Abstract: A method of cleaning deposited solid material from a fouled portion of a gas compressor (6) whilst the gas compressor (6) is in situ in a natural gas processing system (1) is provided. The method comprises the steps of supplying a liquid cleaning agent to a gas inlet of the gas compressor (6), the liquid cleaning agent being capable of removing the deposited solid material; passing the liquid cleaning agent through the gas compressor (6) to a gas outlet of the gas compressor (6), wherein at least a portion of the cleaning agent remains in a liquid state as it passes through the fouled portion of the gas compressor (6); and recovering a fluid containing removed material that is output from the gas compressor (6) so as to prevent the removed material reaching one or more gas processing stages of the gas processing system (1) downstream of the gas compressor (6).

Abstract: A subsea separator vessels includes single machined blocks integrated into a hull so as to combine all the valves used in the process of separating the multiphase fluid in the interior of the blocks. The separator vessels have by-pass valves in their blocks, if necessary to interrupt the separation process. The blocks function as a structure for the separating vessels, thereby replacing all of the metal structure necessary to support the tubes and valves of a conventional manifold, thus reducing the total area occupied by the separation station in the seabed.

Abstract: A subsea well installation is provided, comprising a first pipeline comprising a first valve arrangement and a second pipeline comprising a second valve arrangement. The first valve arrangement is connected to a first subsea well and the second valve arrangement is connected to a second subsea well. The first valve arrangement is connected to the second valve arrangement. The installation is arranged such that fluid can be routed from the first well to any of the first pipeline and second pipeline. Each valve arrangement may comprise three two-way ball valves. Also provided is a method of installing the subsea well installation and a method of operating the subsea well installation.

Abstract: Pumping of wellbore fluid to a surface may have a detrimental effect on the pump performance due to high gas concentrations in the fluid. A pump system that utilizes a helix gas separator provides greater pump efficiency by effectively removing the gas phase of the fluid. The wellbore fluid received at a pump system is directed from an intake to a gas separator that utilizes a stationary auger. The stationary auger induces rotational motion of the wellbore fluid causing the wellbore fluid to separate into a gas phase and a liquid phase. The gas phase is directed to the annulus while the liquid phase is directed to the pump for pumping to the surface. As the stationary auger remains stationary during production or separation of the wellbore fluid into a plurality of phase, fewer moving components are required which decreases overall production time while decreasing maintenance or operational costs.

Abstract: A gas-lift well includes a casing extending down a wellbore, production tubing extending within the casing, a gas system for inserting compressed gas into an annular space between the casing and the production tubing, at least one gas-lift input, and at least one fluid flow regime modifier. The at least one gas-lift input extends from the annular space, through the production tubing, and to an interior of the production tubing. The at least one fluid flow regime modifier is disposed within the production tubing and is at least partially within a fluid column of the production tubing, the at least one fluid flow regime modifier is configured to reduce fluid fallback and impart a turbulent flow regime to at least a portion of the fluid column.

Abstract: A method for testing properties of a pressurized multiphase fluid sample containing at least hydrocarbons and water. The pressurized multiphase fluid sample is placed into a first pressurized chamber of a testing device. The water is separated from the hydrocarbons. At least part of the separated water is flowed through a first outlet in the first pressurized chamber and into a second pressurized chamber. The second pressurized chamber is optionally isolated from the first pressurized chamber. A pH level of the separated water is tested in the second pressurized chamber. Microbial activity and growth is tested for in the pressurized multiphase fluid in the first pressurized chamber. A pressure of the pressurized multiphase fluid is substantially maintained throughout the placing, separating, flowing, isolating, and testing steps.

Abstract: A water injection flow control device includes a stack of discs or cone-like plates that form spiral-shaped flow conduits. The spiral-shaped flow conduits form at least one revolution about a central point or axis and depart or approach the central point or axis for each revolution. At least some of the spiral-shaped flow conduits have sections in series with alternating cross sectional area for flow and at least some have sections with a serpentine-type shape for flow along the spiral-shaped flow conduits. The spiral-shaped flow conduits have an inlet coupled to an inner or outer end of the spiral shaped flow conduits, an outlet coupled to the other end of the spiral-shaped conduits, and a control member.

