WO2005005012A1 - Separateur - Google Patents

Separateur Download PDF

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Publication number
WO2005005012A1
WO2005005012A1 PCT/GB2004/002874 GB2004002874W WO2005005012A1 WO 2005005012 A1 WO2005005012 A1 WO 2005005012A1 GB 2004002874 W GB2004002874 W GB 2004002874W WO 2005005012 A1 WO2005005012 A1 WO 2005005012A1
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WO
WIPO (PCT)
Prior art keywords
vessel
separator
outlet
fluid
solids
Prior art date
Application number
PCT/GB2004/002874
Other languages
English (en)
Inventor
David Parkinson
Original Assignee
Kcc Group Limited
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Kcc Group Limited filed Critical Kcc Group Limited
Publication of WO2005005012A1 publication Critical patent/WO2005005012A1/fr

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Classifications

    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D21/00—Separation of suspended solid particles from liquids by sedimentation
    • B01D21/26—Separation of sediment aided by centrifugal force or centripetal force
    • B01D21/267—Separation of sediment aided by centrifugal force or centripetal force by using a cyclone
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/34—Arrangements for separating materials produced by the well
    • E21B43/35—Arrangements for separating materials produced by the well specially adapted for separating solids
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B04—CENTRIFUGAL APPARATUS OR MACHINES FOR CARRYING-OUT PHYSICAL OR CHEMICAL PROCESSES
    • B04C—APPARATUS USING FREE VORTEX FLOW, e.g. CYCLONES
    • B04C5/00—Apparatus in which the axial direction of the vortex is reversed
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D17/00—Separation of liquids, not provided for elsewhere, e.g. by thermal diffusion
    • B01D17/02—Separation of non-miscible liquids
    • B01D17/0217—Separation of non-miscible liquids by centrifugal force
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D17/00—Separation of liquids, not provided for elsewhere, e.g. by thermal diffusion
    • B01D17/12—Auxiliary equipment particularly adapted for use with liquid-separating apparatus, e.g. control circuits
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D21/00—Separation of suspended solid particles from liquids by sedimentation
    • B01D21/10—Settling tanks with multiple outlets for the separated liquids
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D21/00—Separation of suspended solid particles from liquids by sedimentation
    • B01D21/24—Feed or discharge mechanisms for settling tanks
    • B01D21/2494—Feed or discharge mechanisms for settling tanks provided with means for the removal of gas, e.g. noxious gas, air
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D21/00—Separation of suspended solid particles from liquids by sedimentation
    • B01D21/26—Separation of sediment aided by centrifugal force or centripetal force
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B04—CENTRIFUGAL APPARATUS OR MACHINES FOR CARRYING-OUT PHYSICAL OR CHEMICAL PROCESSES
    • B04C—APPARATUS USING FREE VORTEX FLOW, e.g. CYCLONES
    • B04C5/00—Apparatus in which the axial direction of the vortex is reversed
    • B04C5/12—Construction of the overflow ducting, e.g. diffusing or spiral exits
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B04—CENTRIFUGAL APPARATUS OR MACHINES FOR CARRYING-OUT PHYSICAL OR CHEMICAL PROCESSES
    • B04C—APPARATUS USING FREE VORTEX FLOW, e.g. CYCLONES
    • B04C5/00—Apparatus in which the axial direction of the vortex is reversed
    • B04C5/14—Construction of the underflow ducting; Apex constructions; Discharge arrangements ; discharge through sidewall provided with a few slits or perforations
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B04—CENTRIFUGAL APPARATUS OR MACHINES FOR CARRYING-OUT PHYSICAL OR CHEMICAL PROCESSES
    • B04C—APPARATUS USING FREE VORTEX FLOW, e.g. CYCLONES
    • B04C5/00—Apparatus in which the axial direction of the vortex is reversed
    • B04C5/14—Construction of the underflow ducting; Apex constructions; Discharge arrangements ; discharge through sidewall provided with a few slits or perforations
    • B04C5/18—Construction of the underflow ducting; Apex constructions; Discharge arrangements ; discharge through sidewall provided with a few slits or perforations with auxiliary fluid assisting discharge
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B04—CENTRIFUGAL APPARATUS OR MACHINES FOR CARRYING-OUT PHYSICAL OR CHEMICAL PROCESSES
    • B04C—APPARATUS USING FREE VORTEX FLOW, e.g. CYCLONES
    • B04C9/00—Combinations with other devices, e.g. fans, expansion chambers, diffusors, water locks
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2221/00—Applications of separation devices
    • B01D2221/04—Separation devices for treating liquids from earth drilling, mining
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B04—CENTRIFUGAL APPARATUS OR MACHINES FOR CARRYING-OUT PHYSICAL OR CHEMICAL PROCESSES
    • B04C—APPARATUS USING FREE VORTEX FLOW, e.g. CYCLONES
    • B04C9/00—Combinations with other devices, e.g. fans, expansion chambers, diffusors, water locks
    • B04C2009/002—Combinations with other devices, e.g. fans, expansion chambers, diffusors, water locks with external filters

