BR112016016005B1 - POLYPHASE SEPARATION SYSTEM - Google Patents

Description

“POLYPHASIC SEPARATION SYSTEM” REFERENCE TO RELATED APPLICATIONS

This application claims the priority benefit of United States Patent Application No. 61 / 985,873, filed April 29, 2014, entitled MULTIPHASE SEPARATION SYSTEM, the entirety of which is incorporated herein by reference.

FIELD OF INVENTION

The present techniques provide separation of oil and water feed streams into production fluids. More specifically, the techniques provide for the separation of production fluids in phases from the oil and water components using a subsea polyphase separation system.

BACKGROUND OF THE INVENTION

This section is intended to introduce various aspects of the technique which may be associated with exemplary embodiments of the present techniques. This discussion is believed to assist in providing a framework for facilitating a better understanding of the particular aspects of the present techniques. Therefore, it should be understood that this section should be read in this light, and not necessarily as prior art admissions.

Any number of subsea separation techniques can be used to increase the amount of oil and gas recovered from subsea wells. However, underwater separation at water depths greater than 1500 meters becomes especially challenging due to environmental conditions. As water depth increases, the external pressure in a vessel created by the hydrostatic drop increases the wall thickness required for vessels used for subsea processing. At water depths greater than 1500 meters, this wall thickness increases to such an extent that typical gravity separation vessels are not practical. In addition, vessels of such bulky wall thickness can be a challenge to manufacture, and added material and weight can impact design economics as well as serviceability of the vessel. As a result, large diameter separators often cannot be used at such water depths.

Studies have been made with respect to liquid and gas separation in subsea systems and methods in U.S. Patent No. 8,282,711 B2. These systems and methods describe the separation of liquids and gases from an subsea production fluid using a piping system that divides the flows of liquid and gaseous fluids through separate manifolds.

Further studies concerning a pipe separator system for improving separation can be found in U.S. Patent No. 7,490,671. The system describes a tube separator utilizing a cyclone and an electrostatic coalescer as part of the separator body for separating oil, gas, and water from an underwater well.

Further studies concerning a tube separator for fluid separation can be found in U.S. Patent No. 7,516,794. This system describes a piping system similar to that of US 7,490,671, and fluids flow in separate manifolds. The piping system described adds to the need for the system to be "Hmpable".

Further studies concerning a fluid separation facility can be found in U.S. Application 2005/0006086. The system describes pipe separators that are part of the transport piping and use an electrostatic coalescer to separate a stream of oil, gas, and water.

Further studies concerning a method and apparatus for improving the performance of a separator can be found in U.S. Application 2008/0116072. The method and apparatus describe a gravity settling vessel, and feed a through current through a compact electrostatic coalescer and back to the settling vessel.

SUMMARY OF THE INVENTION

An exemplary embodiment provides a polyphase separation system including a separation line configured to feed a polyphase fluid into vertically oriented feed lines within the separation system, wherein the feed lines consist of an upper line, a line. intermediate, and a bottom line. The upper line is configured to flow an oil supply line to an oil section. The intermediate line is configured to flow an oil / water emulsion feed line to an oil / water emulsion section. The bottom line is configured to flow a water supply line to a water section. The polyphase separation system also includes a control volume, configured to adjust the fluid flow rate at an outlet, where the oil section, water section, and oil / water emulsion section blend into one another. different heights of the vertically oriented control volume.

Another exemplary embodiment provides a method for the separation of oil and water and oil / water emulsion within a polyphase fluid, including flowing a polyphase fluid into a manifold inlet of a polyphase separation system. The method includes separating the polyphasic fluid into an oil phase, a water phase, and an oil / water emulsion. The oil phase is separated into a line that is in a plane vertically above a distribution inlet plane. The water phase is separated into a line that is in a plane vertically below the distribution inlet plane. The oil / water emulsion is separated into a line that is in a plane vertically above the plane of the line with the water phase and vertically below the plane of the line with the oil phase. The method also includes draining each line to a vertically oriented control volume, where the flow rate of each line is controlled, the oil and water level present in each line is detected, and each line is separated to a volume output. of control.

Another exemplary embodiment describes a separation system including an inlet line configured to feed a polyphase fluid to lateral feed lines within the separation system, wherein the lateral feed lines consist of a plurality of upper and lower lines. a plurality of lower lines. Each top line of the separation system is configured to feed an oil side feed line to an oil section, and further configured to split the inlet line into an oil / water emulsion section, where the oil section is in a plane vertically located above the oil / water emulsion section. Each bottom line of the separation system is configured to feed a lateral water supply line to a water section, wherein the water section is in a plane located vertically below the oil / water emulsion section, and the water section. Water is coupled to the oil / water emulsion section by subsequent lateral water extraction, originating from the oil / water emulsion section. The separation system also includes a control volume and a control system.

DESCRIPTION OF DRAWINGS

The advantages of the present techniques are best understood by reference to the following detailed description and the accompanying drawings, in which: Figure 1 is a block diagram of a polyphase separation system for separating production fluids which may be obtained from an underwater well;

Figure 2 shows an elevation drawing of an exemplary polyphase separation system;

Figure 3 is a top view of the exemplary polyphase separation system of Fig. 2, illustrating a horizontal divider in the polyphase separation system;

Figure 4 is a perspective view of another polyphase separation system as described herein;

[0018] Figure 5 is a side view of the polyphase separation system of fig. 4;

Figures 6A and 6B illustrate a process flowchart showing a method for separating liquids within a polyphase fluid;

Figure 7 illustrates a block diagram of an exemplary separation system, and includes a control system;

[0021] Figure 8 is a schematic view of a polyphase separation system and control system;

[0022] Figure 9 is a drawing illustrating the top, middle and bottom lines with sandblast nozzle injection points and recycle streams;

[0023] Figure 10A is a perspective drawing illustrating the water line with a collection area at the base of the line for solid particles to accumulate;

Figure 10B is an end view drawing illustrating the water line with a collection area at the base of the line for solid particles to accumulate;

[0025] Figure 11 is a drawing illustrating an adjustable dam system; and [0026] Figure 12 is a drawing illustrating an adjustable deflector system.

Fig. 13 is a side view schematic diagram of another embodiment of a polyphase separation system;

Fig. 14 is a perspective diagram of the descending / rising pipe apparatus of the polyphase separation system of Fig. 13;

Fig. 15 is a perspective diagram of the dams of the polyphase separation system of Fig. 13; and Fig. 16 is a side view schematic diagram of another embodiment of a polyphase separation system.

