RU2305170C2 - Packer separation device for well reservoir operation (variants) - Google Patents

Abstract

FIELD: hydrocarbon production, particularly sealing or packing boreholes or wells.

SUBSTANCE: device comprises pump, one or several mandrels with removable valves to provide medium flow, nipple for removable valve and one packer installed over reservoir or between reservoirs or several mechanical, hydraulic, hydromechanical or impulse packers arranged over reservoir or between reservoirs in any combination. All above components are connected to pipe string with opened or sealed lower end and are sunk in well. At least one packer is connected with one or several members, namely with anchor, telescopic connection, connector, stem or filter. Pump is freely or fixedly fastened to packer arranged below the pump and has case to isolate pump inlet from hole clearance and to provide communication thereof with pipe string interior. Mandrel is arranged over pump case. Mandrel has removable valve provided with through or blind axial channel and radial orifices or two opposite connection pipes having free or spring-loaded check valves. The check valves have limited strokes to prevent medium flow between reservoirs.

EFFECT: increased efficiency and reliability during simultaneous or alternate operation of several producing and/or injection reservoirs in each well drilled in multiply field, possibility to operate well in single reservoir.

37 cl, 22 dwg

Description

The invention relates to the field of hydrocarbon production (oil, gas, gas condensate, gas hydrate) and reservoir pressure maintenance (RPM), mainly in multilayer fields, and can be used simultaneously (OE) and / or separate (WEM), or alternately (PE ) the operation of several production (ARD or PD) and / or injection (ORZ or PZ) objects (layer, interlayers) of one well, and, in some cases, can be used to regulate and study the parameters of objects, injection or disposal of water and / or gas to the facility, excluding cheniya absorption formation damping solution, isolation of the water reservoir, or leaking of the barrel, as well as cutting off the flow of formation fluid fountain, gas lift, and the injection well pumping.

A well-known well installation (Mirzadzhanzade A.Kh. Technology and equipment for oil production. M .: Nedra, 1986), including a pipe string with start-up valves and packers, deflated and installed in a multi-layer field well.

Known downhole installation (RF Patent No. 2194152, ЕВВ 43/12, 34/06, bulletin No. 34 dated 12/10/02), including a pipe string deflated and installed in the well, equipped with at least and above or between the layers one packer, disconnector and / or telescopic connection, a borehole chamber with a removable valve, including a pump during pump operation.

A well-known well installation for implementing the method of simultaneous-separate development of several production facilities (RF Patent No. 2211311, ЕВВ 43/14, bulletin No. 24 dated 08/27/03), consisting of a pipe string with one or more packers, downhole cameras and / or nipples without or with valves, disconnectors and / or telescopic connections, including a pump during pump operation.

Known installations have a limited scope due to the complexity of the descent, landing and extraction of packer equipment from the well. In addition, when the installation is implemented, there is no information about the operation of its disconnector, and there is also difficulty in disrupting the packers to extract them.

Known mechanical packer (OAO Tyazhpressmash, Internet: http://www.tkpo.ryazan.ru:8101/), consisting of a barrel with an external shoulder or emphasis, an adapter, o-rings and seals, a casing with threaded radial holes for shear screws and tip. In this packer, the free wheeling for the cuffs is not regulated, and the cuffs cannot leak beyond the generatrix during deformation, which reduces the reliability of its operation.

Known packer with an anchor hydraulic action type 2PD-YAG (Catalog. Equipment for gas-lift operation of oil wells. Tsintihimneftemash. M., 1991), consisting of a barrel with internal bores, external grooves, radial holes, a cylinder forming a hydraulic chamber with the barrel associated with the cavity of the barrel through radial holes, support nuts, cuffs, rings, cones with dies and ram holder, connected with the barrel with shear screws. In this case, the anchor rigidly connected to the barrel of the stacker consists of a sleeve, a housing with one or more rows of radial channels, spring-loaded movable sealed dies with limited radial strokes placed thereon due to the strips installed on the housing, and the sealed movable dies form an annular with the barrel off-axis hydraulic channel. This packer structurally does not have the possibility of temporary failure due to high overpressure inside its trunk, and its failure occurs only with the shear screws being cut with an additional tightness of the pipe string of 10-12 tons, which complicates the technology of using the packer installation, in particular, for simultaneously separate well operation. Also, considering that the hydraulic anchor of the packer is triggered only by external - bottomhole pressure, it often happens that the shear screws are cut off during the packer’s landing process and released spontaneously with the pipe string and, accordingly, the trunk moving up.