Definitions

  • This invention relates to a separator and particularly, although not exclusively, relates to an underwater separator for separating oil from borehole fluids.
  • the solids need to be free of oil to international standards prior to being released to the sea. Although this may be possible to achieve on the sea bed, the sub sea measurement of oil on solids is not currently available. Such measurement currently requires a "Retort"' system which evaporates the liquids attached or absorbed by the solids, condenses them and measures the oil fraction on a volume by volume basis.
  • sea water either alone or combined with produced water, injected into the producing reservoir.
  • sea water either alone or combined with produced water
  • seawater there will be a requirement for the removal of fine solids in both the produced water and seawater prior to injection.
  • Other issues such as scale formation precipitated by mixing of dissimilar waters, sulphate reducing bacteria and dissolved oxygen levels will also need addressing.
  • Fig (1) is a process schematic for one such system.
  • the separation efficiency of these separators is very dependant on the following factors: temperature - affects liquid viscosities and hence interfacial drag forces, typically the higher the temperature the better the separation in a shorter time; specific Gravity or density difference between oil and water, The lighter oils separate quicker; droplet size distribution of oil in water or water in oil, which affects rise or sink rates; and emulsion characteristics, if present.
  • An ideal separator to be used subsea for bulk water knock out would have the following abilities: • manage Gas; • remove equal to or more than 75% of the produced water at a quality equal to or better than 50 mg/1 free oil in water; • be controlled by water quality and differential pressure rather than level controls; • have less than 30 seconds retention time; • have the ability to remove solids on line; and • be small enough to be deployed by current work boats, drill ships and rigs.
  • a liquid/liquid hydrocyclone separator as shown in Fig. (3) , uses centrifugal force to accelerate separation by increasing apparent G forces.
  • Liquid-liquid hydrocyclones are capable of separating immiscible, insoluble liquid-liquid mixtures. Fluid normally enters the unit through a tangential or involute inlet. The flow is directed into a vortex without disrupting a reverse flowing core. As the flow is forced down a hydrocyclone liner, it takes up a helical form along the liner walls. It is accelerated in a conically reducing section, to the high velocities required to create the strong centrifugal forces that promote rapid separation. These velocities are maintained along the liner, frictional losses being offset by a gradual reduction in cross sectional area throughout the conical section.
  • the denser fluid moves to the walls of the hydrocyclone and is removed at the downstream fluid outlet (underflow) .
  • the less dense fluid is drawn into the low pressure core.
  • an oil rich stream flows back up the hydrocyclone, to be removed at the upstream outlet orifice (overflow) .
  • the vortex and reverse flowing core extend down into the tail -section of the hydrocyclone, increasing the residence time and allowing smaller, slower • separating droplets to migrate to the core.
  • the total residence time in the hydrocyclone is in the order of a few seconds.
  • the centrifugal force created in one such unit on the market available from US Filter® is of the order of 1000 G.
  • the hydrocyclone is insensitive to motion and orientation.
  • Dissolved gas break-out within conventional hydrocyclones has not proved to be a problem on any existing installations largely due to: - i) The pressure drop across the cyclone being a smooth gradient, no sudden changes in geometry existing to accelerate changes in condition; ii) Residence time in the unit (approximately one second) is insufficient to approach any equilibrium condition. Evolved gas is lower in actual volume than predicted - often as low as 20 % of prediction.
  • Process Control of the De-oiling hydrocyclones is achieved by reference to the ratio of the volumetric flow rates of the de-oiling hydrocyclone overflow (reject Oil: PR) to underflow (Water :PO) . This is governed by the ratio of the differential pressure from inlet to overflow to the differential pressure inlet to underflow, referred to as the Pressure Differential Ratio, or PDR.
  • PDR PI - PR PI - PO
  • the PDR may be maintained by a pressure differential control valve, (fail closed) in the oil outlet line, under the influence of a pressure differential ratio controller.
  • the PDRC can be adjusted to give a PDR of between 1.5 and 1.7.
  • the de-oiling hydrocyclones may be followed by a degassing vessel which may have further means to remove or skim remaining oil from the water.
  • a separator for separating out a flow into a first fluid, a second fluid which is more dense than the first fluid, and solids, the separator comprising: a vessel having an inlet for the flow; means for causing the flow to rotate within the vessel; a first outlet in the vessel for the first fluid, the first outlet comprising a passage, an inlet end of the passage being situated towards a central axis, of the vessel; a second outlet for the second fluid, the second outlet being situated towards a side wall of the vessel; and