Abstract: A gas flow velocity within a horizontal wellbore section is increased by a velocity string and a downhole-type compressor. A pressure within the horizontal wellbore section is decreased by a downhole-type compressor located within a vertical wellbore section fluidically connected to the horizontal wellbore section. Liquid build-up within the horizontal wellbore section is decreased in response to the increased gas flow velocity and the decreased pressure.

Abstract: A separating system (1) includes a riser (3) for receiving fluid from a multi-phase pipe (2) and for delivering gas to a subsea gas pipeline (8) through a gas delivering pipe (9). A liquid receiving pipe (12) has a lower end (14) with a liquid intake (15) being adapted to receive liquid from a liquid column (6) in the riser. A liquid delivering pipe (16) has an upper end (17) adapted to receive liquid from an upper end (13) of the liquid receiving pipe (12) and a lower end (18) adapted to deliver liquid to a subsea liquid pipeline (19). A level control system (22) controls the level of the surface of the liquid column by regulation of the liquid flow rate to the liquid pipeline. The riser encloses the liquid receiving pipe, the liquid delivering pipe and the gas delivering pipe. A method for separating is furthermore disclosed.

Abstract: A motor-compressor unit for sub-sea applications, including a pressure casing, and an electric motor housed in a motor compartment formed in the pressure casing and a compressor housed in a compressor compartment formed in the pressure casing. A shaft drivingly connects the electric motor and the compressor. At least one magnetic bearing rotatingly supports the shaft and a control system is provided for controlling the magnetic bearing. The control system is housed in a control system compartment structurally connected to and supported by the pressure casing.

Abstract: A device for use in recovery of gas trapped by fluid and suspended solids in a gas or oil well includes a body defining a cavity with a cap at its upper end and an opening for entry of fluid at its bottom end. A lower valve controls fluid flow into, and an upper valve controls flow out of, the cavity. Pressurized gas pushes downward on fluid in the cavity in a compression stroke which closes the lower valve and opens the upper valve. Gas is exhausted from the cavity during an exhaust stroke. An effluent line allows exit of the fluid and suspended solids during the compression stroke. A probe line provides electrical power to a pair of probes for initiating and halting entry of the stream of pressurized gas into the cavity.

Abstract: A subsea oil and/or gas production system comprises a host production facility and a plurality of subsea wells. A fluid conveying network is provided that connects each subsea well to the host production facility. A separate electrical power and data network is provided for conveying direct current electrical power and data, operatively connected to each subsea well for providing each subsea well with data transfer and electrical power services. The use of direct current ensures that the electrical power and data network can provide power over much greater distances than currently available, and the use of separate networks for conveying fluids and for providing electrical power and data transfer allows for a much more flexible system.

Abstract: A method for drilling a subsea well from a rig through a subsea wellhead below the rig includes employing a single gradient or dual gradient drilling system that includes a drill string that extends from the rig into the well and surface mud pumps for pumping drilling fluid through the drill string and into a well annulus of the well. The drilling system includes a subsea rotating device for conducting the drilling fluid from the well annulus and through a solids processing unit. A subsea pump then conducts the drilling fluid from the solids processing unit to a return line back to the rig. The surface mud pump and subsea pump are staged in coordination to trap pressure and/or remove pressure in the well annulus to maintain a selected pressure gradient in the well annulus.

Abstract: A subsea oil and/or gas production system comprises a host production facility and a plurality of subsea wells. A fluid conveying network is provided that connects each subsea well to the host production facility. A separate electrical power and data network is provided for conveying direct current electrical power and data, operatively connected to each subsea well for providing each subsea well with data transfer and electrical power services. The use of direct current ensures that the electrical power and data network can provide power over much greater distances than currently available, and the use of separate networks for conveying fluids and for providing electrical power and data transfer allows for a much more flexible system.