DETAILED DESCRIPTION OF THE INVENTION

In the following detailed description section, specific embodiments of the present techniques are described. However, to the extent that the following description is specific to a particular embodiment or particular use of the present techniques, it is intended to be for exemplary purposes only and simply to provide a description of exemplary embodiments. Accordingly, the techniques are not limited to the specific embodiments described below, but preferably include all alternatives, modifications, and equivalents within the true spirit and scope of the appended claims.

As used herein, "substantially", "predominantly" and other degree words are relative limiters intended to indicate the allowable variation of the characteristic thus modified. They are not intended to be limited to the absolute value or characteristic that modifies it, but preferably possess more of the physical or functional characteristic than its opposite and preferably address or approach such a physical or functional characteristic.

A "polyphasic fluid" is a fluid that is receptive to flow and is composed of two phases that are not chemically related (eg, oil and water), or where more than two phases are present (e.g. . liquid and gas).

An "emulsion" generally comprises two immiscible phases. The two immiscible phases include a continuous (or external) phase and a discontinuous (or internal) phase. The discontinuous phase comprises the secondary fluid, which generally exists in continuous phase droplets. Two varieties of emulsions are oil-in-water and water-in-oil. Oil-in-water emulsions generally include a fluid at least partially immiscible in an oleaginous fluid (usually a water-based fluid) as the continuous phase, and an oleaginous fluid as the discontinuous phase. Water-in-oil emulsions are the opposite, with oil fluid as the continuous phase and a fluid at least partially immiscible in oil fluid (generally a water based fluid) as the discontinuous phase. Water-in-oil emulsions may also be referred to as inverted emulsions.

A "demulsifier" refers to a surfactant or combination of surfactants that inhibits or prevents dispersion in an emulsion, thereby allowing immiscible substances to be more readily separated from each other.

A "dam" refers to a physical barrier, which can act as a gravity settling structure and, as used herein, is intended to separate water from oil flowing into a particular stream. As used herein, the barrier may also be extended downwards to force separation of flowing fluids from denser fluids such as water oil.

As discussed above, traditional separators, which often have a diameter of about one meter or more, face technical challenges in using deep water, for example, at depths greater than approximately 1500 meters. Thus, the embodiments described herein provide for an unconventional separation system which is capable of obtaining acceptable oil-water separation while satisfying the size and weight restrictions imposed on deepwater processing units. In addition, the separation system can be designed for tube code instead of vessel code, which can provide cost and weight savings. In many cases, for a given pressure class, the required wall thickness for a pipe is less than the required wall thickness for a corresponding vessel.

According to the embodiments described herein, a polyphase separation system may be used to increase the production of subsea wells, especially in deep water and arctic environments. In various embodiments, the separation system is a tube separator, which can be configured to separate production fluids into an oil phase, an aqueous phase, and a solid (or slurry) phase. In some embodiments, the separator may be configured to separate gaseous production fluids. In other words, examples of current separation techniques can be used to create single phase currents. This may allow the use of single-phase pumps, which are more effective and can achieve higher pressure differentials compared to polyphase pumps. For example, a single phase pump may be sufficient to pump a single phase current. In contrast, a series of polyphase pumps may be required to achieve the same pressure differential while pumping a polyphase current, especially in high intensity applications.

The separation process described herein can be used to achieve mass removal of aqueous fluids from the production fluids. Removal of aqueous fluids is termed water removal here, although it may be understood to include water with other contaminants, such as salts or other miscible fluids. Such mass removal of water can alleviate flow safety concerns by allowing substantially pure oil and gas streams to be delivered to the surface. These substantially pure streams will form smaller amounts of hydrates, such as methane cleavages, thus reducing the risk of obstruction or flow reductions. In addition, corrosion concerns can be reduced or eliminated. Sand and water by-product streams can then be disposed of in dedicated offshore disposal zones, or can be used for pressure maintenance in production reservoirs.

Mass removal of water may also result in a decrease in hydrostatic drop acting on the reservoir, thereby increasing both reservoir drive and production. Mass removal of water can also reduce flowline infrastructure, reduce the number of top-side water treatment facilities, reduce energy and pumping needs, and decongest existing facilities that are challenged with declining production rates. due to increased water cuts.

Figure 1 is a block diagram showing a polyphase separation system 100 for separating production fluids 102 obtainable from an underwater well 104. The polyphase fluid can be any type of fluid that includes one-phase components. water and an oil phase which are relatively immiscible. For example, polyphasic fluid may be production fluids 102 from an underwater well 104. Production fluids 102 may be hydrocarbon fluids, which include a mixture of natural gas, crude oil, brine, and solid impurities such as sand. Production fluids 102 may be obtained from subsea well 104 via any type of subsea production system (not shown) that is configured to produce hydrocarbons from subsea locations. A gas-liquid separation system 106 may optionally be used upstream to separate a gas stream 108 and a liquid stream 110.

In one exemplary embodiment, the production fluids 102 are separated into gas and liquid phases in a gas-liquid separation system 106. The gas stream 108 may be further processed by downstream equipment 112. Downstream equipment 112 may include, for example, any type of downstream gas processing equipment, such as a gas compressor, a gas treatment facility, gas refining device, or the like, or a gas pipe.

In the embodiments described herein, the liquid stream 110 may be flowed into a liquid-liquid oil / water separation system 114. The oil / water separation system 114 is a tube separator that is configured to achieve separation. by mass of the liquid stream 110 into an oil stream 116, a water stream 118 and, in some examples, an oil / water emulsion stream 120.

Within the polyphase separation system 100, the liquid stream 110 may be separated into separate streams 116, 118, 120, which may flow through a refining section until the streams blend into a control volume 122. A The control volume is used, for example, to achieve final phase separation and to keep the phases separated from oil and water, before substantially flowing oil through an oil outlet 124 and substantially water through a water outlet 126. The designs for the separation system 100, as well as the mechanisms by which the polyphase separation system 100 can affect the quality of the separated oil phase, water phase and oil / water emulsion, are described with respect to Figs. 3-8.

In some embodiments, the separation system oil 100 is drained off the top of the control volume 122 through the oil outlet 124. From the oil outlet 124, a substantially pure oil stream 128 can be processed by downstream equipment. Downstream equipment may include, for example, any type of processing equipment, such as an oil treatment plant, or an oil pipeline, among others. A portion of oil from oil outlet 124 may be recycled back to oil stream 116 upstream of control volume 122 as an oil recycle stream 132.