  • the central axis of the vessel is substantially vertical .
  • the vessel is substantially symmetrical about its central axis.
  • the vessel is cylindrical.
  • the means for causing rotation comprises shaping or aligning the inlet so that inlet flow is directed away from the central axis of the vessel .
  • the vessel is operated at above atmospheric pressure, but it may alternatively be operated at below atmospheric pressure or may be open to the atmosphere.
  • a gas vent is provided in an upper part of the vessel.
  • the solids are stored in a lower part of the vessel for later removal. Removal of solids may be carried out continuously or in a batchwise process.
  • a fluidising unit is provided in a lower part of the vessel.
  • the fluidising unit is operated to fluidise settled solids and transport them out of the vessel.
  • the third outlet comprises a transport outlet of the fluidising unit.
  • the separator when the separator is used in a subsea application, the separated solids can be transported to the surface through a riser. If necessary, the separated solids may be raised to the surface in a separate small riser. This has the further advantage that the solids are not re-entrained back into the oil rich stream, from which they would have to be removed again.
  • the outlet does not re- entrain the solids.
  • it may be situated above the third outlet and may be shielded. It is also important to prevent the flow out of the second outlet leaving the vessel in such a way that it induces the vortex to break down or interferes with the swirling flow.
  • a core finder is fixed in the vessel above the fluidising unit.
  • a core finder captures and reflects a vortex core formed by the rotation of the mixed fluids .
  • the separator has a hold-up (or retention) time of 10 to 30 seconds.
  • the second outlet is provided in a lower part of the vessel .
  • the second outlet is situated in the side wall of the vessel.
  • the outlet passage has a mouth which opens into a part of the vessel at which the first fluid accumulates as it separates out.
  • an axis of the outlet passage is substantially vertical.
  • the axis of the outlet passage is aligned with the central axis of the vessel .
  • the outlet passage comprises a pipe.
  • the pipe extends into the vessel through a top part of the vessel, and preferably projects into the vessel.
  • the vessel is a fluid tight pressure vessel, which can be operated in a hostile environment, such as at the seabed.
  • the outlet passage is at a lower pressure than the vessel .
  • the first fluid comprises a hydrocarbon fluid, such as crude oil and the more dense fluid comprises water, such as produced water and entrained impurities and solids from a bore hole.
  • these solids may comprise sand and debris thrown to the outside of the separator and therefore leave the vessel with the . separated water. It is considered that such material is cleansed of oil to a degree by the vortex action in the separator and thus leaves in a relatively clean condition.
  • the separator inlet is therefore preferably made of stellite or other such hard faced material to minimise the erosion.
  • a separator for separating out a flow into a first fluid, a second fluid which is more dense than the first fluid, and solids, the separator comprising:
  • a vessel having an inlet for the flow; means for causing the flow to rotate in a vortex within the vessel; a first outlet in the vessel for the first fluid, the first outlet comprising a passage, an inlet end of the passage being situated towards a central axis of the vessel; a second outlet for the second fluid, the second outlet being situated towards a side wall of the vessel; a third outlet for the solids; and a core finder fixed in a lower part of the vessel, the core finder being adapted to capture and reflect the core of the vortex towards the inlet end of the passage.
  • a preferred embodiment of the present invention provides a separator acting subsea which amalgamates some of the features of normal three phase separators, de-oiling hydrocyclones and degassing/floatation vessels, at the lowest operable pressure drop.
  • the unit can be controlled by pressure differentials and not levels, with an override provision based on water quality measurement.
  • the present invention provides a reliable method of removing, on the sea bed, at least 75% of the produced water. It also provides management of solids, so that the liquid volumetric flowrate to a riser would be reduced, allowing more wells to be drilled and produced with existing facilities. This would in many cases increase the production economics and recoverable reserves of both existing oil production facilities offshore, new offshore installations and offshore marginal fields.
  • the system is able to manage slugs of gas up to 1000 pipe diameters without a process upset (that is to say a volume of gas as a single phase which is equivalent to a volume of gas at a given pressure and temperature inside a given inside diameter pipe from the wellhead, flowing at a given velocity, as a function of the separation minimum hold up or retention time needed for process or control systems to manage the said gas slug) .
