RU2495235C1 - Method and device for controlled pumping down to formations - Google Patents

Abstract

FIELD: oil and gas industry.SUBSTANCE: to the well with tubing string a package is run in that includes bottom packer, disconnector, pumping down distributor, top packer, disconnector. The lower part of package is equipped with a socket or liner and the top part with extension cord. Cross-over shoe is installed over the bottom and top packers. Packers are set and pressurised. Down-the-hole flowmeter with plug is run in to the distance bigger than location for mounting seat of the plug. Fluid is delivered to the tubing string, total fluid consumption is determined. The plug is set to the mounting seat, fluid is supplied to tubing string, consumption is determined for fluid pumped down to the lower bed. This value of consumption is subtracted from total consumption value for fluid pumped to upper bed. Actual values of fluid consumption for beds are compared with preset values. In case of difference in values recoverable part of pumping down distributor is run out to the surface. Bottom and top unions are set to mounting seats. The recoverable part of pumping down distributor is run in until it seats in the main cover of pumping down distributor. Controlled pumping down is carried into beds. In order to shutoff one of formations a blind plug is installed instead of a union. When operations are completed the package is run out. Pumping down distributor includes a main cover consisting of a nipple with several through channels, body and bushing of cross-over shoe, recoverable part consisting of the bottom and top bushings and diffuser. Top bushing and diffuser have mounting seats for top and bottom unions and blind plugs. Top bushing has a mounting seat for the plug. In bottom bushing there are upper and lower central channels, divergent and convergent channels.EFFECT: possibility to perform controlled pumping down to formations by means of one device, to measure consumption of fluid.9 cl, 3 dwg

Description

The invention relates to the oil industry, in particular to equipment for the operation of injection wells, which opened two layers.

There is a method of separate operation of objects of an injection or production well and installation options for its implementation, selected as an analogue, including the descent in series into the injection or fountain, or pump, or gas lift well of two columns of pipes of larger and smaller diameters, placed one in the other concentrically. A pipe string of larger diameter is equipped with at least one packer and one bypass assembly or element for a medium flow - a working agent or produced fluid. At least two objects of one well are operated. According to the invention, the cavities of the pipe string of smaller and larger diameters are disconnected in a hermetically sealed manner at a depth either lower or lower or higher than the upper object for separate movement of the media along them. One of the cavities is hydraulically connected to the bottomhole zone of the upper object through the bypass node or element, and the other to the bottomhole zone of the lower object. In this case, the bypass node or element is either performed with an axial landing channel, or the landing node is provided from below. A pipe string of smaller diameter is equipped with a disconnecting element, which is lowered and installed either in the axial mounting channel of the bypass unit or in the landing unit below the bypass element (patent No. 2328590, IPC ЕВВ 43/14, prior. 20.10.2006).

A known method of developing a multilayer oil reservoir, selected as an analogue, including dividing the formations into groups with different filtration-capacitive properties, isolating groups of formations with different permeabilities, pumping a working agent through injection wells, taking oil from the formations through production wells. After separation of the reservoirs according to the filtration-capacitive properties, they are divided into three groups with different permeability using packers. Selectively, in the injection wells, the lower group of formations is cut off, the upper and lower groups of the respective separate columns are additionally examined for formation permeability. Then the insulation is removed, the total permeability of the middle and lower groups of layers is studied. The lower packers of the injection wells are equipped with a flow divider, for example a fitting or a control valve. Next, the working agent is injected in separate columns into the upper group of layers and into the middle and lower groups of layers. At the same time, injection is carried out at the wellhead from one injection line by breaking it with wellhead flow controllers, for example, valves for individual columns of each injection well. The rise in the production of groups of reservoirs from producing wells is carried out simultaneously or separately, depending on the physicochemical properties of the products of these groups of reservoirs (patent No. 2380523, IPC EV 43/14, prior. 23.07.2008).

A disadvantage of the known methods is that two columns of pipes are used to pump the working agent, which increases the metal consumption of the installation.

