RU2531984C2 - Separation of oil, water and solids in well - Google Patents

Abstract

FIELD: oil-and-gas industry.

SUBSTANCE: set of inventions relates to in-well hardware and methods of in-well separation of fluids and solids as well as to preparation of well fluids and solids separation system. In-well device comprises separation system with separator including well fluid inlet, oil light channel, water flow channel, solids channel and detachable flow constrictor arranged in solids channel to facilitate separation of well fluid.

EFFECT: facilitated separation of well fluids and solids and their processing.

20 cl, 10 dwg

Description

BACKGROUND

Oil production from a well may include pumping a wellbore fluid consisting of a portion of water and a portion of oil, i.e., an oil-water mixture. When an oil well is depleted, a larger percentage of water is present, which is then supplied to the surface. Formation water can sometimes make up more than 80% of the total volume of the supplied well fluid, which leads to the need to solve complex operational issues. For example, formation water may require treatment and / or reverse injection into an underground formation reservoir in order to utilize water and maintain reservoir pressure. Treatment and disposal of produced water can be costly.

One way to solve these issues is to use a downhole device to separate oil and water and reverse injection of the separated water into the reservoir, which minimizes the flow of unwanted water to the surface. Reducing the amount of water supplied to the surface can reduce the required power, reduce hydraulic losses and simplify ground equipment. In addition, many of the costs associated with water treatment are reduced or eliminated.

However, the successful separation of oil and water inside the well and then the reverse injection of water is a relatively complex and sensitive process with many variables and factors that affect the efficiency and feasibility of such an operation. For example, the ratio of oil to water can vary from well to well and can have a significant effect on the life of the well. The required injection pressure can also affect the life of the well. For example, the required discharge pressure for separated water tends to increase over time.

Additional problems arise when the wellbore fluid contains solids, such as sand and other particles, which are sometimes mixed with the wellbore fluid. Solids are generally heavier than oil and tend to separate with water. However, the presence of solids in the water stream can cause complications inside the well, such as clogging. In some cases, solids are separated from the flow of injected water and may clog the back pressure sites. The proportion of solids in the well fluid or water may also change over time, which causes great difficulties in handling solids within the well.

SUMMARY OF THE INVENTION

A system and method for separating liquids and solids and for processing separated solids inside the well have been created for separating oil, water and solids inside a well. To do this, a separation system is used, having a separator with an inlet for well fluid, an outlet for oil flow, an outlet for water and an outlet for solids. The separator acts to separate the wellbore fluid into substantially oil, water, and solids, and direct these components into respective channels. In conjunction with the separator, a flow restrictor may be used, which facilitates the separation of the components of the well fluid.

BRIEF DESCRIPTION OF THE DRAWINGS

Some embodiments of the downhole separation of oil, water and solids will now be described with reference to the accompanying drawings, in which like numbers indicate like components, with the drawings showing the following:

in FIG. 1 is a front view of a well system using an electric submersible pump system in conjunction with a separation system according to an embodiment;

in FIG. 2 shows a cross section of an example of a separation system according to an embodiment;

in FIG. 3 is a cross-sectional view of a portion of a well system depicting one example of a flow restrictor according to an embodiment;

in FIG. 4 shows a cross section similar to that of FIG. 3, but showing a flow restrictor removed from a portion of the well system according to an embodiment;

in FIG. 5 is a front view of another example of a downhole system in combination with a separation system according to another embodiment;

in FIG. 6 is a cross-sectional view of one example of a redirector that can be used with a downhole system according to an embodiment;

in FIG. 7 shows a cross section of a redirector in combination with a flow restrictor for use in a well system according to an embodiment;

in FIG. 8 is a cross-sectional view of an example flow restriction system that can be used with a well system in accordance with an embodiment;

in FIG. 9 is a cross-sectional view of a flow restriction system comprising a sensor or sensors, according to an embodiment; and

in FIG. 10 is a cross-sectional view of another example of a separation system in which a wellbore fluid is divided into three components that mainly comprise oil, water, and solids, respectively, according to an embodiment.