  • a process upset that is to say a volume of gas as a single phase which is equivalent to a volume of gas at a given pressure and temperature inside a given inside diameter pipe from the wellhead, flowing at a given velocity, as a function of the separation minimum hold up or retention time needed for process or control systems to manage the said gas slug.
  • the system achieves one or more of the following key process steps : -
  • a vortex valve can be incorporated into the pre-water knockout separator.
  • a major benefit of using a vortex valve is the complete lack of actuated control valves with moving parts on main flow lines, the ability to manage slugs and in a slowly swirling vessel, the ability to detect and manage interface levels. There is also a considerable benefit in not requiring hydraulic or electric power to actuate a vortex valve and its ability to respond instantly, ie with no delay between cause and effect. It is an advantage of the separator that it is capable of managing gas slugs, solids and liquid/liquid separation with no moving parts or valve actuators on the main flow lines.
  • the fluidising unit can move any separated solids to the surface for treatment by means of a riser.
  • inlet water can be used to wash media in a radial type filter, and the very small amount of media wash water used can be displaced into a riser for treatment at the top side (in a subsea application) .
  • the radial filter utilises ceramic media.
  • the filter should be capable of operating for up to ten years without a change of media. Therefore, ceramic media is an ideal media for the filter.
  • Fig (1) is a diagram of the principal steps in a process used to separate oil from water on the seabed;
  • Fig (2) is the production profile of a typical oil producing well
  • Fig (3) is a diagram of a conventional de-oiling hydrocyclone
  • Fig (4) is a cross-section through a separator in accordance with the present invention.
  • Fig (5) is a longitudinal cross-section through a fluidising apparatus
  • Fig (6) is a cross-section on line AA in Fig (5) ;
  • Fig (7) shows an alternative filtering arrangement in which a low pressure high flow rate de-oiling hydrocyclone is provided downstream of a filter assembly
  • Fig (8) is a computer representation of cyclone flow.
  • a system which has the required process units needed to create a modular subsea separation system.
  • Fluids from the production well or wells (W) report to a gas liquid separator (A)
  • free gas from (A) exits the separator under pressure control and may or may not report to an inductor or jet pump (C) and from (C)'s outlet to the production riser.
  • Liquids and solids from (A) report directly, or via a booster pump (G) , to free water knock out separator vessel (B) .
  • the continuous oil phase from (B) reports under differential pressure control to the suction side of the booster jet pump (C) , or direct to a production riser as required by the pressure balance across the system.
  • the continuous water phase from (B) reports under differential pressure control or quality control (oil in water content) either directly to an injection/disposal well or zone via injection pump (H) , or to a water polishing unit (E) to further reduce the oil in water content of the produced water.
  • (D) is charged with solids to a predetermined volume, it is isolated from (B) thus allowing a small volume of treated water from injection pump (H) at elevated pressure to transport the solids again with a fluidising unit to either a disposal zone, or if clean to the sea bed, or (preferably) to the production riser downstream of the jet pump (C) to avoid erosion of the jet pump internals and unnecessary maintenance on the sea bed.
  • the solids are then removed at the topside production facilities. Waste liquid streams from (D) and (E) when used report to the suction side of (C) or the riser as the case may be .
  • sea water is normally filtered to meet reservoir permeability and dissolved oxygen is normally removed down to around 20ppb (parts per billion)
  • some scale and corrosion inhibitors can be injected to the water, as can biocides. If the volume of water needed to be injected can be met with produced water from the well then this can be used, again in some cases following some filtration. In many cases however the volume of produced water is insufficient for the reservoirs needs and must be supplemented by aquifer waters, if readily available, or if not by seawater.
  • Aquifer water requires a well to be drilled and must be available in sufficient quantities in order to be viable, so seawater is likely to be the most abundant and economic source available. Consequently, in most cases produced water removed and treated on the seabed, will be mixed with seawater to make up the required volumes of injection water for enhanced recovery.
  • filters (E) and (F) have different filtration needs to overcome. Filter (E) will experience fine solids which may be oil wetted but are normally fairly resistant to deformation by pressure across them, i.e.