Sharifov’s disconnecting device is known (RF patent No. 2203386, ЕВВ 23/06, 33/12, Bull. No. 12, 04/27/2003), containing a barrel and a housing with internal grooves, an adapter, an emphasis with internal and external collars and radial grooves for a latch in the form of cams, sealing cuffs, a tip, a collet to prevent rotation of the barrel relative to the body, a sliding sealing sleeve with shear screws, sealing rings and an inner bore for radial movement of the latch, outer grooves, an inner lower movable sleeve with a fix torus and an upper sleeve, a fixed locking ring. In the installation, when the disconnector is triggered, there is no information about the uncoupling of its casing with the barrel without preloading and lifting the pipe string. In addition, the disconnector has low reliability when reconnecting its body with the barrel due to the lack of its centralizer, and also has the ability to move down the sliding sealing sleeve in the body and spontaneous operation of the disconnector during descent into the well, which in turn complicates the technology of using the packer installation , in particular, during simultaneous and separate operation.

Also known is the Sharifov column disconnector (RF patent No. 2203385, ЕВВ 23/06, 33/12, Bull. No. 12, 04/27/2003), consisting of a housing with internal sealing cuffs and a barrel with collars, landing surfaces and radial openings, a casing with internal sealing elements, forming the upper and lower chambers with the barrel, hydraulically connected, respectively, with the barrel cavity and / or the space behind the casing, an abutment with shear screws, a retainer, an adapter, a collet, or a reentry shoe. Here, after the disconnector is triggered, that is, the casing is moved downward, it is not fixed, due to which, when the pressure in the pipe string is relieved and there is a difference between the liquid density in the annulus and the tube space, the casing of the disconnector moves back to its original position and, as a result, the housing automatically connects to trunk, which reduces the reliability of the disconnector when used in a packer installation.

The aim of the invention is to increase the efficiency and reliability of the installation during simultaneous separate or alternate operation of several producing (oil, gas, gas condensate, gas hydrate) and / or injection formations (for RPM or disposal of excess water and / or gas) by each well in a multi-layer field, and also during the operation of wells with one reservoir.

The efficiency of the installation when it is used for one or more production and / or injection formations by one well in a multilayer field is achieved, in particular, due to: separate or simultaneous descent, landing and extraction of packers for formations; maintaining the reliability of the production string by eliminating the movement of the medium flow through it and / or cutting off its cavity from high pressure; separate development of producing strata or injection of a working medium into strata; a separate study of each of the layers; differential effects on formations by creating depression or repression on them; injection or disposal of water and / or gas into the formation or layers; separate jamming or separation of layers; the implementation of underground repairs without killing the reservoir or reservoirs and / or eliminating the formation’s absorption of the solution when killing the well by cutting off the reservoir or reservoirs from the wellbore using a cut-off or blank plug; elimination of negative technological impact on the formation (absorption of the solution by the productive formation) with the use of a check valve in the installation, and, therefore, preservation of the filtration inflow characteristics (flow rate) of the formation; preventing a decrease in the design bottomhole pressure during the launch and operation of the well; regulation or maintenance of the optimal range or bottomhole pressure for the formation in the well; ensure the medium is pumped into the injection reservoir, cutting off another producing formation with a blank plug or valve, or, conversely, producing fluid from one formation, cutting off the other injection formation; regulation of the design flow rate of the working environment for the layers; providing a pumping or fountain method for extracting medium from one formation while simultaneously injecting medium (working agent) or disposing of excess produced water or gas into another layer of one well; ensuring the extraction of liquid (water) by the pump from the lower layer (s) and pumping it into the upper injection layer, or vice versa, pumping the liquid from the upper layer and pumping it into the lower injection layer.