The known method of Sharifov for simultaneous-separate and alternate operation of formations by one injection well, selected as a prototype of the claimed method, which consists in letting at least one pipe string with a constant or variable diameter without or with a plugged end into with at least one packer of hydraulic and / or mechanical action, lowered below the upper layer, without or with a column disconnector. Below and above the packer, at least one landing unit in the form of a borehole chamber or a nipple with a removable valve (removable control unit) is lowered to feed the working agent through them into the lower and upper layers, the packer is installed and crimped from below and / or from above. During crimping, the minimum absorption pressure of each formation is determined. The working agent is pumped from the mouth into the cavity of the pipe string at a given pressure, directing it to the upper and / or lower layers through the corresponding removable valves (extractable control units) in the landing units. The total consumption of the working agent, wellhead pressure and / or temperature in the cavity of the pipe string and the annulus of the well are measured on the surface. The bottomhole pressure of the upper layer, the pressure in the pipe string and the annulus at the depth of a removable valve (extractable control unit) in the landing unit above the packer are determined. Find the flow rate of the working agent injected into the upper layer through a removable valve (extractable control unit), subtract it from the total and determine the flow rate of the working agent injected into the lower layer. Compare the actual costs of the working agent for the formations with their design values. Moreover, when they differ, the wellhead pressure is changed and / or removable valves (retrievable control units) from the landing units using cable technology are removed for one or both layers. Their characteristics and / or parameters are determined and changed. After that, each removable valve (removable control unit) is re-installed in the corresponding landing unit using cable technology and pumping of the working agent through them into the corresponding layers is continued (patent No. 223003009, IPC ЕВВ 43/14, prior. 09/11/2003).

The disadvantages of this method include the fact that for the injection of the working agent into the reservoirs, several downhole chambers or nipples are used, while the number of tripping operations required to install and replace removable valves, as well as the metal consumption of the installation, are increased.

A known installation for simultaneous and separate injection of water into the reservoirs, including a column of elevator pipes with packers separating the reservoirs, and couplings with axial and radial channels and a removable plug. The removable plug descends from the mouth on the draft and is made with the possibility of tight interaction with the axial channels of the couplings. The installation contains longitudinal channels communicating spaces above and below each starting clutch. The removable plug is made by the team and consists of plungers that are connected by rods and interact with the corresponding axial channels of the couplings, and is constantly located in the well. Longitudinal channels are made in each plunger, and the couplings are made in the form of polished bushings with radial holes. Moreover, the length of rods, bushings of couplings and plungers, as well as the number of holes and holes in the bushings of the couplings are selected with the possibility of selective overlapping by the plungers of radial channels in the respective bushings of the couplings without lifting the plug to the surface (RU No. 2436934 C1, IPC ЕВВ 43/00, prior. 01.06 .2010).

A disadvantage of the known installation is the difficulty in selecting the length of rods, bushings of couplings and plungers, their number, as well as the number of holes in the bushings of the couplings, depending on the number of layers and the switching options necessary for their operation. The disadvantages include the large metal consumption, as well as the inability to use geophysical instruments in this installation.

A well-known well installation, selected as an analogue, including pump tubing (tubing) lowered into the production tubing with oval chambers and / or central nipples having transverse channels and a seat with a removable valve in the form of a housing with radial, axial and hydraulic transverse channels connected to it, seals and a latch, a control element connected to the rod of the locking element is installed inside the housing. An additional pipe string is installed to a depth below the unsealed portion of the production string; in the annular space formed between the pipe strings, a cement bridge and / or one or more hermetically isolating cavities of disconnectors are installed, while tubing is installed inside the additional pipe string, and part of the borehole surface the oval chamber above the seat of the removable valve is pressed from both sides into the internal cavity and / or the body of the removable valve in the central nipple flax with internal longitudinal non-axial through channels, hydraulically communicating tubing cavities above and below the central nipple (RU No. 2131017 C1, IPC E21B 43/00, prior. 08.07.1997).

A disadvantage of the known installation is the need for a large number of tripping operations to replace removable valves, while both the descent and lifting of the valves is carried out only using special cable technology.