  • filter (E) must be sized to. meet the required oil capture or removal rate, rather than the solids removal rate. At lower flux rates solids removal efficiencies generally improve, but the unit's size increases for a given flowrate. Filter (F) will only have to remove solids with no oil, when it is treating seawater or aquifer waters. This will allow the unit to be designed for a higher flux rate, and hence be of a smaller size.
  • filters (E) and (F) again have different problems to overcome when used on the seabed.
  • Filter (E)'s media wash water will contain high levels of solids and oil which are inadmissible to the sea, and will therefore need to report to the riser for further treatment on surface facilities, whereas filter (F) is removing inert solids or zooplankton with no associated oil . It may therefore be allowable to discharge the media wash water from filter (F) directly into the sea via a stack to allow the concentrated solids to plume or spread over large distances by use of under water currents .
  • Injection pump (H) can be a normal centrifugal pump, or a down-hole type, as would currently be used as ESP's (electrically submerged pumps) .
  • Fig (4) shows a free water knockout separator (B) comprising a pressure vessel or tank 1 with an inlet for well fluids 2 which is preferably tangential or has means to cause the fluids entering 1 to rotate in a vortex, a treated water outlet means 3 situated at the lower end of vessel 1, an oil rich outlet means 4 at the upper end of vessel 1 which can extend as required into vessel 1 axially to a position where an oil pad will exist, an inlet or outlet means 5 for control of pressure or removal of gas from vessel 1, a core finder 6 for the capture and reflection of the vortex core produced by the rotational motion of the fluids in vessel 1, a fluidising unit 7, which when fed by water at a higher pressure than that existing in vessel 1, will fluidise settled solids and direct them to a solids outlet 8.
  • B free water knockout separator
  • Figs (5) and (6) illustrate a fluidising apparatus comprising a flow chamber 102 having a fluid inlet 104 and a fluid outlet 106.
  • the flow chamber 102 comprises a housing in the form of a cap 108 having a side wall 110 and a top 112 which in the region 114 is generally in the shape of a cone with a concave side wall .
  • the underside of the top 112 is provided with an annular recess 116 in which is located a cylindrical flow guide 118.
  • the upper portion 120 of the flow guide 118 is provided with a series of tangential slots 122a to 122f .
  • the lower portion 124 of the flow guide 118 has an external thread which cooperates with an internal thread formed in an annular flange 126.
  • a fluid outlet 106 is defined between the side wall 110 of the cap 108 and the flange 126 and an annular flow passage 128 is defined between the side wall 110 of the cap 108 and the upper portion 120 of the flow guide 118.
  • the annular flow passage 128 is continuous with the fluid outlet 106, so that the fluid inlet 104 communicates with the fluid outlet 106 by means of the tangential slots 122a to 122f and the flow passage 128.
  • a transport outlet 130 Directly above the flow chamber 102 is located a transport outlet 130.
  • fluid under pressure enters the fluidising unit through the fluid inlet 104, passes down the flow guide 118 and exits the flow guide tangentially via the slots 122a to 122f (as the open end of the flow guide 118 is closed by the cap 108) .
  • the cap 108 also acts as a swirl enhancer and is positioned such that its side wall 110 forms one side of the said annular flow passage 128 around the tangential slots 122a to 122f.
  • the cap 108 is longer than the slots 122a to 122f, such that it overlaps the slots by an amount 'd' and defines the fluid outlet 106 by which the concentrated swirling fluid exits the flow chamber 10
  • the profiled region 114 of the cap 108 is shaped in order to encourage a stable fluid regime above the flow chamber 102.
  • the swirling flow exiting the flow chamber 102 fluidises, mixes and breaks up settled or partly settled solids adjacent to the flow chamber 102, thereby forming a mobile slurry, which is directed towards the transport outlet 8 (Fig (4) ) from where it can be directed to a slurry pipeline or for further processing.
  • the transport outlet 8 may, for example, comprise a substantially horizontal pipe or a pipe with a bend (preferably a 90 degree bend) , and it may be funnelled, such that it flares outwardly towards the flow chamber 102.
  • the separator vessel (B) receives well fluids either indirectly from a bulk gas removal unit or directly from the well itself. Referring to Fig (4), the fluids enter the separator at inlet 2 which imparts a rotational force on the fluids, the purpose of which is to enhance the separation forces above those which exist under normal gravity. It is not intended to create the same level of separation force as those existing within de-oiling hydrocyclones, rather to develop a balance between centrifugal force and retention time, the separator is designed to have a retention time of less than 20 seconds which for a given flowrate is considerably smaller than a conventional three phase separator, but larger than a de- oiling hydrocyclone.