The technical result and the economic effect of the use of the proposed technical and technological solutions for production and / or injection wells is achieved, in particular, due to: reduction of capital costs for drilling additional wells; increase production; cost reduction for events; reduction of time for repair work at the well; increase the life of the well and underground equipment.

The purpose of the invention is achieved due to the following technical and technological solutions.

Option 1. Packer disconnecting installation includes lowered into the wellbore on a pipe string having an open or plugged lower end, a pump, one or more downhole chambers with removable valves for medium flow, a nipple for a removable valve and one packer installed above the formation or between the layers , or several packers of mechanical, hydraulic, hydromechanical or pulsed action (lowered simultaneously or separately), placed above and between the layers in any combination, and at least one packer connected to one or more of the elements - anchor, telescopic connection, disconnector, shank, filter. The pump is connected rigidly or loosely to the packer located below it and has an external sealing casing made with the possibility of isolating the pump intake from the annulus and connecting it hydraulically with the pipe string cavity, while a well chamber with a removable valve, which is made with an axial valve, is installed above the pump casing. through or non-through channel and radial holes or two opposing fittings with free or spring-loaded check valves with limited strokes to exclude I am the possibility of the flow of medium from one layer to another.

Between the borehole chamber and the pump, a flow meter can be installed to measure the flow rate and, accordingly, the volume of fluid pumped from the upper reservoir into the lower reservoir.

The installation may include several mechanical packers with appropriate shanks and one or more downhole chambers with removable valves to separate the layers and control their parameters.

Several hydraulic packers and one mechanical packer, or vice versa, with corresponding shanks and one or more downhole chambers with removable valves for separating the layers and adjusting their parameters, can be lowered into the wellbore on the pipe string.

A lower hydromechanical or hydraulic packer and one or more upper mechanical packers with corresponding shanks and one or more downhole chambers with removable valves can be lowered to the wellbore for pipe separation and regulation of their parameters.

In the installation, the anchor of the packer is made of mechanical or hydraulic action with the possibility of temporary failure from a given internal or external, or internal and external pressure.

In the installation, a telescopic connection is installed either above the upper packer to compensate for changes in the length of the pipe string during operation, or between packers for the sequence and reliability of the packers breaking when they are lifted.

Option 2. Packer disconnecting installation includes placed in the wellbore on a pipe string having an open or plugged lower end, one or more downhole chambers with removable valves for the flow of produced or injected medium, a nipple for a removable valve and several packers (deflated simultaneously or separately) located above and between the layers, at least one of the mentioned packers is made of hydraulic action and is connected to one or more of the elements - an anchor, a telescopic connection It consists of one or several parts of the barrel with internal bores, external grooves and radial holes, a cylinder forming a hydraulic chamber connected with the barrel through the radial holes, support nuts, cuffs, rings, cones with dies and die holder connected to the barrel with shear screws. The hydraulic action packer is either configured to temporarily fail due to a predetermined internal overpressure, and for this purpose a sliding sealing sleeve is installed in its barrel with the ability to move under mechanical or hydraulic action, disconnect or connect the hydraulic chamber through radial holes with the barrel cavity, respectively, for temporary exclusion of the possibility of actuation or operation of the packer hydraulic action when the pressure in it is not a pipe, or it is made with the possibility of releasing it both by mechanical action by cutting shears and by hydraulic action to reduce the load on the pipe string, moreover, to ensure the possibility of hydraulic release on the lower part of the barrel, one or more circulation holes and radial channels are made, in the latter there are stops in the form of cams, stoppers or balls, while inside the barrel there is a sliding sealing sleeve with an external groove for the stops, and a compass The hole in the barrel is made with the possibility of connecting its cavity with the annular space when moving the sliding sealing sleeve in the barrel from the upper fixed to the lower extreme position, while the stops in the radial channels of the barrel are placed with the possibility of support through the ring on shear screws at the upper fixed position of the sliding sealing bushings for cutting, as well as with the possibility of radial movement into the outer groove of said sleeve and free passage under the ring without cutting shear nt, at the extreme lower position of the sliding sealing sleeve to relieve additional load on the pipe string when the hydraulic packer breaks.