Water from the separation system 100 is drained out of the bottom of the control volume 122 through the water outlet 126. A portion of the substantially pure water stream 130 from the water outlet 126 may be recycled back to the water. water stream 118 as a water recycling stream 134, for example upstream of control volume 122. This may be useful for expelling sand and other sediment that may have accumulated at the bottom of the pipe separator through which the stream of water 118 flows.

Further treatment of each stream 116, 118 and 120 is possible upstream of control volume 122, and further treatment for substantially pure oil stream 128 and substantially pure water stream 130 is possible downstream. 122. For example, oil and water or coalescence pretreatment equipment, such as a heating system, a chemical injection system, an electrostatic coalescer, or the like, or an oil separation cyclone water, or liquid exporting pipes, could be used in addition to current separation techniques.

The block diagram of Fig. 1 is not intended to indicate that the polyphase separation system 100 is for including all components shown in Fig. 1. In addition, any number of additional components may be included within the system. polyphase separation 100, depending on the details of the specific implementation. For example, polyphase separation system 100 may be designed to achieve gas / liquid as well as liquid / liquid separation, with or without pretreatment, thereby substantially supplying pure oil, pure water, and pure gas streams. the downstream equipment. In addition, polyphase and liquid separators (not shown) may be placed upstream and / or downstream of polyphase separation system 100. In addition, polyphase separation system 100 may be considered a tubular, configured to flow a polyphase fluid. and obtain phase separation.

Fig. 2 shows an elevation drawing of an exemplary polyphase separation system 200. A polyphase fluid flows into polyphase separation system 200 on a distribution inlet line 202. Polyphase separation system 200 is split vertically. in a first divider 204 in a predominantly oil line 206 and a predominantly water line 208. The predominantly oil line 206 is vertically divided into a second divider 210 of the polyphase separation system 200 into a predominantly oil line 206 and an oil / water emulsion line 212. The predominantly oil line 206, predominantly water line 208, and oil / water emulsion line 212 may be of a diameter equal to or smaller than the distribution inlet line 202. For example, perforated deflectors 214 with a preselected open area can be used to balance the flow between lines 206, 208, and 212. Perforated baffles 214 are downstream of flow dividers 204 and 210. Perforated baffles 214 also act as downstream flow stabilizing devices of flow dividers 204 and 210. In order to balance flow and ensure sufficient residence time Within each line, a range of open areas may be used for perforated deflectors 214.

Following open tube sections 216 of polyphase separation system 200, lines 206, 208, and 212 enter control volume 220. A level detector 218, which can determine phase interfaces, such as an oil interface / water, an oil / emulsion interface, or an emulsion / water interface can be installed on the control volume 220. The level detector 218 can be configured to send, for example, gamma radiation through the control volume fluids. 220 in order to measure where the interfaces between oil, water and emulsion exist. This measurement indicates the amount of water and the amount of oil that is present within the control volume 220. The level detector 218 can be configured to send a signal to a controller (not shown) that can adjust control valves or speeds. (not shown) that are in the oil and water outlet lines. Control valves or pump speeds are configured to effectively control the flow rate of each line leaving the control volume 220.

A substantially pure oil stream 128 may be removed from the outlet 222 of the top of the control volume 220, while a substantially pure water stream 130 may be removed from the outlet 224 of the bottom of the control volume 220.

In another embodiment, the control volume 220 may be configured as a horizontal spherical or cylindrical separator (not shown). Additionally, the polyphase separation system 200 can be considered a tubular, configured to flow a polyphase fluid and obtain phase separation.

Fig. 3 is a top view of the exemplary polyphase separation system 300 illustrating a horizontal divider 304 in polyphase separation system 300. Polyphase separation system 200 may include a distribution input line 302 configured to feed polyphase fluid to separate lines 306 and 308. Dispensing inlet 302 may be coupled to a left line 306 and a right line 308, which are first horizontally divided into divider 304. Left line 306 and right line 308 may be parallel to the distribution input line 302. Flow in each line may be influenced by perforated baffles 310 installed within the lines. Subsequent lines (not shown) may be split vertically to achieve greater separation of the oil phase and water phase, to decrease their flow rates, and to be at different levels in control volume 312. In embodiments Alternatively, each of the horizontally divided lines 306 and 308 may be configured to feed an independent control volume, where each control volume could then be smaller than the volume of all mixed flow lines.

The polyphase separation system 300 divides the flow into lines 306 and 308 for the separation of oil, water and emulsion. Liquid degassing can also be performed on lines 306 and 308 or an earlier section, depending on the application. Downstream of lines 306 and 308 and following the mass separation of the oil and water phases, polyphase separation system 300 is connected to a plurality of vertically oriented dividers, which may be arranged at right or oblique angles, leading to a predominantly line. oil and a predominantly water line. The predominantly oil line is above the plane of the distribution inlet line 302, while the predominantly water line is below the plane of the distribution inlet line 302. An oil / water emulsion line can also be located between the upper and lower lines, and is not shown in Fig. 3. The planes of both lines 306 and 308 are substantially parallel to each other and to the distribution input line 302, for example, they lie in horizontal planes. This arrangement can achieve purer oil and water output quality by leaving the 300-phase separation system compared to a single line horizontal pipe separator. Left lines 306 and right lines 308 may be equal or smaller in diameter than distribution input line 302.

[0055] The scheme of Figure 3 is not intended to indicate that polyphase separation system 300 is for including all components shown in Fig. 3. In addition, any number of additional components may be included within polyphase separation system 300. depending on the details of the specific implementation.

Fig. 4 is a perspective view of another polyphase separation system 400 as described herein. In Fig. 4, a refinement section is located after the first level detector and before the control volume. The refinement section is discussed in more detail with respect to Fig. 5. In polyphasic separation system 400, the distribution inlet line 402 is divided into an intermediate line 404, where oil is the predominant phase, and a line 406, where water is the predominant phase. Intermediate line 404 can feed polyphase fluid into an upper line 405 and an oil / water emulsion line 408. Perforated baffles 410, or other flow control devices, may be inserted at various positions within each line in order to to balance the flow rate of fluid within a particular line. The upper line 405 may be in the background, which is above and substantially parallel to the plane occupied by the oil / water emulsion line 408. The lower line 406 may be below and substantially parallel to the plane occupied by the oil / water emulsion line. 408. In addition, the bottom line 406 can feed water and sand particles to a down pipe (described in more detail in Fig. 5).

