WO2016209086A1 - Système de séparateur et procédé de décomposition de bande de dispersion - Google Patents

Système de séparateur et procédé de décomposition de bande de dispersion Download PDF

Info

Publication number
WO2016209086A1
WO2016209086A1 PCT/NO2016/050139 NO2016050139W WO2016209086A1 WO 2016209086 A1 WO2016209086 A1 WO 2016209086A1 NO 2016050139 W NO2016050139 W NO 2016050139W WO 2016209086 A1 WO2016209086 A1 WO 2016209086A1
Authority
WO
WIPO (PCT)
Prior art keywords
inlet pipe
separator
pipe
separator system
diameter
Prior art date
Application number
PCT/NO2016/050139
Other languages
English (en)
Inventor
Jon Sigurd BERNTSEN
Per Eivind Gramme
Original Assignee
Kanfa As
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 Kanfa As filed Critical Kanfa As
Publication of WO2016209086A1 publication Critical patent/WO2016209086A1/fr

Links

Classifications

    • 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
    • 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
    • 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
    • B01D17/0208—Separation of non-miscible liquids by sedimentation
    • 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
    • B01D17/0208—Separation of non-miscible liquids by sedimentation
    • B01D17/0211—Separation of non-miscible liquids by sedimentation with baffles
    • 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
    • B01D17/0208—Separation of non-miscible liquids by sedimentation
    • B01D17/0214—Separation of non-miscible liquids by sedimentation with removal of one of the phases
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D19/00—Degasification of liquids
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D19/00—Degasification of liquids
    • B01D19/0021—Degasification of liquids by bringing the liquid in a thin layer
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D19/00—Degasification of liquids
    • B01D19/0021—Degasification of liquids by bringing the liquid in a thin layer
    • B01D19/0026—Degasification of liquids by bringing the liquid in a thin layer in rotating vessels or in vessels containing movable parts
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D19/00—Degasification of liquids
    • B01D19/0042—Degasification of liquids modifying the liquid flow
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D19/00—Degasification of liquids
    • B01D19/0068—General arrangements, e.g. flowsheets
    • 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
    • E21B43/36—Underwater separating arrangements
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17D—PIPE-LINE SYSTEMS; PIPE-LINES
    • F17D1/00—Pipe-line systems
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17D—PIPE-LINE SYSTEMS; PIPE-LINES
    • F17D1/00—Pipe-line systems
    • F17D1/005—Pipe-line systems for a two-phase gas-liquid flow
    • 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