Abstract: A system and method are disclosed for containing an underwater gas or oil leak. The system and method may include a vortex device comprising a vortex chamber, a high pressure inlet tangentially engaging the vortex chamber, a low pressure inlet axially engaging the vortex chamber, and a low pressure outlet axially engaging the vortex chamber opposite the low pressure inlet. The vortex device may be positioned underwater proximate an underwater leak. A vortex may be generated within the vortex device. The vortex device may then collect a leak flow issuing from the underwater leak. The vortex device may collect the leak flow via the low pressure inlet, the high pressure inlet, or both.

Abstract: A slug mitigation system for subsea pipelines includes a riser located between a low level and an upper (above sea-) level of a pipeline, where an inline separator, e.g. an “I-SEP”, is located upstream of a first stage separator. A throttling valve or fixed restriction is located downstream or upstream in series with the inline separator. Further aspects may also include a surface jet pump upstream of the in-line separator and/or a cyclonic separator downstream of the in-line separator.

Abstract: The invention relates to a wet gas compression system comprising a compact flow conditioner (21), intended to be placed below sea level in close vicinity to a well head or on a dry installation, said flow conditioner (21) being intended to receive a multi-phase flow through a supply pipe (11) from a sub sea well for further transport of such hydrocarbons to a multi-phase receiving plant, and where preferably avoid sand accumulation or remove as much sand as possible from the multi-phase flow, the gas (G) and the liquid (L) being separated in the flow conditioner (21) whereupon the separated gas (G) and liquid (L) are re-assembled and enters a multi-phase meter (46) prior to boosting by means of a compressor (22). In the combined multi-phase pump and compressor unit (22), as an integrated unit, comprises a combined multi-phase pump and compressor unit (22) functioning on the centrifugal principle, used for trans-porting liquid and gas from a flow conditioner (21) to a remote multi-phase receiving plant.

Abstract: Embodiments of the present invention generally relate to methods and apparatus for centrifugal separation. In one embodiment, a separator includes an outer tubular having ends sealed from the environment and an inner tubular. The inner tubular is disposed within the outer tubular, has ends in fluid communication with a bore of the outer tubular, and is attached to the outer tubular. The separator further includes an inlet. The inlet is disposed through a wall of the outer tubular, in fluid communication with a bore of the inner tubular, and tangentially attached to the inner tubular so that fluid flow from the inlet to the inner tubular is centrifugally accelerated. The separator further includes a gas outlet in fluid communication with the outer tubular bore; and a liquid outlet in fluid communication with the outer tubular bore.

Abstract: A fluid treatment system comprises a fluid treatment module having a fluid inlet and first and second fluid outlets. A pump is provided to establish a first pressure differential between the fluid inlet and one of the first and second fluid outlets of the fluid treatment module, and an eductor is provided to establish a second pressure differential between the fluid inlet and the other of the first and second fluid outlets of the fluid treatment module. The pump is adapted to deliver a motive fluid to the eductor.

Abstract: A subsea system and an oil/gas outlet arrangement for splitting of oil and gas. The subsea system comprising a separator (1), the separator (1) comprising; at least one well flow inlet (13) for a multiphase flow mixture of at least oil and gas, an oil/gas outlet arrangement (15) arranged in a distance from the well flow inlet (13) over which distance the multiphase flow mixture separates in at least an oil phase (O) and a gas phase (G), the oil/gas outlet arrangement (15) comprising; at least one conical crown device (2), the conical crown device (2) having an outer wall with at least one cutout (4) extending through said outer wall, through which cutouts (4) the oil and gas flow into the crown device (2), each crown device (2) is in fluid connection with at least one fluid outlet (5, 6), and wherein the oil/gas outlet arrangement (15) comprises at least two fluid outlets (5, 6).

Abstract: A subsea production system, comprising a plurality of wells located on a sea floor, the wells producing a fluid comprising hydrocarbons; a cold flow center on the sea floor, the cold flow center fluidly connected to the plurality of wells; and a production facility on land or on a floating structure, the production facility fluidly connected to the cold flow center; wherein the cold flow center lowers a temperature of the fluid and produces a slurry of the fluid and suspended solids for transportation to the production facility.