A level detector 412 is configured to measure the phase interface levels between oil, water and emulsion components on each of lines 405, 406 and 408. The phase interface levels that are measured can be transmitted to a controller, which is configured to control downstream valves in the upper 405 and lower 406 lines. The valves are used to control flows entering control volume 422. In an exemplary embodiment, control volume 422 is a vertically oriented cylindrical structure. which is configured to flow substantially oil through an oil outlet 416, substantially water through a water outlet 418, and an oil / water emulsion through an optional emulsion outlet 420. In another exemplary embodiment, the volume of control 422 may be spherical in shape and polyphase separation system 400 may act as a pre-separator. In yet another embodiment, the control volume 422 may be a horizontal oil-water separator. Spherical and vessel-based control volumes can be used when internal and external pressures are not a significant limitation on the system.

The scheme of Fig. 4 is not intended to indicate that polyphase separation system 400 is to include all components shown in Fig. 4. In addition, any number of additional components may be included within the polyphase separation system. 400, depending on the details of the specific implementation. For example, the length of lines 405, 406 and 408 may be extended upstream of or within refinement section 502 of Fig. 5 to increase residence time and improve oil / water separation. This may allow the improvement or elimination of downstream separation steps and equipment. Near the end of polyphase separation system 400, flow will be directed to separate communication tubes through a 502 refinement section.

Fig. 5 is a side view of polyphase separation system 500, for example polyphasic separation system 400 of Fig. 4. In Fig. 5, refinement section 502 is enlarged and illustrated in more detail. Equal numbered items are as discussed with respect to Fig. 4. The fluid flowing from top line 405, bottom line 406, and oil / water emulsion line 408 passes through a level detector 412 and into section 505 top line fluid enters the refinement section 502 and partially flows through an optional dam 506. The top line dam 506 is configured to allow the less dense oil phase to flow above the 506 dam. denser water and oil / water emulsion phases accumulate against dam 506 and flow through a downpipe 504 and into oil / water emulsion lines 512 of refining section 502. a control valve 508 is configured to control upper line flow 405 upstream of control volume 422.

Another optional dam system 507 may be used on the bottom line 406 to allow the denser water phase to flow below the dam 506. The less dense oil and oil / water emulsion phases accumulate against the dam 507 and flow through a riser 510 and into the oil / water emulsion lines 512 of refinement section 502. Another control valve 508 is configured to control the flow of the lower line 406 upstream of control volume 422. Downpipes 504 between emulsion lines 512 are further configured to flow the denser water component to the lower emulsion line, and flow the less dense oil component to the upper emulsion line.

Refinement section 502 is configured to allow the oil phase to enter the top of control volume 422 and exit through an output 416 from the top of control volume 422. Refinement section 502 is also configured to allow that the water phase enters the bottom of the control volume 422, and exits through an output 418 from the bottom of the control volume 422. The refinement section 502 is also configured to allow the oil / water emulsion phase to enter the through the control volume 422, and exit through an optional output 420 from the middle of the control volume 422.

In one exemplary embodiment, control volume 422 is a vertically oriented cylindrical structure with inlets of each of the upper oil lines 405, lower water 406, and intermediate oil / water emulsion 512, as well as oil outlets 416. , water 418, and oil / water emulsion 420. The outlets may connect downstream refinement separation steps, for example, degreasing hydrocyclones.

[0063] To increase oil / water separation before fluid from each line is drained through refinement section 502, oil / water emulsion and oil lines can be equipped with optional electrostatic coalescing devices (not shown) for increased water droplet coalescence and oil / water separation. Oil, water, and oil / water emulsion lines can be equipped with internal coalescence and flow distribution, for example, plate packs, perforated deflectors, and the like, which increase droplet coalescence and oil / water separation. .

The oil and water level on each of lines 405 and 406 entering refinement section 502 can be controlled with control valves 508 to maintain the oil / water interface above or below dam height 506 to so that an insignificant amount of oil / water emulsion flows downstream through the lines. The oil / water emulsion may be forced to flow into a continuous oil emulsion line 512, a continuous water emulsion line 513, and an oil / water emulsion line 515. Emulsion lines 512, 513, 515 They are allowed to communicate with each other to allow free droplets to migrate to their respective phases via the descent tubes 504 and rise tubes 510.

Additional downpipes may be connected to the bottom line 406 as sand collectors 514 to capture sand that accumulates in polyphase separation system 400. Sand collectors 514 may be sealed by a sand shield (not shown). ). The sandblock can be configured with sand transport trim to allow a preset amount of sand to accumulate before the sandblock is emptied. Upstream of the sand shield, an optional sandblasting system may be activated to inject discharge water into the bottom line 406 of a recycling stream 516 at injection point 518. The sandblasting system may be used to blast the accumulated sand from bottom line 406 into a sand collector 514. In some embodiments, multiple sand collectors 514 may be used to capture sand from bottom line 406.

At the entrance to volume control 422, refinement section 502 will have separated the polyphasic fluid into three components, one predominantly upper 405 oil line, one predominantly lower 406 water line, and multiple intermediate lines 512, which are a oil / water emulsion. In this exemplary embodiment, the control volume 422 is vertically oriented.

Figs. 6A and 6B are a process flowchart of a method 600 for separating liquids within a polyphase fluid. In various embodiments, polyphase separation systems 200 and 400, discussed above with respect to Figs. 2 and 4, are used to implement method 600.

[0068] An optional gas-liquid separation process (not shown) can be used upstream of the current method. This separation step separates gases from the production fluid. Here, the polyphase fluid is flowed to the distribution inlet of a gas-liquid separation system. Polyphase fluid can be separated into gases and liquids within the gas-liquid separation system. The gas stream may be flowed above the liquid stream to a gas outlet. The gases are substantially separated from the liquid stream, and the liquid stream continues in the main process described below from block 602.

The method 600 begins at block 602, in which the polyphase fluid is flowed to a separation system manifold inlet. The polyphase fluid can be separated into vertically oriented distribution communication pipes, and flows into a predominantly oil line in block 604A, an oil / water emulsion line in block 604B, and a predominantly water line in block 604C.

The flow division of each line is controlled at 606A, 606B, and 606C, using, for example, perforated deflectors. Each line can flow through an open tube section of the separation system, indicated by blocks 608A, 608B, and 608C. The open pipe sections can be configured to allow a particular dwell time for the fluid in each line. A certain residence time may be used which provides the most effective separation in the open pipe sections of the polyphase fluid of the separation system.