Known three-packer installation, selected as an analogue, containing equipment mounted in the production string of the well on the string of tubing 1. The equipment includes upper 2, middle 3 and lower 4 packers, a through-type nipple 5, a funnel 6 with a ball, circulation valves 7 and 8, mechanical heat compensators 9 and 10, a jet pump 11 and a non-through nipple 12 with the possibility of installing a blind plug or fitting insert. Each of the packers 2, 3 and 4 have an individual installation and lifting scheme. The upper packer 2 is made with a hydraulic installation and upward axial removal after cutting the power pins, the middle packer 3 - mechanical action with a support installation and a rotary-axial removal, the lower packer 4 - mechanical action with a rotary-axial installation and removal. The lower 4 and middle 3 packers can be lifted from the well only after rotation of the tubing string 1, and the upper packer 2 after tightening the tubing string 1, taking into account the regulated force for it. Packers 2, 3, and 4 are double-sided and have the option of independent placement in a fixed location of the production string (RU No. 77899 U1, IPC Е21В 43/14, Е21В 33/12, prior. May 26, 2008).

A disadvantage of the known installation is the need for a large number of tripping operations to replace the fitting inserts installed in the circulation valves.

It is known equipment for simultaneous-separate injection of water into two layers through one well selected as an analogue, containing a pipe string with a packer installed between the layers, above which there is a cross coupling that hydraulically connects the internal cavity of the pipes to the over-packer annulus of the well. A check valve is integrated in the hydraulic channel of the cross-coupling, eliminating the flow of water from the borehole into the pipe cavity. The hydraulic channel of the cross-coupling has a saddle, for shutting it off with a shut-off element launched from the wellhead, closing the saddle with a shut-off element eliminates the flow of water from the pipes into the borehole annulus. The locking element can be made of material with a density lower than the density of water injected into the well (RU No. 59140 U1, IPC ЕВВ 43/16, prior. 06/19/2006).

The disadvantages of the known equipment include the fact that the regulation of injection is performed only on the upper layer. Moreover, the regulation mechanism is not reliable enough, because in case of intensive injection of water into the formation, the elastic properties of the return spring may be lost. The disadvantages also include the lack of an upper packer in the equipment necessary to protect the pipe string from the effects of high pressure injection of the working agent into the reservoir.

A device is known for controlled injection of fluid into the reservoirs, selected as an analogue, containing a landing tool in the form of a nozzle lowered on a pipe string, a packer consisting of a housing, a mandrel, and an elastic sleeve located on the housing, a throttling assembly including a nozzle with a fitting, this nozzle is equipped with a Central channel, blocked from the bottom by a check valve, made in the form of a ball, spring-loaded upward from the fitting, the packer position lock, perforated shank, shear elements. The elastic packer cuff is made in the form of barrel-shaped seals, and the packer body is telescopically inserted into the mandrel, to which a perforated shank is rigidly attached to the bottom. The throttling unit is installed on the lower end of the packer body, and the upper and lower ring samples are made on the packer body, between which the packer body is equipped with a tapered surface, tapering from top to bottom, while the barrel seal retainer is made in the form of a split cone tapering on the packer body, tapering from below up, placed above the lower ring selection and dies spring-loaded down, and placed on the packer body above the upper ring selection, as well as a stop mounted on the housing e packer below the lower o-ring above the barrel-shaped packer seals. The emphasis in the transport position is fixed relative to the packer body by a shear element, while the emphasis externally covers a split cone and is rigidly connected to it by screws. The split cone and the dies can interact with each other when the packer body is axially moved downward with the dies moving radially outward in the working position, while the body and the stop are equipped with flushing holes communicating the device’s internal space with its external space (RU No. 69916 U1, IPC Е21В 43 / 20, prior. 07.27.2007).

A device for regulating the injection of fluid into the reservoirs, selected as an analogue, consisting of a planting tool, a packer and a throttling unit. The latter is a nozzle with a fitting and a sealing collar, mounted freely in the hollow head of the thrust pipe, provided with longitudinal grooves and a tapered supporting surface. The nozzle also has a similar conical bearing surface. The thrust pipe is connected to the mandrel, and the latter is connected to the packer body, on which an elastic cuff is worn. The support pipe is connected by shear elements to the packer body. The pipe string at the lower end is equipped with a valve connected in transport position by means of shear screws with a landing tool. In the event of a cessation of water injection (accident, power outage, etc.), fluid from the lower reservoir will act on the nozzle with a fitting, lift it and open the longitudinal grooves. As a result, the pressure drop in the wellbore above and below the packer will be minimal, which will prevent it from moving away and thereby ensure its reliable operation during further water injection (RU No. 52097 U1, IPC ЕВВ 43/20, prior. October 17, 2005).