DETAILED DESCRIPTION OF THE INVENTION

The following description provides details that help to understand the essence of this invention. However, it will be understood by those skilled in the art that the present invention may be practiced without these details and that numerous changes or modifications are possible to the described embodiments.

In this description and the attached claims: the terms "up" and "down", "upper" and "lower", "upward" and "downward", "upstream" and "downstream", " above "and" below "and other similar terms indicating relative positions above or below a given point or element are used in this description to more clearly describe some embodiments of this invention. However, when applied to equipment and methods of use in wells that deviate from the vertical or are horizontal, such terms may mean “left to right,” “right to left,” or other relationships as appropriate.

The described embodiments generally relate to artificial lift systems, for example, artificial lift systems for hydrocarbon wells. Embodiments include systems and methods for separating wellbore fluid components such as oil, water, and solids. For example, one embodiment relates to downhole separation of oil, water, and solids, and to controlling backpressure to influence the separation of components of a wellbore fluid. One way to control the separation of oil and water, for example, is to control the back pressure applied to the oil stream and / or water stream. The back pressure can be controlled by adjusting the flow restriction in order to cause the desired change in the oil flow and / or water flow exiting from the separator of the well fluid components. In addition to separating the components of the well fluid, embodiments of the invention relate to equipment designed to provide the desired control, i.e. back pressure, applied to the effluent. The magnitude of such regulation can vary from full closure (no flow) to full open (full flow), depending on the content of oil, water and solids in the well fluid.

The control of the back pressure and its associated flow can significantly depend on the orientation of the injection zone with respect to the productive zone (injection zone higher in the wellbore or lower in the wellbore from the productive zone). Some of the differences between the two orientations relate to upstream injection, when the device can regulate and divert flow into the annulus of the tubing in one operation, and downstream injection, when the device may need to control flow " along the observation line ”, that is, in receiving the injection flow from the discharge pipe, regulating the flow and then returning this flow to another pipe directed to the discharge zone. In some cases, the diameter of the adjustable passage or bore of the flow restrictor may vary from about 0.125 inches to 1.0 inches.

In FIG. 1 shows a borehole system 20 deployed in a borehole 22. In this embodiment, the borehole system 20 includes an electric submersible pump system 24 having a submersible motor 26 and a submersible pump 28 driven by a submersible motor 26. The electric submersible pump system 24 may include a number of other components, such as a pump inlet 30 and a motor protection device 32. In addition, the shown well system 20 further comprises a separator 34, for example, a centrifugal separator or a cyclone separator, for separating the components of the well fluid. For example, the separator 34 may be designed to separate components, for example, oil and water, liquid and solid components, for example, water and particles, or other combinations of components, for example, oil, water and solids. The separator 34 may be included in the borehole system 20 at various places, such as the location shown above the submersible pump 28. However, to limit the flow of solids through the pump 28, the separator 34 may also be located upstream of the submersible pump 28.

In the shown example, the borehole system 20 is placed inside a hydrocarbon well, for example, inside a casing 36 of a well. After placing the system at the desired location inside the well, submersible motor 26 can be powered to drive both the submersible pump 28 and the separator 34. During operation of this embodiment, the well fluid through the inlet 30 enters the pump 28 and is pumped to the separator 34 The separator 34 accelerates the borehole fluid mixture and drives it in a circular path, thereby using centrifugal forces to place denser materials, such as water and solids, in more distant radii lnyh positions, and less dense fluids, e.g., oil, - at positions closer to the center of rotation. In this example, the oil stream and the water stream exits the separator 34 and passes separately along various paths to the redirector 38, which redirects the water stream and pumps it into the surrounding formation, while directing the oil flow up the wellbore through, for example, pipe 40 to the place collection on the surface. The separator 34 may be designed to separate oil, water and solids (see Fig. 10), in which case the solids component of the well fluid is guided by a redirector 38 to the desired location. It should be noted that the separator 34 can be used in various places with or without redirector 38. For example, the separator 34 can be used to separate oil, water and solid particles and then combine the solid particles with the oil stream again to supply the desired collection point to the surface, which avoids clogging of the water injection zone.