Definitions

  • the present invention relates to a separator system for separating gas, oil and water.
  • the invention also relates to a method for breaking down a dispersion band between an oil phase and a water phase. It especially relates to a separator system for use on an offshore installation.
  • the well fluid produced from an oil or gas well will nearly always be a mixture of oil, gas and water. It is a great advantage to perform most of the separation of these three phases before the fluids are transported to the shore. This will ease the handling, reduce risk associated with the handling and reduce the need for transportation of water.
  • a degassing section upstream of the separator.
  • the degassing section comprises a plurality of substantially vertical degassing pipes connected at a first end to the inlet pipe upstream of the separator.
  • the degassing pipes are connected at a second end to a gas collection pipe. This gas collection pipe connects with the gas outlet pipe from the separator.
  • US 4760742 concerns a device for separating a multiphase petroleum production stream flowing in a sub-sea pipe. Here a gas collection pipe is inclined downwards in the downstream direction, which will allow any liquid carried with the gas to flow downwards together with the gas and thereby pollute the gas with liquid.
  • US 8864881 shows a slug suppressor apparatus comprising an inlet separator capable of gas-liquid separation of well stream fluid and expanded inclined liquid pipe for dampening slugs.
  • the inlet separator has an inlet arrangement for receiving the well stream fluid, a separated gas outlet in its upper section, and a separated liquid outlet in its lower section.
  • the separated gas outlet and the separated liquid outlet are operationally connected to a gas bypass line and the expanded inclined liquid pipe, respectively.
  • the expanded inclined liquid pipe has means for dampening liquid slugs and is connectable to a 3-phase separator.
  • SU 1005820 describes a separator system that is built on similar principles as WO 2006098637, but in addition has a gravitational separator that is schematically shown. However, there are no details on the interior of the separator. Most of the water is separated from the oil before it enters the gravitational separator.
  • WO 2004022198 describes a gravitational separator and its functions.
  • a partition is arranged within the separator. Oil can flow over this partition to a second chamber, while water is retained.
  • the present invention aims to improve the separation efficiency over the above prior art.
  • Separation in pipes is very efficient and is in the present invention utilized to stratify the gas and liquid phase upstream of a gas removal unit, in order to facilitate gas removal upstream of the separator.
  • the more efficient separation in pipes is also utilized in the present invention to achieve maximum separation in the inlet arrangement prior to the flow entering the main separator volume in the separator.
  • the more efficient separation in pipes is due to the fact that the rate determining step is not the sedimentation of water droplets or floating of oil droplets to the water-oil interface, but the break-down of the formed dispersion band or dense packed layer of droplets accumulated at the interface. This dense packed layer of droplets is most efficiently broken down when exposed to shear forces acting between the phases.
  • the present invention therefore has as a first aim to improve the separation in a per se conventional separator by removing as large a portion of the free gas as possible. Thereby the torque through the inlet of the separator and the entrainment of the free gas into the liquid phases are reduced.
  • a second aim of the present invention is to provide an inlet arrangement to a per se conventional separator, which imposes low torque and low shear force to the fluids as such. Thereby is achieved reduced re-dispersing of free gas, a flow regime that facilitates an improved freeing of gas from the liquid phases and a flow regime that facilitates oil and gas separation.
  • a third aim of the present invention is to provide an inlet arrangement to a per se conventional separator with dimensions facilitating the formation of stratified liquid flow. Thereby is achieved improved separation of oil and water as well as more efficient gas release.
  • a fourth and most important aim of the present invention is to provide an inlet arrangement that will hold back the water phase and let the oil phase flow with a higher velocity than the water phase, thereby creating shear forces between the phases that will break down the droplets of oil or water that have accumulated at the interface between the water and oil.
  • a separator system for separating gas, oil and water comprising an inlet pipe, a degassing section and a gravity separator; said degassing section comprising a plurality of
  • substantially vertical degassing pipes connected at a first end to the inlet pipe upstream of the separator, the degassing pipes being connected at a second end to a gas collection pipe, said gravity separator comprising a separation receptacle and an inlet arrangement that includes a substantially horizontal inlet arrangement pipe, with perforations in its upper part, arranged within said separation receptacle, wherein the pipe has a downstream end section comprising a threshold at its lower part, said threshold retaining water up to a specific level in the inlet arrangement pipe, the upper part of the end section being open to allow oil to flow freely over the threshold.
  • Various embodiments of the threshold can serve this purpose, such as an upward inclination in the downstream direction of the inlet arrangement pipe or an end wall of said inlet arrangement pipe, said end wall closing a lower part of the pipe.
  • the threshold does not end abruptly. If an excess amount of water enters the inlet arrangement pipe, the level will rise and water will flow over the threshold. If the threshold is configured so that it gradually allows an increasing amount of water to flow out, the velocity of the water may still be kept lower than the velocity of the oil.