Also, depending on the parameters and characteristics of the well, the installation according to option 2, in particular, can be performed and applied in the following various options.

The anchor is made of mechanical or hydraulic action with the possibility of temporary failure from a given internal or external, or internal and external pressure.

A telescopic connection is installed either above the upper packer to compensate for changes in the length of the pipe string during operation, or between packers for the sequence and reliability of the packers breaking when they are lifted.

The disconnector above the packer is made of hydraulic or mechanical action with the ability to obtain information about its operation without interference pipe string.

The bottom packer is equipped with one or more downhole chambers with removable valves for the lower uncoupled object, consisting of one or several layers, while one or more additional downhole chambers with detachable valves are installed above the packer for the upper uncoupled object, also consisting of one or several layers, for the purpose of extraction or injection of medium through them during simultaneous and separate operation, or the selection of liquid by a pump from one formation through a pipe string and feeding it into another formation with an internal borehole injection with the ability to measure fluid flow by lowering the flow meter into the pipe string above the pump housing.

At least two packers with corresponding shanks and one or more downhole chambers with removable valves for separating the layers and adjusting their parameters are lowered into the wellbore on the pipe string, with the first packer being hydraulic in action from the bottom and the second one in mechanical action, which is seated from the axial load on it by transferring fully or partially the weight of the pipe string after checking for leaks from the bottom and / or top of the lower hydraulic packer.

At least two packers with corresponding shanks and one or several borehole chambers with removable valves were lowered into the wellbore to the pipe string to separate the layers and adjust their parameters, while the first packer from below is a mechanical action that is triggered by axial load onto it by transferring in whole or in part the weight of the pipe string, and the second packer - hydraulic action, which is installed after checking for leaks from below and / or above the lower packer of the mechanical actions.

The installation includes several hydraulic packers with appropriate shanks and one or more downhole chambers with removable valves, for separation of the layers and regulation of their parameters.

A lower hydraulic packer and one or more upper mechanical packers with corresponding shanks and one or more downhole chambers with removable valves for separating the layers and adjusting their parameters are lowered onto the pipe string into the wellbore.

Several hydraulic packers with corresponding shanks and one or several well chambers with removable valves for separating the layers and adjusting their parameters were lowered onto the pipe string into the wellbore, while the number of shear screws installed on one hydraulic packer is distributed for all hydraulic packers.

At least two hydraulic packers with a liner and one or more downhole chambers with removable valves for separating the layers and adjusting their parameters are lowered into the wellbore on the pipe string, while a disconnector is installed at least above the lower hydraulic packer to allow for failure and extracting each hydraulic packer separately from the well.

Several hydraulic packers and one mechanical packer, or vice versa, with corresponding shanks and one or more downhole chambers with removable valves for separating the layers and adjusting their parameters, were lowered (simultaneously, sequentially, separately) on the pipe string.

In downhole chambers, removable valves are made in the form of a regulator with one or two opposite fittings.

The mechanical packer is installed loosely or with the liner resting under it on the lower installed packer, or on the bottom, or on the anchor, or on the existing bore of the wellbore, and it consists of a barrel with an external shoulder or emphasis, an adapter, o-rings and cuffs, a casing with threaded radial holes for shear screws and the tip, while to increase the reliability of the packer, an adjustment nut is installed outside the adapter with the ability to change the free play of the sealing lips and prevent leakage to it from them during its deformation, and the casing on top under the sealing cuffs is made with the possibility of excluding leakage of the lower one, the outer diameter of the adjusting nut not less than the outer diameter of the casing, and the latter, in turn, larger than the diameter of the sealing cuffs, this barrel and casing are made with the possibility of fixing relative to each other.