In blocks 610A, 610B and 610C, level detection is performed by a level detector, which is configured to measure a phase interface on each line of the separation system. Oil, water, and oil / water emulsion levels, which are detected by the level detector, can be transmitted to a control system. In blocks 612A, 612B, and 612C, communication is made to a controller that is configured to energize a driven control valve. In blocks 614A, 614B, and 614C, the control valve is subjected to controller signals in communication with the level detector. At the entrance to the refinement section, the flow of each line is controlled by the control valves based on the controller signals communicating with the block level detector 616A, 616B, and 616C. Once oil, water, and oil / water emulsion levels are detected on each line by the level detector, the controller will receive signals corresponding to those levels, and the control valves will be activated accordingly.

In addition, the predominantly waterline can be equipped with optional sand guards, which are cylindrical volumes oriented perpendicular to the horizontal waterline for collecting and draining sand from the fluid produced on the lines. The waterline predominantly includes water and, to increase flow, this waterline may be equipped with recycle inlet streams or a sandblasting system to fluidize and blast sand into the sand guards. In block 618, the sand that accumulates in the waterline can be drained into the risers and effectively separated. Since this occurs on the predominantly water line, this can be accomplished without significantly disturbing the oil / water mass separation in the refinement section. Additionally, downstream sand handling systems, including the use of produced sand and water cyclones and an accumulation system, can be implemented to sandblast and other solid particles from the polyphase separation system. Sand guards can optionally be equipped with sand transport trim to fluidize and remove sand collected at the bottom of the guards.

In block 620, the oil, water, and oil / water emulsion lines of the polyphase separation system are drained to a control volume, where the oil, water, and emulsion interface levels are controlled. The oil, water, and emulsion are separated in the control volume. At 622A, 622B, 622C, the oil phase, water phase, and oil / water emulsion are separated using the method described herein. The sand, which accumulates in the polyphase separation system, is removed in block 624 by the techniques described herein.

The process flowchart of Fig. 6 is not intended to indicate that method steps 600 are to be performed in any particular order, or that all method steps 600 are to be included in each case. In addition, any number of additional steps, not shown in Fig. 6, may be included within method 600, depending on the details of the specific implementation.

Fig. 7 illustrates a block diagram of an exemplary polyphase separation system 700, and includes a control system. Production fluids 702 are flowed through a main inlet 704. The fluids are first horizontally split 706 and later vertically split 708 to achieve at least to some extent separation of oil, water and oil / water emulsion. to the three separate lines in the vertical plane. Flow can be adjusted on each line 710 using, for example, perforated deflectors, dam structures, valves, or pumps that create a marginal pressure drop on each line. Perforated deflectors are designed to distribute liquid flow evenly across a particular cross section, and to assist in the separation of 702 polyphase production fluids. Perforated deflectors can optionally be raised and lowered when coupled to exposure control gate valves. or adjust the open area of the deflector.

After each line extends through an open tube section, where the length of each open tube section is configured to obtain optimal fluid separation and residence time within the 700-phase separation system, the interface levels oil phase, water phase and oil / water emulsion are detected by a level detector 712. The flow of each line is then controlled 714 by transmitting the oil, water and oil / water emulsion levels when detected by the level detector, to a controller, which controls the downstream control valves. Control valves can be actuated 714 based on previous phase level detection by a level detector, thereby controlling the flow of each line within the refinement section. The purpose of the control scheme is to force the oil / water emulsion of each line into an intermediate section, thereby allowing greater separation of oil and water phases in 702 polyphase production fluids.

Following the refinement section, each line can be drained to control volume 716. Oil and water interface levels can be detected by a level detector at control volume 718. This level can be transmitted to a separate controller and subsequent control valves, or pumps, downstream of the control volume, which may be actuated to control the output of each line 722, 724, and 726 of the control volume. Additional steps in 720 include adjusting the height of a dam system that can be used upstream of the control volume to more effectively separate components from polyphase fluid. The dam system may be stationary or may be coupled to a gate valve system, and the dam height may be adjusted. In addition, a refining section with multiple downpipes and uppipes is an optional addition to aid in further separation before fluid within each line flows into the control volume.

[0078] The separation between the water and oil phases is kept within the control volume at 720. A level detector within the control volume detects the current oil and water level within the control volume. The volume of each phase within the control volume may vary depending on the oil / water interface level that is detected. Finally, the control volume is configured with a bottom water outlet 722, a top oil outlet 726 and optionally an oil / water emulsion outlet in the middle 724 of the control volume. The optional third oil / water emulsion outlet may be further processed downstream of the control volume to achieve the desired separation of oil and water phases.

Fig. 8 is a schematic view of a polyphase separation system 800 and control system 802. Control system 802 is configured to flow fluid from an oil inlet 804, a water inlet 806, and an inlet. oil / water emulsion 806 of the polyphase separation system 800 at a preferred speed. The 800-phase separation system 800 uses the 802 control system to send the control signals 810 and 812 to each of the 814 and 816 control valves, controlling the fluid flowing into the 800-phase separation system. The 802 control system can make part of a larger control system, such as a distributed control system (DCS), a programmable logic controller (PLC), a direct digital controller (DDC), or any other appropriate control system. In addition, the control system 802 can automatically adjust parameters via controller outputs 810 and 812, or it can provide information about the polyphase separation system 800 to an operator who then enters adjustments manually.

Control system 802 sends a signal 810 to control valve 814 to control the flow of oil section 818. Similarly, a control signal 812 is sent to control valve 816, which can adjust the speed. 820 water section flow rate. The oil / water emulsion flow 822 may optionally be controlled by a control valve (not shown) to control the flow of an 808 oil / water emulsion inlet. Another control signal 824 can be sent from level detector 826 to control system 802, which provides input to control system 802 to send signals 810 and 812 to control valves 814 and 816.

Control valves 814 and 816 are configured to regulate fluid velocity in oil section flow 818 and water section flow 820, which ultimately leads to a refinement section. Control valves can indirectly control the flow of oil / water emulsion section 822 of the refinement section. The interface level, for example between the oil and water phases or between an oil phase or a water phase and an emulsion phase, can be detected in sections 818 and 820 of the level detector 826, and the signal of 824 control can be sent to the 802 control system corresponding to the interface levels that are detected. Control system 802 is configured to control the flow of each section 818, 820, and 822 to a refinement section, with water and oil / water emulsion in the flow of oil section 818 being forced through downpipes to an intermediate section (not shown), and with oil and oil / water emulsion in the flow of water section 820 being forced through risers to an intermediate section (not shown). Control volume 828 is configured to substantially flow oil from an oil outlet 830 from the top of the control volume, substantially water from a water outlet 832 from the bottom of the control volume, and optionally an oil / water emulsion from a oil / water emulsion output 834 from the middle of the control volume.