A device for regulating the injection of fluid into the reservoirs, selected as an analogue, containing a packer comprising a mandrel and an elastic element connected to the packer bottom pipe and a throttle assembly. The device is equipped with a landing tool in the form of a pipe and a support pipe connected from below to the mandrel, ending on top with a threaded sleeve, the pipes are interconnected by shear elements. The throttle assembly is installed in the sleeve of the support pipe and is made in the form of a nozzle muffled from above, in the lower part of which a fitting is rigidly mounted. Below the plug along the perimeter of the nozzle, channels are made connecting its internal space with the formation, and the channels are directed upwards to the axis of the device. The lower pipe is equipped with a cone rigidly fixed on it, below which a closed figured groove with longitudinal short and long sections is made on the outer surface of the lower pipe. A clip with a guide pin, which is placed in a figured groove, is installed on the lower pipe. On the cage along its circumference slips are installed, spring-loaded in the radial direction (RU No. 43909 U1, IPC ЕВВ 43/20, prior. 10/15/2004).

A device for regulating the injection of fluid into the layers, selected as a prototype of the claimed device, consisting of a planting tool, a packer and a throttling unit. The latter is a nozzle plugged at the top with a fitting at the bottom. Below the plug along the perimeter of the nozzle, holes are made connecting the internal space of the device with the well zone. The nozzle is installed inside the landing tool, above the packer. Below the packer is the lower pipe, equipped with a filter, based on the bottom of the well when installing the device (RU No. 42858 U1, IPC Е21В 43/20, prior. 21.09.2004).

The disadvantages of the known devices include the fact that the regulation of injection is carried out only on the lower layer without the possibility of regulating the injection on the upper layer, as well as the fact that in order to change the diameter of the passage channel of the nozzle it is necessary to completely remove the entire device.

The problem solved by the invention is the implementation of using one device controlled injection of fluid into the reservoirs, providing the ability to turn off one of the reservoirs to measure the flow rate of fluid injected into another reservoir, as well as the ability to isolate one of the reservoirs, reducing the number of tripping operations regulation of fluid injection, reducing the metal consumption of the layout of underground equipment.

The specified technical result is achieved due to the fact that:

- the arrangement of underground equipment, including a lower packer, a disconnector, an injection distribution device (URS), an upper packer, a disconnector, a lower and an upper packer is installed, pressure testing, a depth meter and a plug above are lowered into a well on a string of tubing (tubing) the latter’s seat, the fluid is supplied to the tubing cavity, the total flow rate of the fluid pumped into the lower and upper layers is measured, then the cork is lowered into the seat, the fluid is supplied to the N cavity CT, determine the flow rate of the fluid injected into the lower reservoir, subtract the flow rate of the fluid injected into the lower reservoir from the total flow rate and find the flow rate of the fluid injected into the upper reservoir, compare the actual flow rate of the reservoir fluid with the given values, and if they differ, the recoverable part of the URZ is raised to the surface using a fishing tool on a geophysical cable, wire or coiled tubing installation, then the upper and lower fittings are installed in the seats of the extracted part of the URZ, the extraction is lowered PSR second part in the tubing before its planting in the body portion, and performed PSR regulated injection of liquid at the end of works produce lift installation;

- the lower part of the layout is equipped with a funnel or shank;

- the upper part of the layout is equipped with an extension cord, which is installed directly above the disconnector or through a certain number of tubing sections or directly under the faceplate;

- the disconnector perform a mechanical or hydraulic principle of action;

- a centralizer sub is installed above the lower packer and under the upper packer;

- the plug and the depth meter are interconnected via a geophysical cable or attached directly to each other;

- the cork is lowered into the tubing together with a deep flow meter or discarded separately without a deep flow meter;

- the extracted part of the URZ is lowered on a geophysical cable, wire or coiled tubing installation or dumped into the tubing;