The sliding sealing sleeve or packer sleeve is additionally made with radial channels in which the supports interacting with the barrel are placed in the form of cams, stoppers or balls, with the possibility of supporting the shock rope tool on top of them when the sliding sealing sleeve or sleeve is in the upper position, as well as radial movement in the inner bore of the barrel at the extreme lower position of the sleeve or sleeve and the release of the percussion rope tool down through itself to obtain information about the movement of the sleeve or and bushings all the way down.

An anchor rigidly connected to the packer barrel consists of a coupling, a housing with one or more rows of radial channels, spring-loaded movable sealed dies with limited strokes placed in them due to the strap mounted on the housing, which form an annular hydraulic channel with the barrel, while for To increase the reliability of the packer, hydraulic holes and grooves are made on the upper part of its trunk, and sealing elements are sealed on the latter, hermetically separating the body into two parts, the upper of which They are connected with the cavity of the packer barrel through hydraulic holes, and the lower one, under the packer space, through the annular hydraulic channel to ensure the operation of the armature, both from external and internal overpressure.

The packer’s trunk is rigidly connected to the anchor body between its two separated parts or rows of radial channels, the upper of which communicates with the cavity of the packer’s trunk through radial channels, and the lower one — under the packer’s space through an annular hydraulic channel, to ensure the armature is triggered, as from an external and from internal overpressure.

The armature body is made with one or several non-axial hydraulic channels, while in the radial channels of the body under the sealed movable rams there are pistons forming hydraulic chambers with them, disconnected from the cavity of the packer barrel and connected through non-axial hydraulic channels with a sub-packer space to ensure the armature is triggered , both from external and internal overpressure.

The top of the packer barrel is made with additional radial openings, while two pistons are interconnected between the anchor body and the packer barrel, the cavity formed above the upper piston being hermetically disconnected and filled with liquid, and the cavity between the pistons is hydraulically connected to the cavity of the packer barrel through additional radial holes, and the cavity under the lower piston is hydraulically connected to the under-packer space to ensure the operation of the armature from both the external and internal huts exact pressure.

The disconnector comprises a barrel and a housing with internal grooves, an adapter, a stop with internal and external collars and radial channels or grooves for the retainer, a sliding sealing sleeve with shear screws, o-rings, an internal bore for radial movement of the retainer, external grooves, an inner lower sleeve fixed in the initial position and a removable upper sleeve fixed with a locking ring, a latch in the form of cams or balls, sealing cuffs in the form of chevron and fluoroplastic or rubberized metal rings, a tip, a stopper or collet to prevent rotation of the barrel relative to the housing, while to increase the reliability of the disconnector in the outer grooves of the sliding sealing sleeve several rows of sealing rings are installed, and at least one of the rings is made between the two of them threaded conical or cylindrical hole connecting the inner and outer cavities of the disconnector when moving the sleeve in the housing from the upper fixed to the lower position to obtain information on the operation of the disconnector, and one or more threaded cylindrical holes with shear screws above the lower or upper outer groove of the sliding sealing sleeve, for reliability of fixing its initial position when lowering into the well, the sliding sealing sleeve is made with radial channels placed in them supports interacting with the barrel in the form of cams or balls, with the possibility of supporting the percussion rope tool from above with the upper position of the sleeve, and As well as radial movement into the inner bore of the case at the extreme lower position of the sleeve and releasing the percussion rope tool downward through itself to obtain information on the operation of the disconnector, the adapter is made in the form of a centralizer with a larger outer diameter and its tip is made in the form of a reentry shoe or a centralizer with a larger outer diameter, the stop is made with communicating holes, while the height of the lower sleeve inside the sliding sealing sleeve is greater than the width of its inner stitches for the retainer, and the distance from the upper end of the lower sleeve to the stop of the sliding sealing sleeve with its fixed position by shear screws is not less than the distance between the lower end of the sliding sealing sleeve at its initial position and the outer shoulder of the stop, and when the case is reentered into the well from a disconnector in its circulating threaded hole has a plug (plug).