  • the upward inclination comprising perforations, where the perforations may have increasing size in the downstream direction and the perforations may be equipped with downwardly extending tubes; or the end wall has a notch extending from the upper edge of the end wall and downwards at least a part of the end wall height, where the notch has a decreasing width in the downward direction; the end wall has at least one opening below its upper edge and preferably a plurality of openings below its upper edge, said openings being of a smaller size with the distance downward from the upper edge.
  • the notch is preferably generally V-shaped.
  • the end wall may be inclined upwards in the downstream direction.
  • the inlet pipe has an upwardly extending portion between the degassing section and the gravity separator. Thereby is ensured that the portion of the inlet pipe downstream of the degassing section always contains liquid. This liquid will prevent large gas amounts from entering the separator.
  • the length of the inlet pipe upstream of said degassing section is adapted to the well fluid to be separated and the diameter of the inlet pipe, and it has been found that the following ranges are suitable, depending on the properties of the fluid:
  • the inlet pipe has a downward inclination in the downstream direction at least in the degassing section. This will promote the separation of gas in the degassing section.
  • this inclination should have an angle of 1 ° - 20°, preferably 3° - 15° and more preferably 5° - 12°.
  • the substantially vertical degassing pipes should have a diameter that is substantially equal to the diameter of the inlet pipe upstream of the degassing section and a length of between 2 and 20 times the diameter of the inlet pipe upstream of said degassing section. This will promote the separation of gas.
  • the gas collection pipe has an upward inclination in the downstream direction, said inclination having an angle of 1 ° - 20°, preferably 3° - 15° and more preferably 5° - 12°.
  • the inlet pipe is substantially horizontal between the degassing section and the gravity separator or has an upward inclination in the
  • the diameter of the inlet pipe between the degassing section and the gravity separator is at least equal to the diameter of the inlet pipe upstream of the degassing section. This promotes stratified flow of the liquids.
  • the upwardly extending portion of the inlet pipe between the degassing section and the gravity separator is a pipe section with a substantially steeper inclination than the inlet pipe between the degassing section and the gravity separator as such.
  • the steeper inclination may be a part of an inverted u-shaped pipe section, i.e. a gooseneck.
  • the inlet pipe between the degassing section and the gravity separator has a constant diameter, to promote stratified flow.
  • the perforated inlet arrangement pipe within said separation receptacle is preferably substantially horizontal and has a diameter that is larger than the inlet pipe upstream of the degassing section and is at least equal to the diameter of the inlet pipe between the degassing section and the gravity separator. This will reduce the velocity of the flow and promote stratified flow of the phases as such. It will also ensure that the water phase will settle in the lower part of the pipe.
  • the invention also defines a method for breaking down a dispersion band between an oil phase and a water phase, wherein the water is retained at and allowed to establish at a certain level, so that the water flows at zero or low velocity, while the oil is allowed to flow freely on top of the water phase at a higher velocity.
  • This method promotes a difference in velocities between the water phase and the oil phase. Thereby, shear forces will act between the phases and break up the dispersion band that has formed between the phases.
  • a major part of the free gas is removed from the oil and water upstream of the breaking down of the dispersion band.
  • the flow will primarily consist of oil and water and gas will not interfere with the process of establishing stratified flow in the separator inlet pipe.
  • a stratified flow regime is ensured upstream of the degassing section by keeping the superficial liquid velocity:
  • Figure 1 shows a schematic general outline of the separator system of the present invention
  • Figure 2 shows a first embodiment of a liquid trap in inlet pipe in the form of a gooseneck
  • Figure 3 shows a second embodiment of a liquid trap in the inlet pipe in the form of a step-up
  • Figure 4 shows a section of the inlet of the separator in a first embodiment
  • Figure 5 shows a section of the inlet of the separator in a second embodiment
  • Figure 6 shows a section of the inlet arrangement of the separator in a first embodiment
  • Figure 7 shows a section of the inlet arrangement of the separator in a second embodiment
  • Figure 8 shows a section of the inlet arrangement of the separator in a third embodiment
  • Figure 9 shows a section of the inlet arrangement of the separator in a fourth embodiment
  • Figure 10 shows a section of the inlet arrangement of the separator in a fifth embodiment
  • Figure 11 shows a section of the inlet arrangement of the separator in a sixth embodiment
  • Figure 12 shows a section of the inlet arrangement of the separator in a seventh embodiment
  • Figure 13 shows a section of the inlet arrangement of the separator in an eight embodiment
  • Figure 14 shows a section of the inlet arrangement of the separator in a ninth embodiment
  • Figure 15 shows a section of the inlet arrangement of the separator in a tenth embodiment
  • Figure 1 shows schematically the general arrangement of the separator system of the present invention. It comprises an inlet pipe 1 that is coupled to the well via appropriate valves and other equipment that is well known in the field. The inlet pipe is coupled to the inlet of a gravity separator 4, as will be explained in detail below.
  • the degassing section 2 is in principle known from the above-mentioned references WO 2006098637 and US 4760742, but will nevertheless be explained in the following for completeness.