- the injection distribution device includes a housing part, consisting of interconnected nipples with several through channels, a housing and an adapter sleeve, an extractable part consisting of top to bottom of the upper sleeve, lower sleeve and diffuser, while the extractable part is inserted into the housing part with the formation of the chamber, the upper and lower sealing units are installed on the lower sleeve, the first of which is fixed with a nut from the bottom, and the last is limited by the stop at the top, landing m is made in the upper sleeve and diffuser nesting under the upper and lower fittings or plugs, moreover, the upper sleeve additionally has a seat for a plug, and the upper central channel is made in the lower sleeve, branching with the formation of several diverging channels connected with the camera and with through nipple channels, as well as several converging channels forming a lower central channel in communication with the passage channel of the diffuser.

The layout diagram of underground equipment for controlled injection of fluid into the reservoirs is shown in figure 1. A longitudinal section of the injection distribution device is shown in Fig.2. A longitudinal section of the URZ with a shift of 90 °, the plug and the flow meter are presented in figure 3.

The downhole installation includes a layout of underground equipment lowered into a well 1 (Fig. 1) on a tubing string 2, including a lower packer 3, disconnector 4, URZ 5, upper packer 6, disconnector 7. The lower part of the arrangement is equipped with a funnel 8 or shank (not shown in figure 1). Disconnectors 4.7 of a mechanical or hydraulic principle of operation are installed above the lower 3 and upper 6 packers, which serve to disconnect the tubing string 2 from the lower packer 3 and the upper packer 6, respectively, in case of sticking. Above the lower packer 3 and under the upper packer 6, centering adapters 9, 10 are installed. The lower packer 3 is made of a mechanical principle of operation and is installed above the funnel 8 or shank. URZ 5 is located above, which serves to regulate the volume of fluid injected into the lower 11 and upper 12 layers, turn off the upper layer 12 to measure the flow rate of the liquid pumped into the lower layer 11, and also to isolate one of the layers if necessary. Next, the upper packer 6 is installed. The upper packer 6 is made of a mechanical operating principle with an emphasis on the lower packer 3. In the upper part of the arrangement there is an extension 13 designed to tightly connect the upper packer 6 to the tubing string 2 and to compensate for the axial movements of the tubing 2 that occur during the injection process liquids. An extension cord 13 is mounted directly above the disconnector 7 either through a certain number of tubing sections or directly under the faceplate (not shown in FIG. 1).

The distribution device injection 5 (figure 2) consists of a housing and extractable parts. The body part consists of interconnected nipple 14, the housing 15 and the adapter sleeve 16. Several through channels 17 are made in the nipple 14. A removable part is inserted into the body part, consisting of the upper sleeve 18, the lower sleeve 19 and the diffuser 20. Top the lower sleeve 19 is installed upper 21 and lower 22 sealing units. The upper sealing assembly 21 is secured from below by a nut 23. The lower sealing assembly 22 is bounded from above by an abutment 24, which acts as a limiter for the movement of the extracted part when it fits into the housing. A chamber 25 is formed between the body and the extracted parts. In the upper sleeve 18 and in the diffuser 20 there are seats 26.27 under the upper 28 and lower 29 fittings, or plugs (not shown in FIGS. 2, 3). Also in the upper sleeve 18 there is a seat 30 (Fig. 3) for the plug 31, lowered with a deep flow meter 32. In the lower sleeve 19 there is an upper central channel 33, branching with the formation of several diverging channels 34. The diverging channels 34 are connected with the camera 25 and with through channels of the nipple 17. In the lower sleeve 19 (Fig. 2) several converging channels 35 are also formed, forming the lower central channel 36. The lower central channel 36 is in communication with the passage channel 37 of the diffuser 20.

The implementation of the method is described in the description of the equipment.

Before the launch of the assembly, the well 1 is modeled (Fig. 1) and the casing walls are cleaned with scrapers (scrapers) (not shown in Fig. 1), and then the wellbore 1 is flushed.