References to water streams, oil streams, and / or solid particle streams exiting separator 34 refer to streams having, respectively, significant concentrations of water, oil, and solids. In other words, the respective streams may contain portions of other components of the well fluid and may not be pure in the sense that they contain exclusively water, oil or solids. Depending on the specific application, the downhole system 20 may include various other components, such as packers 42 and 44.

In FIG. 2 is a cutaway view of one example of a separator 34, which in this case is a centrifugal separator. The borehole fluid mixture is fed through the borehole fluid inlet 45 of the separator 34 into the working area or separator chamber 46, for example, the cyclone chamber of the separator 34. The components of the borehole fluid are separated by a divider 48, which has channels or passages for moving the separated components of the borehole fluid from the working area 46 separator. For example, these passages may include a path or channel 50 for oil and a path or channel 52 for water, which serve as the outlets from the chamber 46 of the separator. Divider 48 may also separate the wellbore fluid into additional components, such as solids, which are supplied through a separate path or channel for solids. As shown, the oil channel 50 is located deeper inside in the radial direction relative to the channel 52 for water. To influence the separation process, backpressure can be selectively applied to flows of oil, water and / or solids. For example, backpressure on a water stream through a water channel 52 can improve separation results when separating a wellbore fluid having a high percentage of oil. For a wellbore fluid having a higher percentage of water, a higher backpressure for oil flow through the oil channel 50 can similarly improve the separation of oil and water. Typically, the same backpressure principle applies to cyclone or centrifugal separators.

In FIG. 3 shows a cross section of another type of separation system 54, wherein the separator 34 separates the components of the well fluid into flows flowing, for example, through an oil channel 50 and a water channel 52. It should be noted that the separator 34 can also be designed to separate solids, which are then sent through a separate channel, as described in more detail below. In FIG. 3 arrows 56 show the oil flow path, and arrows 58 show the water flow path. In this example, a flow restrictor 60, such as a control component, is located in the water passage 52. However, another flow restrictor 60 may be placed in the oil channel 50 or an additional flow restrictor 60 may be placed in the oil channel 50, so that the flow restrictors will be in the water channel and in the oil channel. In this embodiment, the water stream 58 flows up the wellbore into the flow restrictor 60.

The flow restrictor 60 can be selected from a number of different types of flow restrictors, one example of which has an element with a flow passage 62 through this passage or channel 64. The size of the passage 64 can vary, and the configuration of the flow restrictor 60 and the element with a passage 62 allows you to adjust the back pressure in the water stream 58. For example, the flow restrictor 60 may be a removable flow restrictor, which allows replacement with other flow restrictors 60 having a different control iruemost, e.g., a flow control member 62 through the opening 64, which has a different size for adjusting the back pressure. In other embodiments, an element with a through hole 62 is removable and may be replaced by other elements 62 having through holes 64 of other sizes. The flow restrictor 60 and / or element 62 can be replaced with a tool 66 that can be lowered into the well to accommodate and / or remove the flow restrictor 60 and / or element 62. For example, the tool used to replace this device may comprise a tool, lowered on a rope, cable, flexible tubing of small diameter or using other suitable means of transportation 68. In some cases, a cable rope may be the most economical means of transportation to change regulation. In the example shown in FIG. 3, the oil channel 50 may be positioned or configured so that tools lowered by the conveyance means 68 cannot inadvertently enter the oil channel 50. For example, the oil channel 50 may have a cranked portion 70 to prevent the tool 66 from entering this channel or the channel may be of such a size that the tool 66 cannot enter the channel.

In some cases, the flow restrictor 60 comprises an element 62 having an adjustable, variable-sized passage 64, so that changing the size of the passage 64 does not require replacement of the flow restrictor 60. For example, the size of the passage opening can be adjusted mechanically on the surface or with a tool 66 lowered using transport means 68, for example, a wire rope, cable, small diameter flexible tubing. In other cases, the element 62 may have an adjustable bore 64, which is regulated by hydraulic pressure directed down the wellbore through a hydraulic line, or by an electric motor controlled by electrical signals from the surface or a controller located inside the borehole.