The disconnector consists of one or several parts of the barrel with collars, landing surfaces, radial holes, a casing with internal sealing elements, forming the upper and lower chambers with the barrel, hydraulically connected, respectively, with the barrel cavity and / or the space behind the casing, an abutment with shear screws , retainer, housing, adapter, cylinder with internal sealing cuffs in the form of chevron and fluoroplastic or rubberized metal rings, collets or re-entry shoes, while for to increase the reliability of the disconnector between the casing and the barrel, the latch is not able to fix the casing relative to the barrel at the upper initial position and rigidly or not rigidly at the lower working position, and a disconnector in the form of an annular piston with its emphasis on the barrel shoulder is placed between the casing and the barrel having one or more external and internal sealing elements, moreover, a groove is made under the disconnector on the barrel and a snap ring is installed in it for rigidly fixing the disconnector, with it adapter shoe and reentering formed as a centralizer.

Two rows of radial holes are made on the disconnector barrel, hydraulically connecting the corresponding upper and lower sealed chambers, and between them a seat for a removable check valve is made to ensure that the disconnector is activated from excessive pressure in the pipe string.

The pocket of the borehole chamber on top is made with an internal groove for the retainer and, accordingly, the removable valve is made with the upper retainer in the form of a collet or a split spring ring.

Option 3. Packer disconnecting installation for the operation of well seams includes placed in the wellbore on a pipe string having an open or plugged lower end, one or more downhole chambers with removable valves for the flow of produced or injected medium, a nipple for a removable valve and several mechanical packers ( deflated simultaneously or separately), located above and between the layers, and at least one of the mentioned mechanical packers is connected to one or more of the elements - the anchor, eleskopicheskim compound disconnector shank pump and consists of a barrel with an outer shoulder or abutment, adapter, sealing rings and sleeves, the housing with threaded radial holes for shear screws and tip. Outside the adapter, an adjusting nut is installed with the possibility of changing the free travel of the sealing cuffs and eliminating the outflow of the upper one when it is deformed, and the casing on top under the sealing cuffs is made to exclude the outflowing of the lower one, and the outer diameter of the adjusting nut is not less than the outer diameter of the casing, and the latter, in turn, is larger than the diameter of the sealing lips, in addition to this, the barrel and the casing are made with the possibility of fixing relative to each other. Each mechanical packer in the well is installed freely or with the liner resting under it on the lower free installed mechanical packer, or on the bottom, or on the anchor, or on the existing shoulder of the wellbore.

Also, depending on the parameters and characteristics of the well, the installation according to option 3, in the particular case, can be performed and applied in the following various options.

Mechanical packers are connected to the respective shanks and one or more downhole chambers with removable valves, for separation of the layers and regulation of their parameters.

A telescopic connection is established between the packers for the sequence and reliability of the failure of the packers when they are lifted.

The lower mechanical packer from the bottom is equipped with one or more downhole chambers with removable valves for the lower disconnected object, consisting of one or more layers, while one or more additional downhole chambers with removable valves are installed above the upper mechanical packer for the upper object, also consisting of one or several layers, with the aim of extracting or pumping the medium through them during simultaneous and separate operation, or the selection of liquid by a pump from one layer along the pipe string and bottom and at its other downhole injection formation under the chance of fluid flow measurement by the descent of the flowmeter in a pipe string above the pump housing.

In downhole chambers, removable valves are made in the form of a regulator with one or two opposite fittings.

The pocket of the borehole chamber on top is made with an internal groove for the retainer and, accordingly, the removable valve is made with the upper retainer in the form of a collet or a split spring ring.