It will be understood that the polyphase separation system 800, shown in Fig. 8, has been simplified to help explain various embodiments of the present techniques. Accordingly, in the embodiments of the present techniques, numerous devices, not shown or specifically mentioned, may still be implemented. Such devices may include flow meters, such as orifice flow meters, mass flow meters, ultrasonic flow meters, Venturi flow meters, and the like. Additionally, the flow at each output of control volume 828 can be controlled by subsequent process equipment (including pumps, through pump speed control, and control valves) located downstream of control volume 828.

Fig. 9 is a drawing illustrating the upper, middle and lower lines with injection points for sandblasting nozzles and recycling streams. Equal numbered items are as discussed with respect to Fig. 2. The injection points 902 of the sandblast nozzles and recycle streams may be installed in a line of the injection recycle system, which may be a part of the separation system. There may be a single nozzle for releasing a stream of fluid below a particular line, for example, recycled water from the control volume outlet may be recirculated to the predominantly water line 208 of Fig. 2. , to fluidize the accumulated sand in the polyphase separation system 200 of Fig. 2 and to blast the accumulated sand through downpipes into sand guards. Nozzles (not shown) can also be used for recycled flow to influence the flow of a particular line of the polyphase separation system 200 of Fig. 2. To limit the effect on oil / water separation, the recycling lines 904 906 and 908 can be configured to be outside the upper, middle and lower lines.

Figs. 10A and 10B are drawings illustrating the water line with a collection area at the bottom of the line for solid particles to accumulate. A perspective view, Fig. 10A, and a side view, Fig. 10B, of the sand accumulation system 1000 are shown. Waterline 208 of Fig. 2 has an additional bottom space 1002 configured to capture the sand. or other solid particulate matter 1004 which may settle from fluid 1006 flowing in the line.

[0085] A design may be implemented where a portion of the tubular wall is configured outward and follows the length of the line, for example in the general shape of a horseshoe or semicircle. Sand or other solid particulate matter 1004 may accumulate within the bottom area 1002, while fluid flowing within the line 1006 remains more or less constant. Sloped or vertical downpipes may be configured downstream of bottom area 1002 to capture sand or other solid particulate matter 1004 for removal. A sandblasting system and other fluidizing means may be installed on waterline 208 to increase flow and assist in blasting and fluidizing accumulated sand or other solid particulate matter 1004, thereby facilitating separation via downpipes.

[0086] Fig. 11 is a drawing illustrating an adjustable dam system 1100. The adjustable dam system 1100 includes an adjustable dam 1102 which is coupled via a coupling 1104 to a gate valve driver 1106. The adjustable dam 1102 is within a tube 1108. The floodgate valve driver 1106 may be manually or by a controller (not shown) to adjust the height of the adjustable dam 1102. The adjustable dam 1102 for an oil line is configured to allow that a less dense oil phase flows above the adjustable dam 1102, while the denser water or oil / water emulsion phase accumulates against the adjustable dam 1102 and flows through a down pipe and into the emulsion lines. oil / water content of the refinement section (not shown).

Similarly, an adjustable dam 1102 in a waterline can be configured to allow the denser water phase to flow below the adjustable dam 1102 while the less dense oil or oil / water emulsion phase accumulates. against the dam and flow through a riser and into the oil / water emulsion lines of the refinement section (not shown). Adjustable dam 1102 can be triggered manually or based off measurements from level detectors (not shown) that send signals to a controller. A controller of an exemplary control system (not shown) can control gate gate valve 1106, thereby adjusting the adjustable dam level 1102 based on a measured phase interface.

[0088] Fig. 12 is a drawing illustrating an adjustable deflector system 1200. Adjustable deflector system 1200 includes a perforated baffle 1202 coupled by a coupling 1204 to a 1206 gate valve driver. Perforated baffle 1202 is configured to be inserted. inside a 1208 pipe. The perforated baffle 1202 has multiple sections with different open areas. At one end of perforated deflector 1202, the open area may be low, while at the other end the open area may be high. The perforated deflector section 1202, which is inserted into the piping 1208, may be adjusted manually or by a controller (not shown) in communication with a flow meter (not shown) and the gate valve actuator 1206. 1206 gate valve can be configured to adjust the perforated baffle section 1202, which is inserted into the 1208 pipe, based on the measured flow rate of a particular pipe. Adjusting the perforated deflector 1202 in this way helps to ensure a more effective separation of oil and water phases from production fluids.

Although the present techniques may be susceptible to various modifications and alternative forms, the embodiments discussed above have been shown by way of example only. However, it should again be understood that the techniques are not intended to be limited to the particular embodiments described herein. Indeed, the present techniques include all alternatives, modifications, and equivalents within the true spirit and scope of the appended claims.

Fig. 13 is a side view of another embodiment of polyphase separation system 1300, for example, polyphase separation system 200 of Fig. 2 or 400 of Fig. 4. This embodiment of polyphase separation system 1300 employs comparatively close proximity of lines 405, 406, and 408, wherein lines 405, 406, and 408 are located substantially adjacent to each other without intervening parallel lines, tubes, or other conduits. The comparatively close proximity of lines 405, 406, and 408, which reduce the amount of recirculation of polyphase fluids, for example, in dividers 204 and / or 210 of Fig. 2, may be beneficial in reducing remixing and / or facilitating the mixing. phase separation at lines 405, 406, and 408. In Fig. 13, refinement section 1302 is enlarged and illustrated in more detail. Equal numbered items may be substantially the same as discussed with respect to Figs. 4 and 5. Topline fluid 405 enters refining section 1302. An oil communication tube 1350 is shown and can generally receive a stream containing substantially topline oil 405.

A dam 1310, for example, as shown in Fig. 15, may optionally be disposed on the upper flow line 405 to assist or otherwise stimulate upward oil flow into the oil communication tube 1350. When less dense oil accumulates against the barrier 1310, an increasing amount of oil may pass into the 1350 oil communication tube. A control valve 508 is configured to control the flow of the 1350 oil communication tube upstream. 422. Another optional dam 1312, for example, as shown in Fig. 15, may be used on bottom line 406 to assist or otherwise stimulate the denser water phase to flow into the water communication tube. 1360. Another control valve 508 is configured to control the flow of water communication tube 1360 upstream of control volume 422. An optional third dam 1314, for example as a Fig. 15, may be used over intermediate line 408, in addition to or instead of dam 1312, to assist or otherwise stimulate the denser water phase to flow to water communication tube 1360. Although dams 1310, 1312, and 1314 are represented as pluggable flange couplings, those skilled in the art will note that other dam connection mechanisms, eg welding in place, etc., are well known and may be suitably used within the scope. of this description.