As further shown in FIG. 3, shutoff valves 72 are located in the oil channel 50 and / or in the water channel 52. Shut-off valves 72 may be used to prevent fluid from returning from the oil channel 50 and the water channel 52 to the separator 34. Blocking this possible backflow by the shut-off valves 72 prevents damage to the separator 34.

In FIG. 1 shows that packers 42 and 44 can be used to isolate portions of a wellbore along a borehole system 20. For example, the shown packers 42 and 44 isolate the area where water is to be re-injected into the nearest formation redirector 38 from the area where the well fluid enters from the formation below the bottom packer 44. The packer configuration effectively isolates the pump inlet 30 from the fluid back injected into the formation. Alternatively, the packer 44 may be located below the submersible pump 28 so that water is pumped back into the formation above the packer 42 or below the packer 44, which properly isolates the produced wellbore fluid zone from the formation zone where the water is pumped. Various packer configurations can be used to create insulation between reservoir fluids and injection fluids.

In addition, the borehole system 20 may be adapted to inject fluid into the formation to enhance flow within the borehole. For example, in the embodiment shown in FIG. 4, the separation system 54 is similar to the system shown in FIG. 3, except that the flow restrictor 60 is removed. In the configuration of FIG. 4, injection into the formation for stimulation of the inflow can be carried out through pipe 40 both to the oil channel 50 and to the water channel 52. The flow restrictor 60 can be replaced by a flow control device that prevents the fluid used to stimulate the flow to follow the path of the water injected into the formation. For example, arrow 74 shows the injection path into the formation to stimulate flow. The shutoff valves 72 prevent the fluid used to intensify the influx from entering the separator 34, thereby avoiding the negative effects of this fluid on the separator.

In FIG. 5 shows another configuration in which water is back-injected into a desired injection zone 76, below productive zone 78. The submersible motor 26, pump 28 and separator 34 can be connected in a manner similar to that described with respect to FIG. 1, and the redirector 38 is connected upstream of the borehole from the separator 34. The redirector 38 is connected to a channel 80, which passes down the borehole, for the redirected fluid to pass through the lower packer 82. The lower packer 82 separates the production zone 78 from the injection zone 76 located below packer 82. In this embodiment, a water stream passes through channel 80 and through subpacker pipe 84. Subpacker pipe 84 passes through lower packer 82 into discharge zone 76, thereby allowing the water component to be pumped back.

In FIG. 6 shows a more detailed cross-section of an embodiment of the redirector 38. Similarly to FIG. 7 shows a more detailed cross-section of an embodiment of a redirector 38 in combination with a flow restrictor 60 located in a pocket 86 of the flow restrictor. The flow limiter pocket 86 is designed to accommodate the flow limiter 60. In this specific example, the water channel 52 is located radially from the outside of the oil channel 50, based on the centrifugal separation of oil and water. The oil channel 50 passes from the downhole redirector 38 through the redirector and up the wellbore past the redirector until it is connected to the pipe (s) 40, for example, a production tubing / small diameter flexible tubing. A water channel 52 extends from below the redirector 38 to the redirector 38. The water channel 52 is connected to the water channel 88, which connects the water channel 52 to the flow limiter pocket 86. In the shown embodiment, the water channel 88 extends in a direction substantially perpendicular to the water channel 52, so that the water flow passes through a sharp turn, for example, a 90 ° turn. However, the rotation angle may vary and in some cases may be less sharp, for example 45 °, or sharper, for example 135 °. A reverse injection channel into the formation 90 connects the pocket 86 of the flow limiter and the corresponding channel, for example, channel 80, to direct the water component of the well fluid into the desired injection zone 76.

In FIG. 8 shows an embodiment of a flow restrictor 60. In this embodiment, the flow restrictor 60 comprises a housing 92 that has an upper inner chamber 94 and a lower inner chamber 96. The upper inner chamber 94 and the lower inner chamber 96 are separated by a flow restriction device, such as element 62, having a flow channel / passage 64, thanks to which the fluid flow is regulated. The element 62 and the body of the flow restrictor 92 may be one part or two different parts that are matched to each other. The entire flow restrictor 60 and / or flow element 62 may be stationary or removable depending on the practical application of downhole fluid separation.