The layout of the underground equipment is collected in the following sequence: lower packer 3, disconnector 4, URZ 5, upper packer 6, disconnector 7. The lower part of the layout is equipped with a funnel 8 or a shank. Centralizers 9, 10 are installed above the lower 3 and upper 6 packers. The top of the assembly is equipped with an extension 13. Then the assembly is lowered onto the tubing 2 into the wellbore 1 to a certain depth. After that, the mouth is equipped with wellhead fittings (not shown in Fig. 1). The layout is lowered either without a removable part of the URZ 5, or together with it. The first option is used if you need an open passage channel for processing, as well as for the passage of geophysical equipment. The second option, respectively, when there is no need for an open passage channel. Install and then test the lower 3 and upper 6 packers.

To measure the total flow rate of the fluid pumped into the lower 11 and upper 12 layers, the plug 31 and the depth meter 32 (FIG. 3) are lowered on the geophysical cable. The plug 31 and the depth meter 32 are interconnected via a geophysical cable or attached directly to each other. To determine the total flow rate of the fluid pumped into the lower 11 and upper 12 layers, the deep flow meter 32 with plug 31 is lowered above the seat 30. Next, the fluid is supplied to the tubing cavity 2.

The fluid enters the lower layer 11, passing through the converging channels 35, the lower Central channel 36, the lower fitting 29 and the passage channel of the diffuser 37 (Fig.2).

The fluid enters the upper formation 12, passing through the upper fitting 28, the upper central channel 33 (Fig. 3) and diverging channels 34, and then through the chamber 25 into the through channels 17. The total flow rate of the liquid entering the two layers is measured by a depth meter 32 .

To determine the flow rate of the fluid pumped into the lower layer 11, the plug 31 with the deep flow meter 32 is lowered into the seat 30, thereby disconnecting the upper layer 12. Next, the liquid is supplied into the tubing cavity 2, which passes through the converging channels 35 (Fig. 2 ) and the lower central channel 36, and then through the passage channel 37 of the diffuser 20 enters the lower layer 11. Measure the flow rate of the liquid entering the lower layer 11.

To determine the flow rate of the fluid pumped into the lower layer 11, it is also possible to drop the plug 31 separately into the seat 30, thereby disconnecting the upper reservoir 12, and then lower the depth flow meter 32. After the measurement, the plug 31 is removed using a fishing tool on a geophysical cable, wire or coiled tubing (not shown in FIG. 3).

Subtracting the flow rate of the fluid injected into the lower reservoir 11 from the total flow rate, determine the flow rate of the fluid injected into the upper reservoir 12.

The actual fluid flow rates for reservoirs 11,12 are compared with predetermined values. If the actual costs differ from the set values, the extracted part of the URZ 5 is raised to the surface using a fishing tool on a geophysical cable, wire or coiled tubing. In the seats 26, 27 (figure 2) set the upper 28 and lower 29 fittings. Next, they lower it on a geophysical cable, wire or coiled tubing installation or dump the extracted part of the URZ 5 into the tubing 2 before it fits into the body of the URZ 5. Then, liquid is supplied into the tubing cavity 2, which passes through the converging channels 35, the lower central channel 36, and then the passage channel of the diffuser 37 enters the lower layer 11. In the upper layer 12, the liquid enters passing through the upper Central channel 33 (Fig.3), diverging channels 34, and then into the through channels 17 of the nipple 14.

If it is necessary to pump only into the lower layer 11, the extracted part of the URZ 5 is raised to the surface using a fishing tool on a geophysical cable, wire or coiled tubing. A plug (not shown in FIGS. 2, 3) is installed in the seat 26 (FIG. 2) of the upper sleeve 18, and the bottom fitting 29 is installed in the seat 27 of the diffuser 20.

Next, they lower it on a geophysical cable, wire or coiled tubing installation or dump the recoverable part of the URZ 5 into the tubing 2 before landing in the hull part of the URZ 5.

If it is necessary to pump only into the upper layer 12, the extracted part of the URZ 5 is raised to the surface using a fishing tool on a geophysical cable, wire or coiled tubing. An upper fitting 28 is installed in the seat 26 of the upper sleeve 18, and a plug is installed in the seat 27 of the diffuser 20 (not shown in FIGS. 2, 3). Next, they lower it on a geophysical cable, wire or coiled tubing installation or dump the recoverable part of the URZ 5 into the tubing 2 before landing in the hull part of the URZ 5.