Abstract: A method of producing oil and gas from a gathering manifold or a well. The method includes the steps of channeling field production into a sealed vessel through an inlet pipe, and permitting oil and gas components of the field production to separate naturally from water and other fluids within the vessel. The method further includes the steps of evacuating the separated oil and gas from the vessel via pipelines attached to the vessel at locations corresponding to the separated oil and gas, and pumping seawater into the vessel to pressurize the vessel and thereby aid in the production of oil and gas from the vessel.

Abstract: Systems and methods include using a subsea machine for separating a mixture received from a seabed well. The subsea machine includes: a chamber configured to receive and separate by gravity the mixture received from the seabed well. The chamber includes: a housing configured to contain the mixture received from the undersea well during separation, and a piston provided inside the housing and separating the housing into a top section and a bottom section. The piston is configured to move in a first direction along an axis to create more space in the top section for receiving the mixture from the seabed well and to move in a second opposite direction along the axis for removing the mixture from the chamber after separation has occurred.

Abstract: A method of operating a system for handling an influx of gas into a marine riser during the drilling of a well bore includes the steps of operating a first riser closure apparatus to close the riser at a first point above a flow spool provided in the riser, there being a riser gas handling line extending from the riser at the flow spool to a riser gas handling manifold, operating a second riser closure apparatus to close the riser at a second point below the flow spool, pumping fluid into an inlet line which extends into the riser at a point above the second point but below the flow spool, and operating a choke provided in the riser gas handling manifold to maintain the pressure in the inlet line or the riser at a substantially constant pressure.

Abstract: A method of drilling and producing from an offshore structure, comprising drilling a first well from the offshore structure with a drilling riser; completing the first well with a first subsurface tree; connecting the first subsurface tree to a manifold; drilling a second well from the offshore structure with a drilling riser; completing the second well with a second subsurface tree; connecting the second subsurface tree to the manifold; and connecting a production riser to the manifold and the offshore structure.

Abstract: A system and method are disclosed for containing an underwater gas or oil leak. The system and method may include a vortex device comprising a vortex chamber, a high pressure inlet tangentially engaging the vortex chamber, a low pressure inlet axially engaging the vortex chamber, and a low pressure outlet axially engaging the vortex chamber opposite the low pressure inlet. The vortex device may be positioned underwater proximate an underwater leak. A vortex may be generated within the vortex device. The vortex device may then collect a leak flow issuing from the underwater leak. In certain embodiments, the vortex device may collect the leak flow via the low pressure inlet. In other embodiments, the vortex device may collect the leak from via the high pressure inlet.

Abstract: A subsea production and separation system comprising a subsea well drilled into a sea floor; a subsea tree located on the sea floor at a top portion of the subsea well; a manifold located on the sea floor; a well jumper connecting the subsea tree and the manifold; a first sled located on the sea floor; a second sled located on the sea floor; a separator located on the sea floor; a first flowline jumper connecting the manifold to the separator; a second flowline jumper connecting the manifold to the separator; a third flowline jumper connecting the separator to the first sled; a fourth flowline jumper connecting the separator to the second sled; a liquid export line connected to the third flowline jumper; and a gas export line connected to the fourth flowline jumper.

Abstract: An apparatus, method, and system for recovering oil from a submerged oil source, wherein the system includes a submerged conduit having at least two openings, with a first opening capable of being located in proximity of a leak in order to capture leaking oil, and with a second opening capable of communicating captured leaking oil to another location. A natural gas separator, coupled to the submerged conduit separates the boiling vapor phase natural gas from the captured oil thereby outputting oil with water contaminant. An oil/water separator coupled to the natural gas separator then separates out the contaminant water, resulting in a processed recovered oil product for storage and subsequent refinement. The flow to capture the leak is induced by generating a lower pressure at nozzle in the conduit via power jet, air lift, pumping of fluid out of conduit close to sea level, or other methods.

Abstract: An apparatus, system and method is disclosed for processing geological solids or wellbore cuttings generated by excavation or drilling under a body of water. An apparatus for processing solids in association with a riser may employ a solids processing apparatus having a central cavity that is substantially free of mechanical obstructions. The central cavity may be positioned in-line with the riser. The apparatus may be adapted for receiving solids within the central cavity and reducing the particle size of the solids by action of a cutter assembly which is positioned outside of the central cavity. The cut and processed solids may be pumped to the surface of the water.