In the shown embodiment, the passage hole 64 for restricting the flow of the element 62 has a smaller diameter than the diameter of the upper inner chamber 94 or the lower inner chamber 96, however, the diameter of the passage 64 can be almost the same as the diameter of the upper chamber 94 or the lower chamber 96. In addition in addition, one or more channels 98 are located in the body 92 of the flow limiter and hydraulically connect the upper chamber 94 with an area external to the flow restrictor 60. Another channel 100 is located at the downhole end of the flow restrictor 60 and provides a flow path that allows communication with the lower part of the element 62 through the lower inner chamber 96.

When the flow restrictor 60 is placed inside the flow limiter pocket 86, the channels 98 allow fluid to pass from the water channel 88 through the channels 98 to the upper inner chamber 94. Then, the fluid enters through the passage 64 of the element 62 into the lower inner chamber 96. From the lower inner chamber 96 a fluid, for example water, passes through a channel 100 from a flow restrictor 60 for reverse injection to a desired zone, for example, to a discharge zone 76. To form a seal with the inner surface of the pocket of the flow restrictor 96, several seals 102, for example, o-rings, may be installed near the housing 92. In a number of cases, the flow restrictor 60 may be removable. Additionally or alternatively, the element 62 can be designed as interchangeable or adjustable, which allows you to adjust the size of the flow channel 64. It should be noted that the flow restrictor 60 may have many internal configurations that allow you to obtain the required restriction / regulation of fluid flow to facilitate separation of components downhole fluid.

If the flow restrictor 60 is removable, it may include a fastener 104 designed to facilitate engagement with the tool 66 for placement and removal in relation to the pocket 86 of the flow limiter. As noted previously, the tool 66 can be connected to various means of transportation 68, for example, a hoisting rope, cable or small tubing flexible tubing.

In many cases, the separation methods used and the selectable flow restrictor depend on the parameters and characteristics associated with the well fluid, for example, the composition of the well fluid. For example, knowledge of the composition of the wellbore fluid may be useful in determining appropriate methods for separating, producing, and reversing the injection of various components of the wellbore fluid. In some cases, the sensor 106 may be located inside the borehole to detect selected parameters of the wellbore fluid, such as the ratio of oil, water and solids in the wellbore fluid, as shown in FIG. 9. Data from the sensor 106 can be transmitted up the wellbore in many ways, for example, using electrical signals through a wire, fiber optic signals, radio signals, acoustic signals, wireless transmission technologies, and other methods of transmitting the corresponding data. Alternatively, signals may be transmitted to the downhole processor 108. The downhole processor 108 may be used to provide instructions to, for example, an engine coupled to element 62, to define a specific hole size, or to perform other downhole functions. Depending on the practical application, the sensor 106 may be located downstream of the inlet of the well fluid separator 34, inside the separator 34, the redirector 38, the flow restrictor 60, from the outside of the separator 34 and down the wellbore from the well fluid inlet 30, from the outside separator 34 and upstream of the inlet 30 from the outside of the separator 34 and at the same level as the inlet 30 for the downhole fluid, upstream of the inlet 30, upstream of the separator or at other suitable locations.

In FIG. 9 shows an example of a flow restrictor 60 having a sensor 106 located in the upper inner chamber 94. In another embodiment, the sensor 106 may be in the lower inner chamber 96; or several sensors 106 may be located in the upper inner chamber, the lower inner chamber, and / or in other desired places. Depending on the need for obtaining well fluid information, the sensor 106 may be designed to determine various parameters, such as temperature, flow rate, pressure, viscosity, oil to water ratio, or other desired parameters. Additionally, the sensor or sensors 106 may be used in conjunction with a remote sensor 110 that integrates with a redirector 38 or other suitable component of the borehole system 20. The sensor 106 may transmit information to the downhole processor 108 or other suitable data acquisition system through an appropriate telemetry system, such as an electrical contact system telemetry system or short-hop system. As described above, the information received from the sensor 106 can also be used to adjust the size of the passage 64. For example, the element 62 may include a control mechanism 111 that is mechanically, hydraulically, electrically, or otherwise adjusted. For example, the tool may be lowered on a suitable transport means 68 to mechanically influence the adjusting mechanism 111, resulting in a change in the size of the passage 64.