The principal views of the installation and its individual elements for producing and / or injection reservoirs of wells in different designs are shown in FIGS. 1-22, in particular: FIG. 1 shows a generalized diagram of a multi-packer installation for production and / or injection reservoirs with one well; figure 2 - packer installation for simultaneous separate injection of the working medium or downhole pumping of products from the upper reservoir into the lower reservoir and / or production of fluid from the reservoir; figure 3 - packer installation with a plug for injection and / or production; figure 4 is the same, only with a filter and / or disconnected disconnector for fluid extraction; figure 5 - packer installation with the support of the shank on the bottom; figure 6 - hydraulic packer with an anchor; Fig.7 - hydraulic packer with a sliding sealing sleeve; on Fig - hydraulic packer with a sliding sealing sleeve; Fig.9 - sliding sealing sleeve or sleeve with a stopper; figure 10, 11, 12 - the anchor of the packer in three versions; Fig.13 is a disconnector of mechanical and hydraulic action; on Fig - a disconnector hydraulic action, triggered by internal pressure; on Fig - disconnector hydraulic action, triggered by external pressure; in Fig.16 - mechanical packer; on Fig, 18 is a removable valve for injection and production wells; on Fig - downhole chamber with a removable valve; on Fig - determination of the flow rate of the upper undivided layer by the actual bottomhole pressure corresponding to the dynamic level during the joint work of two layers; on Fig - determination of the flow rate of the upper disconnected reservoir by the actual pipe (at the depth of the reservoir or in the intake of the pump, or at the pump outlet) or annular (above the pump) pressure corresponding to the dynamic level during the joint operation of two layers; on Fig - determination of the flow rate of the upper reservoir according to the measured dynamic level during the joint work of two layers.

The installation includes (FIGS. 1-5) a pipe string 2 lowered into the wellbore 1 with an open or muffled end 3.

To separate one or more (two, three or more) formations, for example A, B and C, from the cavity of the pipes 2 and the wellbore 1, the pipe string 2 is equipped with either one 4 or 5 packer, or several packers 4 and 5 or 4, 5 and 6.

All packers 4, 5 and 6 are lowered into the well simultaneously or sequentially (separately) and are made of mechanical and / or hydraulic, or other action, without or with shear screws 7.

Either above or below, or both above and below the packers 4, 5 and 6 (or for one or more of them), anchors 8 are installed (for example, see Fig. 1 for packer 4), to exclude the possibility of moving the packer up either down, or both up and down during its landing and operation of the well, as well as to create emphasis when landing mechanical packers. In this case, the anchors 8 can be performed both hydraulic and mechanical action, without or with the possibility of regulating the pressure and / or force of their operation.

Under the packer 4 (see figure 4) or between the packers 4, 5 (see figure 2), or both under the packer 4, and between the packers 4 and 5 (see figure 5) or 4, 5 and 6 (see FIG. 1), a liner of several pipes (tubing) 2 is lowered, without (see FIGS. 2, 4) or with one or more downhole chambers (in the form of a mandrel) 9, 10, 11, 12, 13 , 14 with removable valves 15, 16, 17, 18, 19, 20, for the flow of the produced or injected medium, or of the medium extracted from the lower reservoir and pumped into the upper reservoir.

Packers 4, 5 and 6 (or one or more of them) in the well can be equipped with a disconnector 21 on top (see Figs. 1-4) and, in some cases, disconnectors 21, 22 or 21, 22 and 23 (Fig. .one).

The disconnector consists of two removable and non-removable parts, designed to be able to disconnect the pipe string 2 from the planted one, for example packer 4 (see Fig. 4), and then lower the subsequent upper packer 5 with a shank of several pipes 2 and down into the pipe string 2 removable part of the disconnector for repeated rigid or not rigid, but tight connection of the pipe string 2 with the lower installed packer 4 (see figures 1, 5).

The pipe string 2 may have one 24 (see figure 4) or several (see figure 1) nipples 24, 25, 26, 27 (made separately or combined with disconnectors) for a removable or non-removable valve (in particular, a check valve etc.) for the purpose of crimping the pipe string 2 and, in some cases, for regulating the operating conditions of the formation or formations.

The pipe string 2 or pump 28 (ESP, SHGN, NS, GPN, etc.) does not have (see Fig. 1) or has an outer casing "K" (see Fig. 2) having a sealed supply for the power cable. Also, the pipe string 2 can be equipped between the packers 4, 5 and 6 (Fig. 1) or 4 and 5 (Fig. 5), and / or above the upper packer 5 or 6 with a telescopic connection (temperature compensator) 29, 30 for stress relieving pipe string 2, reduce vibration of pump 28 in the pump well, increase the reliability of packers 4, 5, 6 during the WEM, as well as for the sequence of disruption of the packers 4, 5, 6 (due to the telescopic stroke) when lifting the multi-packer well WEM.