Abstract: A method and apparatus for removing metallic material from a circulating well fluid stream provides a treatment vessel that is divided into first and second sections. Each of the sections includes a magnetic field that can be in the form of one or more magnets. In one embodiment, multiple magnets are provided in each of the sections. Manifolds attach to an influent and to an effluent of the treatment vessel. Each manifold enables selective transfer of fluid to either of the selected sections. Similarly, discharge of circulating fluid can be from either of the sections via a discharge manifold. The treatment vessel enables continuous treatment by valving fluid flow so that only one section need be used at a time in order that the other section could be serviced for removing collected metallic material from the magnetic field or from the magnets.

Abstract: A method of separating a multiphase fluid, the fluid including a relatively high density component and a relatively low density component, that includes introducing the fluid into a separation region; imparting a rotational movement into the multiphase fluid; forming an outer annular region of rotating fluid of predetermined thickness within the separation region; and forming and maintaining a core of fluid in an inner region. Fluid entering the separation vessel is directed into the outer annular region and the thickness of the outer annular region is such that the high density component is concentrated and substantially contained within this region, the low density component being concentrated in the rotating core. A separation system employing the method is also provided. The method and system are particularly suitable for the separation of solid debris from the fluids produced by a subterranean oil or gas well at wellhead flow pressure.

Abstract: The present invention regards a subsea cooling unit having an inlet for a hot fluid and an outlet for cooled fluid, the cooling unit comprising a number of coils exposed to seawater, and means for generating a flow of seawater past the coils, where the means for generating the flow of seawater comprises a propeller and a rotatable actuator and that the cooler is enclosed in a duct.

Abstract: According to an embodiment, a method of limiting the amount of oil in a sea comprises: positioning a device for directing the flow of a fluid adjacent to a wellhead, wherein the device comprises: a first fluid passageway; a second fluid passageway; a third fluid passageway, wherein the first fluid passageway is operatively connected to the second and third fluid passageways; and a fluid director, wherein the fluid director is operatively connected to the first, second, and third fluid passageways, and wherein depending on at least one of the properties of a fluid, the fluid director directs the fluid to increasingly flow into the second or third fluid passageways. This embodiment is useful in limiting the amount of oil when a blowout has occurred.

Abstract: Methods and apparatus for diverting fluids either into or from a well are described. Some embodiments include a diverter conduit that is located in a bore of a tree. The invention relates especially but not exclusively to a diverter assembly connected to a wing branch of a tree. Some embodiments allow diversion of fluids out of a tree to a subsea processing apparatus followed by the return of at least some of these fluids to the tree for recovery. Alternative embodiments provide only one flowpath and do not include the return of any fluids to the tree. Some embodiments can be retro-fitted to existing trees, which can allow the performance of a new function without having to replacing the tree. Multiple diverter assembly embodiments are also described.

Abstract: This invention relates to equipment and a subsea pumping system using a subsea module installed on the sea bed, preferably away from a production well and intended to pump hydrocarbons having a high associated gas fraction produced by one or more subsea production wells to the surface. One object of this invention is achieved by means of the design of a pumping module (PM) which is linked to pumping equipment already present in a production well and which basically comprises: an inlet pipe (2), separator equipment (3), a first pump (4) and a second pump (8). In the subsea pumping system for the production of hydrocarbons with a high gas fraction, the other object of this invention, when oil is pumped from the production well (P) the well pump (13) increases the energy of the fluid in the form of pressure and transmits this increase in energy in the form of an increase in suction pressure in the second pump (8) of the subsea module (PM).

Abstract: A system for offshore disposal of drill cuttings including a cleaning system for treating contaminated drill cuttings into drill cuttings and contaminants; a transport system for moving the drill cuttings; a slurrification system for making a slurry of the treated drill cuttings; and a cuttings re-injection system for injecting the slurry into a well.