  • the fluids rotating in vessel 1 start to separate, with any free gas migrating to the top of vessel 1, and oil moving to the centre of vessel 1 and upwards to sit above the water which has migrated outwards to the wall of vessel 1 and downwards. Any solids entering with the fluids report to the bottom of vessel 1.
  • the gas outlet/inlet 5 is used to keep a gas blanket at the desired pressure above the oil pad, this achieves two functions.
  • the first function is to provide additional pressure to remove oil from vessel 1, via oil outlet 4, and the second function is to assist the establishment of a strong vortex by establishing a gas core for the oil to migrate to.
  • a pressure control valve on outlet 5 is used to modulate the pressure inside vessel 1 to the desired level. After the liquids have been rotating for some time, an oil pad will form on top of the water, it is intended to allow this pad to exit vessel 1 via oil rich outlet 4 which is always below the total level of liquids in vessel 1 and in the oil phase. Control of the flowrate of the oil rich stream leaving outlet 4, is obtained by the gas pressure above the oil pad which is adjustable. Separated produced water leaves vessel 1 via outlet 3; this is preferably controlled by a water quality monitor and a flow control valve or the speed of the water injection pump (H) . Vessel 1 may also have its split ratio ( ratio of water removed to oil removed) controlled by differential pressure similar to that described earlier for de-oiling hydrocyclones.
  • Solids that have settled into the base of vessel 1 are fluidised and removed to the next process as may be the case by the use of a hydro transport unit such as that described in our earlier UK application No 0212728.0 or similar.
  • the separator (B) is able to manage the complete flow range of phases it is likely to experience during the life of the field. For example in the early days' of production there may be very little water, whereas at the final stages of production it is most likely that the bulk phase will be that of water. Control of this variation in flow is best achieved by monitoring water quality on line using instruments such as a Jorin Vipa unit or similar. This can be achieved using fibre optic communication from the seabed to the surface facilities with very fast response times.
  • the Vipa unit is a video microscope that films droplets and solids as they pass through a sample cell at line pressure; this information is then digitised and fed to a computer programme that can determine oil in water mg/1 and solids content, both of which are important factors when considering the next steps of injection or filtration. Should water quality not meet design requirements for whatever reason the water out line 3, will close and allow all fluids to depart vessel 1 via the oil outlet 4, after a set time the water will again be sampled and when it meets specification it will be allowed to move on to the next process stage.
  • solids will normally be constantly removed using a small amount of treated produced water from down stream of injection pump (H) and fed into sand cyclone (D) , the overflow from (D) joins the oil rich stream from (B) , (D) will be made up of a solid liquid cyclone section that has a small sand holding volume and a lower section which is isolatable by valve means from the cyclone section, such that once isolated and full of solids it can be elevated in pressure by water from downstream of injection pump (H) via its fluidising hydro transport unit, such as our earlier UK application No 0212728.0, in order to transport the solids to the riser downstream of any inductor or jet pump (C) to avoid erosion.
  • H down stream of injection pump
  • D sand cyclone
  • valve means from the cyclone section
  • the solids from (D) can be raised direct to the topside in a separate small riser to avoid re-entraining them back into the oil rich stream, from which they would have to be removed again.
  • the bottom sand pot of cyclone separator (D) therefore operates as a batch process controlled by a solids level monitor or other means within the sand pot .
  • Filters (E) and (F) or a combined unit to achieve the filtration after mixing of the waters to be injected will preferably be of the type described in our earlier UK application No 0308291.4, or similar, as these type of filters wash their filtration media online, and by use of their media wash vessel can displace oily waste wash water back into the riser by operating the fluidising unit in the wash vessel at elevated pressures.
  • cyclone separator (D) it may be possible to use cyclone separator (D) to act as the Filter (E) and (F)'s media wash vessel, hence reducing the number of pressure vessels on the sea bed.
  • a low pressure high flowrate less efficient de-oiling hydrocyclone downstream of (B) on the water outlet as typically shown in Fig (7) , particularly where no filtration is required to meet reservoir injectivity or disposal zone requirements.
  • CFD computational fluids dynamics
  • Fig (8) is a typical output for cyclone modelling showing pressure contours and solid trajectories.