  • the degassing section 2 comprises a plurality of substantially vertical pipes 7- 1 1 that are connected to the inlet pipe 1 at their lower ends.
  • the inlet pipe 1 has a downward inclination in the downstream direction in the degassing section, starting upstream of the upstream vertical pipe 8 and ending at or downstream of the downstream degassing pipe 1 1 , denoted by 12.
  • This inlet pipe section is denoted 13.
  • the vertical pipes 7-1 1 are connected to a gas collection pipe 14.
  • the gas collection pipe joins the gas outlet 15 from the separator 4. From here the gas is exported to further handling, such as compression or burning in a flare.
  • the gas collection pipe 14 has two sections, a first section 16 that extends across the upper ends of the vertical pipes 7-11 and a second section 17 that extends from the first section to connect to the gas outlet 15.
  • the inlet pipe 1 extends through a further section 3 to the inlet 18 of the gravity separator 4.
  • the gravity separator 4 has an internal inlet arrangement 19, which is connected to the inlet 18. The inlet arrangement will be explained in further detail below.
  • the separator 4 also has a baffle 21 and an oil outlet 22 and a water outlet 23.
  • a prerequisite for efficient removal of gas in the degassing section is that a proper flow regime is achieved in the inlet pipe 1 .
  • Efficient free gas removal typically takes place when the flow is either slug flow or stratified flow.
  • the flow regime achieved depends on a multiple of factors, such as the chemical properties of the oil, water and gas, i.e. viscosity and density of the three phases of the well fluid, interface tensions between the three phases, coalescence properties for droplets of one phase in another, etc. It also depends on water cut, phase inversion point, production rates, the pressure of the well fluid, the roughness of the inside of the inlet pipe 1 , etc.
  • the superficial velocity of the liquid phases and the gas phases are determining how much mixing of the phases there will be when the well fluid flows through the inlet pipe. It has also been found that the desired flow regime, i.e. slug flow or stratified flow, is achieved when the inlet pipe is substantially horizontal until the degassing section 2. It has also been found that there is a correlation between the superficial gas velocity and the superficial liquid velocity and that a desired flow regime is achieved when the relationship between the superficial velocities are as follows:
  • the diameter of the inlet pipe should be within the range of 6" to 36" (152 mm to 915 mm), preferably 6" to 24" (152 mm to 610 mm), and more preferred 6" to 16" (152 mm to 407 mm).
  • the length of the inlet pipe 1 is also a key factor. It has been found that the length upstream of the degassing section 2 should be as long as possible. This will ensure that a desired flow regime is established. However, for practical reasons there are limitation on how long the inlet pipe 1 can be. It has therefore been found that the required length L1 has to be chosen depending on the diameter D1 .
  • a typical length L1 for a well fluid that is extremely difficult to separate will be in the range of 180 - 550 times the diameter D1 .
  • the length L1 should be within the range of 150 - 450 times the diameter D1 .
  • the length should be within the range of 100 - 300 times the diameter D1 .
  • the length should be within the range of 60 - 180 times the diameter D1 .
  • the length should be within the range of 30 - 90 times the diameter D1 .
  • the proper downward inclination a of the inlet pipe section 13 in the downstream direction relative to the horizontal has also been found to depend on the diameter D1 of the inlet pipe.
  • An interface between gas and liquid will form in the area of the downstream vertical degassing pipe 1 1 .
  • the inclination a of the inlet pipe section 13 will be in the range of 1 - 20°, preferably 3 - 15°, and more preferred 5 - 12°.
  • the number of vertical pipes 7-1 1 in the degassing section 2 can vary, but is typical from 4 to 6 pipes, depending on flow rates and size of slugs.
  • the diameter of the vertical pipes 7-1 1 is preferably the same as the diameter D1 of the inlet pipe 1 .
  • the length of each of the vertical pipes 7-1 1 may vary, but will typically be in the range of 2 to 20 times the diameter of the pipe.
  • the first section 16 of the gas collection pipe 14 may have the same inclination a as the inlet pipe section 13 but in an upward direction in the downstream direction. Thereby any liquid that has been drawn out with the gas will have a tendency to run back to the degassing section 2 and down the vertical pipes 7-1 1 .
  • the second section 17 of the gas collection pipe 14 can be either horizontal or have a slight upward inclination in the downstream direction to facilitate any liquid running back to the degassing section 2, especially during shutdown of the separation system.
  • the further section 3 of the inlet pipe 1 has at least the same diameter D3 as the upstream inlet pipe 1 , 13, but may also have a larger diameter, depending on the desired flow regime in this part of the separation system.
  • the length L3 of this further section 3 may be fairly short, but a longer length may be appropriate if it proves necessary for the establishment of an oil-water interface in the pipe before the fluid enters the separator 4.
  • transition between the inlet pipe section 13 covering the degassing section 2 and the further inlet pipe section 3 is denoted 12. This transition should be situated at or downstream of the last, i.e. furthest downstream, vertical pipe 1 1.
  • the further section 3 of the inlet pipe 1 has a gooseneck, such as shown in figure
  • the gooseneck or the upward inclination should have a height H that is at least the same as the diameter D3 of the pipe section 3.
  • This gooseneck or inclination ensures that the pipe section 3 upstream of the gooseneck or inclination will be filled with liquid. Thereby, gas pockets are prevented from finding their way into the separator 4.
  • Inside the separator 4 there is an inlet arrangement 19 that is in connection with the inlet 18.
