check valve includes a check side face that interfaces with a gate side face of a gate block of the gate valve. A pump side block is coupled to the gate valve, and a well side block is coupled to the check valve. A first pressure relief valve is coupled to a top face of the pump side block, and a first bleed-off valve is coupled to a top face of the first pressure relief valve. A second pressure relief valve is coupled to a top face of the well side block, and a second bleed-off valve is coupled to a top face of the second pressure relief valve.

Abstract: A method of operating a subsea production system (1), the system comprising a subsea tree (2) connected to a subsea well (3), a production tubing (4) in the well (3), and an electrically operable electric downhole safety valve (5), wherein the method comprises, in case of malfunction in operation of the electric downhole safety valve (5), the steps of installing a hydraulically operable insert hydraulic downhole safety valve (6) within the production tubing (4); connecting the insert hydraulic downhole safety valve (6) to the fluid line (10) at a point of setting (7) in the subsea well (3); operating the insert hydraulic downhole safety valve (6) by using the fluid line (10) which extends from an input port (11) at a position outside of the subsea tree (2).

Abstract: A valve assembly for connection to an opening provided in a housing of a well tool device includes a fluid communication channel, a flapper valve device, a flapper element supporting device, and a securing device. The fluid communication channel provides fluid communication from an outside of the housing to a bore provided on the inside of the housing. The flapper valve device includes a flapper element configured to be in a closed position in which the fluid communication channel is closed and an open position in which the fluid communication channel is open. The flapper element is biased to the closed position. The flapper element supporting device supports the flapper element when the flapper element is in the open position. The securing device secures the flapper valve device and the flapper element supporting device to the opening. The securing device includes a through bore forming a first part of the fluid communication channel.

Abstract: Methods and system involving well control. In some embodiments, the system includes an injection spool coupled to a subsea wellhead including an inlet, a manifold in fluid communication with the inlet of the injection spool for mixing one or more components of a well control treatment composition, a first container for storing natural gas in fluid communication with the manifold, and a second container for storing nitrogen in fluid communication with the manifold.

Abstract: A wellbore chemical injection assembly includes an extension flange including two ends and defining a flange bore. The first end can be fluidically coupled to a tubing spool inlet of a wellhead installed at a wellbore surface. The second end can be fluidically coupled to a chemical reservoir from which chemical is injected through the flange bore into the tubing spool. The assembly includes a mandrel positioned within the extension flange. A portion of the mandrel resides within the flange bore, while a remainder extends out. The mandrel defines an interior opening spanning an axial length of the mandrel. Outer coupling threads formed on the mandrel can removably mate with counterpart threads in the tubing spool inlet. Inner coupling threads formed on an inner surface of a portion of the interior opening can removably mate with coupling threads on a valve assembly removably seated in the interior opening.

Abstract: In one instance, a method of completing a well includes providing a drilling-uncompleted adapter having a first side on an upper portion and a second side on a lower portion and attaching the second side of the drilling-uncompleted adapter onto a casing head of a well. The method further includes attaching at least one fracturing valve to the first side of the drilling-uncompleted adapter and fracturing the well. The method also includes removing the drilling-uncompleted adapter after fracturing and attaching tubing head to the casing head for production. The tubing head does not endure the fracturing.

Abstract: What is provided is a method and apparatus which can be detachably connected to an annular blowout preventer thereby separating the drilling fluid or mud into upper and lower sections and allowing the fluid to be displaced in two stages, such as while the drill string is being rotated and/or reciprocated. In one embodiment the sleeve can be rotatably and sealably connected to a mandrel. The swivel can be incorporated into a drill or well string and enabling string sections both above and below the sleeve to be rotated in relation to the sleeve. In one embodiment the drill or well string does not move in a longitudinal direction relative to the swivel. In one embodiment, the drill or well string does move longitudinally relative to the sleeve of the swivel.

Abstract: The protection device has a valve and a valve actuator, able to move the valve to a closed position when a pressure upstream of the valve exceeds a predetermined threshold pressure. The valve actuator includes a biaser, to maintain the valve in an open position; an actuation mechanism, to move the valve to the closed position, the actuation mechanism with a fluid sampling passage to fluidly connect the flow line to a fluid actuated surface of the actuation mechanism. At least a rupture element preventing the passage of fluid from the flow line when the pressure upstream of the rupture element is lower than the threshold pressure, the rupture element being able to break at the threshold pressure.