Abstract: A large diameter subsea gravity separator for ultra deep water conditions of 2000 to more than 4000 m includes a vessel having a shell which defines a cylindrical tubular portion and closure portions at axially both ends of the tubular portion. The shell is a sandwich shell which is dimensioned to provide for a predetermined collapse resistance of at least MPa and includes an inner steel layer, an outer steel layer and a concrete layer completely filling the space between the inner steel layer and the outer steel layer.

Abstract: A method and systems are provided for injecting a hydrate slurry into a reservoir. The method includes combining gas and water within a subsea simultaneous water and gas (SWAG) injection system. The method also includes forming a hydrate slurry from the gas and the water, and injecting the hydrate slurry into a reservoir.

Abstract: Apparatus and method for processing a process fluid at a remote location, with the apparatus including a pump located at a first location and configured to provide a pressurized working fluid. The apparatus also includes an umbilical coupled to the pump such that the umbilical receives the pressurized working fluid from the pump and transports the pressurized working fluid therefrom. The apparatus further includes a hydraulic turbine disposed at the remote location and coupled to the umbilical such that the hydraulic turbine receives the pressurized working fluid from the umbilical. The apparatus additionally includes one or more shaft energy conversion devices operatively coupled to the hydraulic turbine and disposed at the remote location.

Abstract: A two phase gas-liquid separation apparatus is provided that shapes the flow in a flow shaping line. Shaping the two-phase flow allows centrifugal force to send the heavier, denser liquid to the outside wall of the flow shaping line and allows the lighter, less dense vapor or gas to occupy the inner wall of the flow shaping line. With the gas positioned on the inner wall of the flow shaping line, an exit port on the inner wall will allow for the majority, if not all, of the gas, along with a low amount of liquid, to be sent to a conventional separator. A high ratio of vapor/liquid at a flow rate much lower than the total flow rate within the flow shaping line is sent to the conventional separator. This allows for efficient separation of the vapor from the liquid with the use of a smaller conventional separator.

Abstract: Disclosed is a tubing system for transporting a gas-liquid flow from a well to a production platform or processing facility. It includes a dual pathway section between the well and the production point having a first tubing portion and a second tubing portion. The second tubing portion includes a plurality of parallel channels so as to divide the multi-phase flow into a plurality of flows through individual channels. This is done to reduce flow slippage of the lower viscosity portion of the flow, which may lead to inefficiencies in flow characteristics, and often, undesirable cyclical variations in pressure and fluid volume. This is especially useful in inclined portions of the petroleum flow pipe system and along hilly terrain. The first round tubing portion is used for transporting the gas-liquid flow as well as for maintenance purposes, such as for pigging, fishing or coiled tubing operations.

Abstract: The present invention relates to a collecting device (1) for solids material which is moved by means of a fluid from a first location on a seabed, on an offshore installation or on land to a second location, the fluid carrying the solids material in through an inlet portion (7) of the collecting device (1), the collecting device (1) being provided with one or more permeable portions arranged to retain the solids material exceeding a predetermined size. The invention also relates to a method of using the collecting device (1), the method including the abandoning of a filled collecting device (1).

Abstract: A subsea pumping system using a subsea module is installed on the sea bed, preferably away from production wells and intended to pump hydrocarbons having a high associated gas fraction produced by subsea production wells to the surface. The system achieves an advantage by the design of a pumping module (PM) which is linked to pumping equipment already present in a production well and which includes: an inlet pipe (2), separator equipment (3), a first pump (4) and a second pump (8). Another advantage of the subsea pumping system for the production of hydrocarbons with a high gas fraction is that, when oil is pumped from the production well (P), the well pump (13) increases the energy of the fluid in the form of pressure and transmits this increase in energy in the form of an increase in suction pressure in the second pump (8) of the subsea module (PM).