  • the inlet arrangement 19 preferably comprises a pipe 20 with a diameter D4 that is at least the same as the diameter D3 of the inlet pipe section 3.
  • the diameter D4 is larger than the diameter D1 of the inlet pipe 1 upstream of the degassing section 2.
  • the diameter will be at least the same for the fluids from the inlet pipe 1 upstream of the degassing section 2 through to the inlet arrangement 19.
  • the diameter is increasing in the downstream direction along these pipe sections.
  • a transition from a smaller diameter pipe section 3 to a larger diameter pipe 20 is preferably shaped so that the lower limitation of the pipe section 3 and the pipe 20 are on the same level, as shown in figures 4 and 5.
  • the upper limitation may have any of many suitable forms and may especially be a short incline 24 in a substantially straight line, as shown in figure 4, or a curved line, as shown in figure 5.
  • the pipe 20 of the inlet arrangement 19 is situated in the upper part of the gravity separator 4.
  • the pipe 20 is perforated along its upper limitation. Gas in the fluid entering the inlet arrangement 19 is allowed to escape through these perforations 25, and the gas can escape through the gas outlet 15 from the separator 4 to join the gas from the degassing section 2.
  • the perforations may be slits or other holes distributed along the length of the pipe 20.
  • the inlet arrangement with its preferred increased diameter D4 compared to the diameter D1 , is designed to facilitate improved separation of the gas, oil and water phases. The increased diameter will lower the liquid velocity, leading to increased gas release and facilitating liquid-liquid stratification along the pipe 20.
  • At the downstream end of the pipe 20 there is an opening 6 allowing the liquid to escape into the separator 4 volume.
  • the downstream end of the pipe 20 has a threshold 5 that will ensure that the water phase, which due to the stratified flow will be in the lower portion of the inlet pipe 20, is held back, i.e. the velocity of the water phase is reduced.
  • This formation of and hold-up, i.e. retaining, of the water phase after stratification in the pipe 20 will happen regardless of incoming amounts of water in the oil-water-gas mixture (water cut). Only when the amount of water exceeds a certain level, the water will be allowed to flow out of the inlet pipe 20. Due to this construction of the downstream end of the pipe 20 the water phase and the oil phase is flowing at different velocities, i.e.
  • the downstream end of the pipe 20 can be designed in various ways to achieve the desired functionality.
  • the downstream end of the pipe 20 has a threshold, which in figures 6 and 7 is a gooseneck 26.
  • This will retain water in the pipe 20 so that a water level W is established.
  • the water level W will be retained at the same height as the height Hw of the bottom of the gooseneck as shown in figure 6.
  • the gooseneck 26 may have perforations 27 at its upward slope a distance above the lower limitation of the pipe 20, as shown in figure 7 to drain water from the pipe 20. In that case, the water level will establish at the height of the perforations 27.
  • the end of the pipe 20 is in both cases open, so that the oil will run on top of the water and escape into the interior of the separator 4.
  • Figures 8-10 show other embodiments of the end of the pipe 20. These have a steep inclination 28 instead of a gooseneck 26.
  • the inclined pipe section 28 ends abrupt at a height Hw.
  • the inclined pipe section 28 has perforations 29 at the lower end of the inclination to allow water to escape when it exceeds the level Hw.
  • the inclined pipe section 28 is equipped with narrow vertical pipes 30, which have increasing diameters in the downstream direction.
  • the cross section of the perforations or narrow pipes are selected so that liquid is retained in the pipe 20 at substantially the level W.
  • Further alternative shapes of the downstream end of the pipe 20 are shown in figures 1 1 -15.
  • the pipe 20 has an end wall 31 covering the lower half of the cross section.
  • the end wall may have openings in the form of a notch 32, a single hole 33 or a multiple of openings 34 with increasing diameter in the upward direction.
  • the end wall may also be inclined in the downstream and upward direction as shown in figure 15.
  • the end of the pipe 20 is configured so that the cross section of the opening gradually increases with the height.
  • a preferred embodiment is shown in figure 12, where a notch 32 defines the water level W.
  • the water will first flow out through the narrow bottom of the notch 32. If the water amount continues to increase, the water level W will rise further up the notch and the amount of water escaping through the notch 32 will increase. If a large enough amount of water is supplied to the inlet pipe 20, the water level W may increase to the ledge 35. Now, the velocity of the oil and water will be substantially the same. However, such a situation will last only for a short periods during production, normal production is characterized by constant rate differences. Thus, the water level W will only increase beyond the ledge 35 for short periods of time.
  • the dispersion band When the oil and smaller amount of water leaves the inlet pipe 20 through the opening at the downstream end, the dispersion band has been substantially broken down and the oil and water exist in larger droplets or as a laminar flow.
  • This liquid of pre-separated oil and water will collect at the lower side of the separator 4. As the oil and water is largely separated, the gravity separation will now be very effective. Due to gravity, the oil and water will separate. Water is heavier than oil and will collect at the bottom and be drained through the water outlet 23.
  • a baffle 21 is arranged between the water outlet 23 and the oil outlet 22. The interface between the oil and water is monitored and the water outlet 23 is adjusted so that the interface is kept below the top of the baffle 21. Thereby oil is allowed to flow over the top of the baffle and out the oil outlet 22.