After carrying out work on pumping liquid, the layout is removed to the surface. To do this, by tensioning the tubing string 2 (Fig. 1), first the upper packer 3, then the lower packer 6 is transferred to the transport position. After that, the layout is raised to the surface.

Thus, the claimed invention allows using a single device, namely URZ, to carry out controlled injection of fluid into the reservoirs, to measure the total flow rate of fluid injected into two reservoirs, as well as the flow rate of fluid injected into the lower reservoir by shutting off the upper reservoir using a plug. Also, thanks to the claimed invention, it is possible to carry out treatments and passage of geophysical instruments through an open passage channel. This is achieved by the fact that the URZ is made with the possibility of raising its extractable part to the surface. The inventive method and device for controlled injection of fluid into the layers can reduce the metal consumption of the layout, because adjustable injection in two layers does not require the descent of several pipe columns and the use of downhole chambers. Also, the claimed invention allows to reduce the number of tripping operations for the implementation of the process of regulating the injection of fluid.

Claims (9)

1. A method of controlled fluid injection into the reservoirs, including descent into the well on a pipe string of mechanical packers without or with a column disconnector, planting packers and crimping them, pumping fluid from the mouth into the cavity of the pipe string, determining the total fluid flow rate pumped into the upper and lower strata, measuring fluid flow rate in one of the strata, determining fluid flow rate in another reservoir by subtracting previously measured flow rate from the total flow rate, raising the extracted control unit to the surface, changing characteristics, re-installation of the extracted control unit and pumping fluid through it into the corresponding reservoirs, characterized in that the arrangement of underground equipment, including the lower packer, disconnector, injection distribution device - URZ, upper packer, is lowered into the well on the tubing string - tubing , disconnector, install the lower and upper packers, conduct pressure testing, lower the depth flow meter and plug above the latter’s seat, supply fluid to the tubing cavity, replace they determine the total flow rate of the fluid pumped into the lower and upper reservoirs, then lower the plug into the seat, supply fluid to the tubing cavity, determine the flow rate of fluid pumped into the lower reservoir, subtract the flow rate of fluid pumped into the lower reservoir from the total flow rate and find the flow rate fluid injected into the upper reservoir, the actual fluid flow rates for the reservoirs are compared with predetermined values, and when they differ, the recoverable part of the URA is raised to the surface using a fishing tool on a geophysical cable barely, wire or coiled tubing installation, then the upper and lower fittings are installed in the seats of the extracted part of the URZ, the extracted part of the URZ is lowered into the tubing before its landing in the body part of the URZ and the fluid is pumped in an adjustable manner, at the end of work, the installation is lifted. 2. The method according to claim 1, characterized in that the lower part of the layout is equipped with a funnel or shank. 3. The method according to claim 1, characterized in that the upper part of the layout is equipped with an extension cord, which is installed directly above the disconnector or through a certain number of tubing sections or directly under the faceplate. 4. The method according to claim 1, characterized in that the disconnector perform mechanical or hydraulic principle of action. 5. The method according to claim 1, characterized in that a centralizer sub is installed above the lower packer and under the upper packer. 6. The method according to claim 1, characterized in that the plug and the deep flow meter are interconnected via a geophysical cable or attached directly to each other. 7. The method according to claim 1, characterized in that the plug is lowered into the tubing together with a deep flow meter or dumped separately without a deep flow meter. 8. The method according to claim 1, characterized in that the extracted part of the URZ is lowered on a geophysical cable, wire or coiled tubing installation or dumped into the tubing. 9. An injection distribution device including a body part consisting of interconnected nipples with several through channels, a housing and an adapter sleeve, a removable part consisting of an upper sleeve, a lower sleeve and a diffuser, the extractable part being inserted into case part with the formation of a chamber, the upper and lower sealing units are installed on the lower sleeve, the first of which is fixed with a nut from the bottom, and the last is limited by a stop at the top, the landing gears are made in the upper sleeve and diffuser e places for the upper and lower fittings or plugs, moreover, the upper sleeve additionally has a seat for the plug, and the upper central channel is made in the lower sleeve, branching with the formation of several diverging channels associated with the camera and with through channels of the nipple, as well as several converging channels forming the lower central channel in communication with the passage channel of the diffuser.

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