Abstract: The present invention relates to equipment for the conveying and recovery of hydrocarbons from an underwater well for the extraction of hydrocarbons under uncontrolled release conditions, comprising a chamber (23) for the separation of the hydrocarbon stream leaving the well, into a heavy phase (23a) and a light phase (23b), means (15,16,17,24,25,26) being envisaged, in connection with the separation chamber (23), for conveying the heavy phase (23a) and light phase (23b) towards the surface, characterized in that it comprises a directioning body (18) of the hydrocarbon stream, having a substantially cylindrical shape, or as a truncated paraboloid with both ends open, wherein a first end is an inlet of the hydrocarbon stream leaving the well, and a second end, distal with respect to the inlet of the hydrocarbon stream (20), is in fluid connection with the separation chamber (23) with the interpositioning of a perforated spherical cap (22).

Abstract: Method, riser assembly and gas handler for diverting gas from a riser, The riser assembly includes a riser having a first end and a second end and a conduit extending from the first end to the second end; a gas handler connected to the riser and provided between the first end and the second end, the gas handler having an external casing; plural pipes attached to an outside of the riser such that at least one pipe of the plural pipes enters through the external casing; and a gas vent pipe configured to start at the gas handler and extend towards the second end of the riser and the gas vent pipe is further configured to divert a gas from the gas handler through the outside of the riser.

Abstract: A method and device for recovering drilling fluid used in connection with the provision of a subsea well, in which the drilling fluid is circulated from a vessel on a sea surface via a drill string and out through a drill bit into an annulus which is defined by a borehole and the drill string. The device includes a filtering device which is connected, in respect of fluid, to an annulus and which is arranged to contain drill cuttings and drilling fluid. A fluid line extends from a portion of the filtering device to the vessel, the fluid line being arranged to carry drilling fluid which has been separated from the drill cuttings back to the vessel.

Abstract: Systems and methods for the recovery of iodine are described. In particular, recovery systems and methods produce an iodine complex from an aqueous brine containing iodide. A head tank for maintains a supply of the brine, a pH controller acidifies brine received from the head tank and an oxidizer converts iodide in the acidified brine to elemental iodine. At least one activated carbon contactor module is removably inserted into a stream of the oxidized brine provided by the oxidizer and binds the molecular iodine to form the iodine complex. A container may enclose the head tank, the pH controller and the oxidizer in order to facilitate transportation of the system and performance of the methods and processes in proximity to a brine source. The brine may be employed or associated with oilfield operations.

Abstract: A method for control of liquid or liquid slugs in multi phase fluid pipelines, including a multiphase pipeline for the transportation of a fluid, consisting of mainly gas and some liquid such as water an/or gas condensate. The gas is evacuated via a gas separation unit connected to the multiphase pipeline to a second gas transport pipe, and the liquid is fed to a dedicated pipeline section acting as a buffer volume pipeline. The separation unit includes one or several vertical pipes connected at a distance from one another along the multiphase pipeline, whereby the gas is transported separately to a downstream processing facility on a platform or onshore or the like, and whereby the liquid proceeds to the loop which may preferably be an extension of the multiphase pipeline, or the liquid and gas may be re-combined and led in a common transport pipeline to the desired destination.

Abstract: A system for remediating hydrates has a heat storage box with an interior volume, a heater for heating fluid flowing into the hot fluid inlet of the heat storage box, a heat exchanger positioned in the interior volume of the heat storage box so as to be in heat exchange relationship with heated water from the interior volume of the heat storage box, and a line connected to a heated water outlet of the heat exchanger so as to be manipulated toward a location of the hydrates for the purpose of delivering the heated water toward the hydrates. The heat exchanger is piping extends in a serpentine pattern within an upper portion of the heat storage box. The line can be connected to a hot stab suitable for a manipulation by an ROV.

Abstract: The present application is directed to a subsea separator. The subsea separator suitably comprises (a) a housing having an inlet for receiving a fluid mixture, a non-gaseous fluid outlet located along the housing at a point lower than the inlet, and a gas outlet located along the housing at a point higher than the inlet; (b) a deflector means located within the housing for acting on fluid entering the housing; and (c) a sealing means in communication with the gas outlet for preventing non-gaseous fluid from exiting the housing through the gas outlet, the sealing means being operationally configured to open and seal the gas outlet based on the volume of non-gaseous fluid within the separator; wherein the separator is operationally configured to operate under a differential pressure including a greater external hydrostatic pressure than internal pressure and vice versa.