Landscapes

  • Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Physics & Mathematics (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Thermal Sciences (AREA)
  • Fluid Mechanics (AREA)
  • Geochemistry & Mineralogy (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Environmental & Geological Engineering (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Degasification And Air Bubble Elimination (AREA)
  • Control And Other Processes For Unpacking Of Materials (AREA)
  • Disintegrating Or Milling (AREA)

Abstract

La présente invention concerne un système de séparation pour séparer un gaz, de l'huile et de l'eau, et un procédé pour décomposer une bande de dispersion entre une phase huileuse et une phase aqueuse. Le système de séparateur comprend une section de dégazage (2) et un séparateur (4) ayant un tuyau d'agencement d'entrée (20). Le tuyau d'agencement d'entrée (20) possède un seuil (5) pour retenir l'eau jusqu'à un certain niveau, de telle sorte que l'huile peut s'écouler par-dessus le seuil (5). Ainsi, une différence de vitesses entre l'eau et l'huile est obtenue et la bande de dispersion est décomposée.
PCT/NO2016/050139 2015-06-25 2016-06-24 Système de séparateur et procédé de décomposition de bande de dispersion WO2016209086A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
NO20150835A NO20150835A1 (en) 2015-06-25 2015-06-25 Separator system and method for breaking down a dispersion band
NO20150835 2015-06-25