A new lowering / rising pipe apparatus system 1304, 1306, and 1308, for example, as depicted and further described in Fig. 14, may optionally be employed to transfer water, oil, and / or emulsion between the parallel lines 405, 406, and 408 of refinement section 1302. In some embodiments, the adjacent solid plates of the descent / riser apparatus 1304, 1306, and 1308 are placed between flanged connections of polyphase separation system 1300.

Refining section 1302 is configured to allow the oil phase to enter the top of the control volume 422, and to exit through an oil outlet 416 from the top of control volume 422. The refinement section 1302 It is also configured to allow the water phase to enter the bottom of the control volume 422, and to exit through the water outlet 418 from the bottom of the control volume 422. The refinement section 1302 can also be configured to allow the oil / water emulsion phase enters the middle of the control volume 422, and exits through an optional emulsion outlet 420 from the middle of the control volume 422.

Fig. 14 is a perspective diagram of the down pipe apparatus 1304, 1306, and 1308, which may then be referred to individually as a down pipe or a down pipe apparatus. Drop / rise pipe apparatus 1304, 1306, and 1308 may be useful for reducing remixing in the refinement section, for example, due to open communication between the oil, emulsion, and water (e.g. on lines 405, 406, and 408 of polyphase separation system 400 of Fig. 4). Down / up pipe 1304 may allow oil to pass from the lower line 406 and / or intermediate line 408 to the upper line 405 via riser tube (s), operatively coupling a portion of the line containing the ( oil phase (s) (eg, a region above the oil / water interface) of the bottom line 406 and / or the intermediate line 408 and that of the top line 405. Down / Up line 1304 may allow water to flow from the upper line 405 and / or the intermediate line 408 to the lower line 406 through the down pipe (s), operatively coupling a portion of the line containing the phase (s) ) (eg, a region below the oil / water interface) of the upper line 405 and / or the intermediate line 408 to that of the lower line 406. The down / up pipe 1304 is configured to prevent or at least least substantially inhibit all other fluid exchanges between lines 405, 406, and 408 by means of plates adjacent solids, which reduce the remix in the refinement section. The descent / rise pipe 1306 may function substantially the same as the descent / rise pipe 1304, with the exception of the amount of oil and / or water passable through the fall / rise pipes 1306 of the passages operably coupled to intermediate line 408. , which may have a smaller diameter (and thus allow comparatively less flow) than the diameter of the descent / rise pipe 1304 of the corresponding passages operably coupled to intermediate line 408. This configuration can accommodate relatively larger amounts of oil, water, and / or emulsion being passed from intermediate line 408 to upper line 405 and / or lower line 406 at a location further upstream of the refinement section (e.g. via down / up line 1304 as shown in Fig. 13), and relatively smaller amounts of oil, water, and / or emulsion, being passed from intermediate line 408 to upper line 405 and / or lin. below 406 at a location further downstream of the refinement section (e.g. via down / up pipe 1306 as shown in Fig. 13). The descent / rise pipe 1308 is configured to allow oil to pass from the lower line 406 to the upper line 405 by operatively coupling a portion of the line containing the oil phase (s) (e.g. above the oil / water interface) of the lower line 406 and that of the upper line 405, and permit the passage of water from the upper line 405 to the lower line 406 by operatively coupling a portion of the line containing the phase (s) ( (s) a region below the oil / water interface) of the top line 405 than that of the bottom line 406. The down / up line 1308 is configured to prevent, or at least substantially inhibit, all other fluid exchanges between lines 405, 406, and 408 by means of adjacent solid plates. Those skilled in the art will appreciate that alternative embodiments of polyphase separation system 1300 may optionally utilize any of the descent / riser tube apparatus 1304, 1306, and 1308 at any suitable location (s) of the refinement section 1302 of Fig. 13; other embodiments may omit one or more of the descent / riser tube apparatuses 1304, 1306, and / or 1308, reconfigure the descent / riser tube apparatuses 1304, 1306, and 1308, and / or add multiple descent tube apparatuses. / rise of a similar design to achieve the desired operating characteristics within the scope of this description.

In addition, one or more of the descent / riser apparatus 1304, 1306, and 1308 may be constructed into two corresponding separate, reciprocal, mirrored, and / or duplicate parts (e.g., as one or more vertical passages affixed to a solid through plate) and coupled to form a single unit. When coupled, any such down / up piping arrangements need not be welded or otherwise adjusted pressed, such as to prevent all fluid changes, but should generally be configured to at least substantially prevent substantial deviation around the piping unit. descent / ascent. Fall / rise pipe apparatus 1304, 1306, and 1308 of the described embodiment are designed to couple to a flange location, but other embodiments may utilize unitary or other non-flange-based designs to realize the equivalent (). s) function (s) as described above. Such alternative embodiments are considered within the scope of this disclosure. Additionally, some descent / riser tube embodiments may include a dynamic functionality, wherein one or more oil, water, and / or emulsion passageways are configured to offset or accommodate a changing oil / water interface level. Some such embodiments may be automatically controlled, for example by a computer controller coupled to a level detector 412, other embodiments may include a flotation mechanism, which causes individual riser or lower tube passages to rise and fall. / or fall with the changing oil / water interface level, and other embodiments include a mechanical unit allowing operators to manually raise or lower the passage (s) based on differences in operating characteristics of the 1300 polyphase separation system .

Fig. 16 is a side view schematic diagram of another embodiment of a polyphase separation system 1600. Equal numbered components may be substantially the same as those of polyphase separation system 1300 of Fig. 13 except that of another embodiment. indicated mode. The 1600 polyphase separation system has a 1602 water outlet isolated from the 422 control volume. The 1602 water outlet can be beneficial at higher water flow rates, where the speed near the bottom of the 422 control volume would be otherwise. too high, for example, by causing the emulsion to be rearranged into the water outlet. The 1600 polyphase separation system also has an optional emulsion output 420 over control volume 422. In some embodiments, the optional emulsion output 420 may prevent water from accumulating behind a dam of the water communication tube, for example, dam 1312 due to stagnation of the emulsion layer and accompanying separation.