In FIG. 10 shows yet another embodiment of a separator 34 and a separation system 54. In this embodiment, the separator 34 is for separating the wellbore fluid into additional components. For example, the separator 34 may be designed to separate the wellbore fluid into oil, water, and solids, such as particles, to provide positive separation and production results. The most important factor for the successful application of downhole fluid separation technology in the long term is to maintain injectivity in the injection zone, for example, in zone 76. During well operation, the decrease in injectivity can be caused by the transfer of solids, for example particles, to the injection zone, for example, into the zone 76, after separation of oil and water. The accumulation of solids on the exposed surface in the sand formation of the injection zone can reduce the throttle response. Maintaining the injectivity coefficient as close as possible to the initial injectivity coefficient and for as long as practicable may be appropriate for continuous operation of downhole fluid separation systems. Mining can be improved either only by limiting the amount of solids deposited in the pressure zone, or in combination with an intensifying effect on the pressure zone.

An embodiment of the separator 34 shown in FIG. 10 is intended to provide an additional solids removal flow. This stream can be used to direct solids away from water injection zone 76. In some cases, the solids discharge stream can be reconnected with the oil component extracted from the wellbore fluid to provide an injected water stream relatively free of solids.

As indicated above with respect to the separator 34, the separation into the oil component, the water component and the solids component can be obtained by rotation, using dynamic separators, for example, cyclone or centrifugal separators, operating according to the principle of density separation using the forces arising during rotation. During rotation of the wellbore fluid, the heavier phase / component separates to the outer radius of rotation. For example, heavier solids may separate to the outer radial regions, while lighter water will separate to the intermediate region, and even lighter oil will separate to the region closer to the center of rotation. This radially centric oil component (possibly with some residual water and / or solids) is discharged as an output productive stream.

As shown in FIG. 10, the separator 34 comprises a solids channel 112 through which a solids stream having a high solids concentration is discharged. As shown, the solids channel / outlet 112 is located in a position that is a radially distant position with respect to the water channel 52 and the oil channel 50. Channels 50, 52, and 112 serve as exhausts from the working area of the separator 46 when streams enter the divider 48. In this example, solids are heavy components and cyclone / centrifugal separation separates solids (with some water as a carrier fluid) to the outer radius of the working zone 46 of the separator. As described above, oil is the lightest and separates toward the center of rotation to create an oil flow. More water is separated in the intermediate place between the oil component and the solids component and it is relatively free of solids. This stream of water, which is relatively free of solids, can be diverted to the desired discharge zone, for example, injection zone 76, using the methods described above. Reverse injection of the water flow into the injection zone 76 avoids the likelihood of clogging of the injection zone 76 and thus prevents damage to the injection zone. The furthest component of the borehole fluid from the center is the solids component that contains the largest proportion of solids, and this solids component can be routed to the reverse combining region 114 and again combined with the oil stream as a productive stream in, for example, pipe 40.

In operation, the borehole fluid mixture is supplied to the separator chamber 46, for example, the cyclone / centrifugal separator chamber 34, by a submersible pump 28 or other suitable pump of the pumping system 24. The borehole fluid enters the working area 46 of the separator 34 through the borehole fluid inlet 116. In the separator operating zone 46, the components of the well fluid are separated into components of oil, water and solids, which mainly contain oil, water and solids, respectively. Streams, mainly oil, water and solids, are then separated into component streams by a divider 48, and the respective component streams are distributed through the corresponding oil channel 50, water channel 52 and solid channel 112. The components of the wellbore fluid may be directed through an appropriate oil flow outlet 118, a water flow outlet 120 and a solids outlet of a divider 48 to respective downstream flow paths. The water channel 52 is radially external to the oil channel 50, and the solids channel 112 is radially external to the water channel 52. For example, the oil channel 50, the water channel 52, and the solid channel 112 may be in the form of concentric channels that distribute the components of the wellbore fluid to desired locations downstream. For example, component streams may be routed to an appropriate redirector 38 and / or through appropriate flow restrictors 60.