Publications (1)

Publication Number Publication Date
WO2016209086A1 true WO2016209086A1 (fr) 2016-12-29

Family

ID=57585192

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/NO2016/050139 WO2016209086A1 (fr) 2015-06-25 2016-06-24 Système de séparateur et procédé de décomposition de bande de dispersion

Country Status (2)

Country Link
NO (1) NO20150835A1 (fr)
WO (1) WO2016209086A1 (fr)

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
SU1005820A1 (ru) * 1981-08-31 1983-03-23 Repin Nikolaj N Сепарационна установка
WO2004016907A1 (fr) * 2002-08-16 2004-02-26 Norsk Hydro Asa Separateur de conduit pour la separation de fluides, notamment de petrole, de gaz et d'eau
WO2004022198A1 (fr) * 2002-09-09 2004-03-18 Norsk Hydro Asa Dispositif de separation de fluides multiphase
WO2006098637A1 (fr) * 2005-03-16 2006-09-21 Norsk Hydro Asa Entree de separateur de tuyau

Family Cites Families (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US1939988A (en) * 1931-06-11 1933-12-19 Thomas F Knoles Automatic oil purifier

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
SU1005820A1 (ru) * 1981-08-31 1983-03-23 Repin Nikolaj N Сепарационна установка
WO2004016907A1 (fr) * 2002-08-16 2004-02-26 Norsk Hydro Asa Separateur de conduit pour la separation de fluides, notamment de petrole, de gaz et d'eau
WO2004022198A1 (fr) * 2002-09-09 2004-03-18 Norsk Hydro Asa Dispositif de separation de fluides multiphase
WO2006098637A1 (fr) * 2005-03-16 2006-09-21 Norsk Hydro Asa Entree de separateur de tuyau

Also Published As

Publication number Publication date
NO20150835A1 (en) 2016-12-26

Similar Documents

Publication Publication Date Title
US8286805B2 (en) Method and apparatus for fluid separation
US6872239B2 (en) Method and a system for separating a mixture
DK1871505T3 (en) Separator to separate a mixture of liquid / liquid / gas and solid.
US20050150827A1 (en) Separator
US11091996B2 (en) Method and system for separating oil well substances
RU2583268C1 (ru) Газожидкостный сепаратор
US11285405B2 (en) Inclined linear multi-phase gravity separation system
CN202400880U (zh) 一种二级聚结处理含油污水的装置
US20170266586A1 (en) Method and Apparatus for Fluid Separation
RU2268999C2 (ru) Скважина и способ добычи нефти из подземного пласта через скважину
US4790947A (en) Water treating in a vertical series coalescing flume
US4720341A (en) Water treating in a vertical series coalescing flume
RU2695207C2 (ru) Фазовый сепаратор с использованием разности давлений
WO2016209086A1 (fr) Système de séparateur et procédé de décomposition de bande de dispersion
NO20120521A1 (no) Undervanns separasjonssystemer
RU2291734C2 (ru) Трубный водоотделитель
RU91883U1 (ru) Скважинная установка сброса воды
CN115650463B (zh) 层流分离装置和油水混合液处理设备
RU2252312C2 (ru) Сепарационная установка
RU73798U1 (ru) Патрубок отвода нефти из трубной сепарационной установки
EP4045763A1 (fr) Procédé et système de séparation de substances de puits de pétrole avec des moyens de capture et d'élimination de liquide d'une canalisation de sortie de gaz

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 16814786

Country of ref document: EP

Kind code of ref document: A1

NENP Non-entry into the national phase

Ref country code: DE

122 Ep: pct application non-entry in european phase

Ref document number: 16814786

Country of ref document: EP

Kind code of ref document: A1