Claims (25)

1. A polyphase separation system (100, 200) comprising: a distribution line (202) configured to feed a polyphase fluid into feed lines within the separation system, wherein the feed lines consist of an upper line ( 116, 206), an intermediate line (120, 212), and a lower line (118, 208), characterized in that; the upper line, configured to flow a first oil-containing stream (116) to an oil section of a control volume (122, 220); the intermediate line, configured to flow a second stream (120) containing oil / water emulsion to an oil / water emulsion section of the control volume; the bottom line configured to flow a third stream (118) containing water to a water section of the control volume; and the control volume, configured to adjust the fluid flow rate at an outlet, where each of the oil section, water section, and oil / water emulsion section mix at different heights of the control volume. . Polyphase separation system according to claim 1, characterized in that the separation system is implemented within an underwater environment, and the polyphase fluid comprises production fluids from an underwater well, Polyphase separation system according to claim 1, characterized in that the upper line, intermediate line, and lower line are parallel to each other and perpendicular to the control volume. Polyphase separation system according to claim 1, characterized in that the flow rate at a control volume inlet is adjusted by the use of a control valve (508) from the upper line upstream of the control volume. and a control valve (508) of the lower line upstream of the control volume, Polyphase separation system according to claim 1, characterized in that the control volume is configured to flow fluid at a top outlet (124, 222) of the control volume, and wherein the fluid flow from the control volume is Top output of the control volume comprises substantially oil. Polyphase separation system according to claim 1, characterized in that the control volume is configured to flow fluid at a bottom outlet (126, 224) of the control volume, and wherein the fluid flow from the control volume is Bottom output of the control volume comprises substantially water. Polyphase separation system according to claim 1, characterized in that the control volume is configured to flow fluid at an outlet (420) from the middle of the control volume, and that the fluid flow from the control outlet One half of the control volume comprises an oil / water emulsion. Polyphasic separation system according to claim 1, characterized in that it further comprises a flow regulator in the upper, intermediate and lower line and wherein the flow regulator comprises a perforated deflector (214); an adjustable perforated deflector (1200), a gate valve (1106) or a combination thereof. Polyphase separation system according to claim 8, characterized in that it comprises: a control system configured to adjust the open and closed flow regulator; a level detector (218) coupled to the top line, intermediate line, or bottom line, wherein the level detector is adapted to measure a water and oil phase interface level present in a line. Polyphase separation system according to claim 1, characterized in that the upper line, intermediate line, lower line, or any combination thereof is further configured for a chemical additive to be injected. Polyphasic separation system according to Claim 10, characterized in that the chemical additive which is injected comprises defoamers or demulsifiers. Polyphase separation system according to claim 1, characterized in that any of the upper line, intermediate line, or lower line is coupled to an electrostatic coalescer. Polyphase separation system according to claim 1, characterized in that any of the upper line, intermediate line, or lower line, or any combination thereof, is configured with droplet coalescing internals. Polyphase separation system according to claim 1, characterized in that it comprises: a lowering pipe (514) coupled to the lower line, wherein the lowering pipe is sealed by a sand guard, and wherein the Sand protector is configured with trim to fluidize and remove sand that has accumulated in the sand protector; or a recycling line (134, 516) coupled to the bottom line, wherein the recycling line is configured to fluidize and remove accumulated sand, and wherein the recycling line is configured to be outside the oil section, section or the oil / water emulsion section. Polyphase separation system according to claim 1, characterized in that a pre-separator is used upstream of the separation system, and wherein the pre-separator is configured to separate gas from polyphase fluid. Polyphase separation system according to claim 1, characterized in that an output (418) of the control volume is configured for recycling upstream of the upper line, intermediate line, or lower line. Polyphase separation system according to claim 1, characterized in that it comprises a refinement section (502), wherein a lateral extraction (504) is coupled from the upper line to the intermediate line, and a lateral extraction (510 ) is coupled from the midline to the bottom line. Polyphase separation system according to claim 1, characterized in that it comprises: a first downpipe / downpipe apparatus (1304) configured to allow oil to pass from the bottom line, intermediate line or both to upper line, wherein the first downpipe / downpipe apparatus is further configured to allow passage of water from the upper line, intermediate line or both to the lower line, and wherein the first downpipe apparatus descent / descent tube is further configured to substantially inhibit all other fluid exchange between the upper line, the intermediate line and the lower line; a second downpipe / downpipe apparatus (1308) configured to allow oil to pass from the lower to the upper line and to allow water to pass from the upper to the lower line, wherein the second downpipe apparatus descent / descent tube is further configured to substantially inhibit all other fluid exchange between the upper line, the intermediate line and the lower line; or both the first downpipe / downpipe apparatus and the second downpipe / downpipe apparatus. A method for separating oil and water and emulsifying oil / water within a polyphase fluid, comprising: flowing a polyphase fluid into a distribution inlet (202) of a polyphase separation system (100, 200); separating the polyphase fluid into an oil phase, a water phase, and an oil / water emulsion; and characterized in that it separates the oil phase in a line (116) which is in a plane vertically above the distribution inlet plane; separating the water phase into a line (118) that is in a plane vertically below the distribution inlet plane; separating the oil / water emulsion into a line (120) that is in a plane vertically above the line plane with the water phase and vertically below the line plane with the oil phase; flow each line to a vertically oriented control volume (122, 220), wherein the flow rate of each line is controlled; detect an oil level and a water level in each line; transmit with a controller to open and close control valves (508) based on the detected oil and water level; and separating each phase by flowing the oil phase, water phase, and oil / water emulsion through a different outlet (416, 418, 420) of the control volume. Method according to claim 19, characterized in that it comprises regulating the flow rate of the fluid in a line by using perforated deflectors (214) by adjusting an adjustable perforated deflector (1200) by use of a gate valve (1106) or any combination thereof. The method of claim 19, further comprising injecting chemical additives into the oil line, water line, and oil / water emulsion line. A method according to claim 19, further comprising: accumulating sand in an additional hollow space (1002) water line; and purify sand from the waterline. A method according to claim 19, further comprising removing dispersed droplets from the mass phase by flowing into an oil line, water line, oil / water emulsion line in a refinement section (502). upstream of the control volume. A method according to claim 19, further comprising recycling the fluid from the upstream control volume in the polyphase separation system. Polyphase separation system according to Claim 1, characterized in that the control volume is configured as a horizontal spherical or cylindrical polyphase separator.