As described above with respect to various embodiments of the well system, the separation of the components of the well fluid, for example, the separation of the components of oil, water and solids, can be improved by applying back pressure to the various flows of the components of the well fluid. In many cases, the required back pressure can be carried out by removable flow restrictors, removable elements with passage openings and / or adjustable passage openings placed in the oil and solids stream and / or in the water stream. However, in order to achieve the required production results, backpressure can be created using various devices and with respect to various combinations of well fluid component flows. A flow limiter, for example, may be placed in an oil and solids stream, an oil component stream, a water component stream and / or a solid component stream.

Although only a few embodiments of the present invention have been described in detail above, those skilled in the art will understand that many modifications are possible without departing from the principles of this invention. Therefore, such modifications should be included within the scope of this invention, as defined in the claims.

Claims (20)

1. A downhole device comprising a separation system having a separator comprising an inlet for downhole fluid, a channel for oil flow, a channel for water flow and a channel for solids; and a removable flow restrictor located in the channel for solids to facilitate separation of the components of the well fluid. 2. The downhole device according to claim 1, in which the removable flow restrictor has a stationary element with an adjustable passage hole having a flow channel, the size of which is changed by replacing the flow restrictors. 3. The downhole device according to claim 1, in which the removable flow restrictor has a removably mounted element with an adjustable passage hole, having a flow channel, the size of which is changed by replacing the removable elements with an adjustable passage hole. 4. The downhole device according to claim 1, which further comprises a pumping system having a submersible pump, the channel for the flow of water opening into the wellbore at a point that is located deeper in the wellbore than the submersible pump. 5. The downhole tool according to claim 1, wherein the removable flow restrictor is adapted to be removed by a downhole tool placed in the well using a conveyance means. 6. The downhole device according to claim 1, in which the separator is a cyclone separator. 7. The downhole device according to claim 1, in which the separator is a centrifugal separator. 8. The downhole device according to claim 1, in which the separation system further comprises a sensor that recognizes a parameter of the flowing fluid. 9. The downhole tool of claim 8, wherein the sensor is located downstream of the well fluid inlet. 10. The downhole tool of claim 8, wherein the sensor is located inside the separator. 11. The downhole tool of claim 8, the sensor is located upstream of the separator. 12. The downhole tool according to claim 1, in which the removable flow restrictor has a control element with a selectively variable passage hole. 13. A method for separating liquids and solids in a well, comprising the steps of: placing a separation system in a well, a separation system comprising a separator having an inlet for downhole fluid, an outlet for oil flow, an outlet for water flow, and an outlet for solid substances; determination of the parameter of the well fluid located in the well; selecting a degree of flow restriction based on determining and selecting an appropriate flow restrictor; and placing the selected flow restrictor in the outlet for solids. 14. The method according to item 13, further comprising changing the flow restriction by removing the flow restrictor from the separator when the separator is located in the well and then placing another flow restrictor having a different regulator in the separator when it remains inside the well. 15. The method according to item 13, in which the determination of the parameter of the well fluid contains its determination using a sensor located inside the well in the separation system. 16. The method according to clause 15, which further comprises placing the sensor inside the flow limiter. 17. A method of preparing a system for separating wellbore fluids and solids, comprising the steps of: creating a separator with a separation working zone in communication with a fluid inlet and a divider having a channel for oil flow, a channel for water flow radially outward from the channel for oil flow, and a channel for solids placed radially outward from the channel for water flow; and placing a flow restrictor in the channel for solids to provide a selective effect on the separation of the well fluid and solids. 18. The method according to 17, further comprising placing a separator in the wellbore and separating oil, water and solids for release, respectively, through an oil flow channel, a water flow channel and a solid channel. 19. The method according to p. 18, additionally containing the use of a downhole pumping system for pumping the separated oil to a place on the earth's surface. 20. The method according to claim 19, further comprising reverse pumping the separated solids into the separated oil above the downhole pump system and supplying the separated solids to a location on the surface of the earth.

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