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  • Engineering & Computer Science (AREA)
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  • Mining & Mineral Resources (AREA)
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  • Life Sciences & Earth Sciences (AREA)
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  • Physical Water Treatments (AREA)

Abstract

La présente invention concerne un séparateur permettant de séparer un courant en un premier fluide, et un second fluide plus dense que le second, et des solides. Ce séparateur comprend un récipient pourvu d'une admission pour le courant. Des organes provoquent une rotation du courant dans le récipient. Le séparateur comprend également, dans le récipient, pour le premier fluide, une première évacuation équipée d'un passage dont l'extrémité d'entrée est tournée vers un axe central du récipient. Le séparateur comprend aussi, pour le second fluide, une seconde évacuation tournée vers une paroi latérale du récipient. Le séparateur comprend enfin une troisième évacuation pour les solides.
PCT/GB2004/002874 2003-07-04 2004-07-02 Separateur WO2005005012A1 (fr)

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GB0315734A GB2403440B (en) 2003-07-04 2003-07-04 Separator
GB0315734.4 2003-07-04

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WO2005005012A1 true WO2005005012A1 (fr) 2005-01-20

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GB (1) GB2403440B (fr)
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KR101346207B1 (ko) 2012-07-04 2014-01-02 주식회사 부강테크 와류를 이용한 3상 분리 수처리 장치
US10112848B2 (en) 2014-08-25 2018-10-30 Exxonmobil Upstream Research Company Emulsion extraction and processing from an oil/water separator
CN110117103A (zh) * 2019-06-10 2019-08-13 青岛哈工资源环境技术有限公司 一种油田三元采出水臭氧氧化降粘的处理装置及其使用方法
CN110465246A (zh) * 2019-09-11 2019-11-19 上海电气电站环保工程有限公司 一种三相分离器
US11173427B2 (en) 2017-09-25 2021-11-16 Sand Separation Technologies Inc. Device for separating solids from a fluid stream
US11839884B2 (en) 2018-09-06 2023-12-12 Sand Separation Technologies Inc. Counterflow vortex breaker

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US7569097B2 (en) * 2006-05-26 2009-08-04 Curtiss-Wright Electro-Mechanical Corporation Subsea multiphase pumping systems
EP2551002A1 (fr) * 2011-07-28 2013-01-30 Siemens Aktiengesellschaft Séparation de phases d'un mélange multiphases
GB2529779B (en) * 2014-11-14 2016-08-17 Dwc As Solids separation, washing and sampling system
CN110342602B (zh) * 2019-07-18 2022-01-25 中国石油集团渤海钻探工程有限公司 一种油气井废气处理用自旋流脱气装置

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GB212728A (en) 1923-02-22 1924-03-20 John Bentley Hansell Improvements relating to terminals for electrical transformers
US3759324A (en) * 1972-05-25 1973-09-18 Kobe Inc Cleaning apparatus for oil well production
US4072481A (en) * 1976-04-09 1978-02-07 Laval Claude C Device for separating multiple phase fluid systems according to the relative specific gravities of the phase
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Cited By (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
KR101346207B1 (ko) 2012-07-04 2014-01-02 주식회사 부강테크 와류를 이용한 3상 분리 수처리 장치
US10112848B2 (en) 2014-08-25 2018-10-30 Exxonmobil Upstream Research Company Emulsion extraction and processing from an oil/water separator
US11173427B2 (en) 2017-09-25 2021-11-16 Sand Separation Technologies Inc. Device for separating solids from a fluid stream
US11839884B2 (en) 2018-09-06 2023-12-12 Sand Separation Technologies Inc. Counterflow vortex breaker
CN110117103A (zh) * 2019-06-10 2019-08-13 青岛哈工资源环境技术有限公司 一种油田三元采出水臭氧氧化降粘的处理装置及其使用方法
CN110117103B (zh) * 2019-06-10 2021-11-26 青岛哈工资源环境技术有限公司 一种油田三元采出水臭氧氧化降粘的处理装置及其使用方法
CN110465246A (zh) * 2019-09-11 2019-11-19 上海电气电站环保工程有限公司 一种三相分离器

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GB2403440A (en) 2005-01-05
GB2403440B (en) 2007-09-05
GB0315734D0 (en) 2003-08-13

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