Above the packer 6 (see Fig. 1) or 5 (see Fig. 5) one 31 or several 31, 32 borehole chambers with removable valves 33 or 33, 34 are installed above the upper layer for development, operation, stabilization of the level, and pressure control , killing and flushing the well, as well as replacing the solution partially or completely with oil (inhibitor) against corrosion and freezing of the medium.

Depending on the method and operating conditions of the well, the installation can be performed in the following various versions:

One was lowered into the wellbore 1 and between its two production facilities (formations) A and B (see Fig. 2, 3) or A and B, B and C (see Fig. 1) one (mechanical, hydraulic, hydromechanical, pulse) packer 4 or 4, 5, without or with a hydraulic anchor 8, and a shank of several pipes 2.

A shank of several pipes 2 can be equipped with a nipple 24 for valve 35 (Figs. 2, 4) or a plug 3 (Figs. 1, 3, 5) and one or more downhole chambers 9, 10 with removable valves 15, 16 for the bottom disconnected object A. Here one or more of the borehole chambers 11, 12 with removable valves 17, 18 (see Fig. 3) can be installed above the packer 4 or 5 for the upper non-separated object B for injection or production of the medium.

When oil is extracted from the lower reservoir A by a pump 28 (see Fig. 2) with simultaneous injection from the mouth of the medium (for RPM or disposal of excess water or gas) into the upper reservoir B through the space formed between the barrel 1 and the pipe string 2, the borehole chamber 31 with a valve 33 can be installed above the pump 28 for pumping through it a partially pumped medium into the pipe string 2 to change the flow structure and prevent the formation of paraffin deposits.

Also, to exclude intensive deposition of paraffin deposits (in particular, paraffin, hydrate, etc.) in the pipe string 2 during the operation of formation A with pump 28 (type SHGN), mechanical scrapers (protectors) can be installed on its rod to clean deposits during the upward stroke of the rod and way down.

In addition, the pump 28 in the form of an ESP and, in some cases, an inverted ESP with a PED engine, can externally have a casing K, in particular a chamber of large diameter pipes (see Fig. 2), isolating the ESP from the annular intake (input module) spaces, and vice versa, hydraulically connecting the intake of the pump 28 with the cavity of the pipe string 2, in particular, through the circulation channels E above the PED inside the casing K to ensure the formation medium B flows from the annulus into the pipe string 2 through the borehole chamber 31, without or with a valve - fitting 33 (or circulating channels), installed above the casing K of the pump 28, and then its direction (through the cavity between the casing K and its pump 28) to the reception of the pump 28 with subsequent injection of fluid (from the upper layer B) into the lower layer A. At the same time, the pump casing 28 , on the one hand, it provides cooling of the inverted PED over the ESP fluid flow of formation B, and on the other hand, it allows you to determine the actual flow rate of the fluid pumped by pump 28 into the lower reservoir A by lowering and measuring the flow rate and, accordingly, the flow rate of the fluid to a depth e between the borehole chamber (circulation channel) 31 and the pump 28. It should be noted that the flow rate can be adjusted using the diameter of the fitting in the removable valve 33 installed in the borehole chamber 31 or in the central nipple above the housing K. Also, the flow rate of liquid (water) taken by the pump 28 from the upper layer B and injected into the lower layer A can be determined as follows. The annular and pipe pressures are calculated, and accordingly, the pressure drop across the removable valve 31 is calculated as a fitting based on parameters (dynamic level, wellhead pressure, etc.) measured on the surface of the well. Then, according to the well-known formula, the water flow rate for the fitting is determined at the found differential pressure.

One hydraulic packer 4 can be lowered into the wellbore 1 and placed above its object A, equipped with a shank of several pipes 2, either with a valve nipple 35 or an anti-sand filter (Fig. 4), or with a plug 3 and one or more downhole chambers 9, 10 with removable valves 15, 16 (see Fig. 3) for operating formation A, and on top with a disconnector 21 and one or more downhole chambers 11, 12 with removable valves 17, 18 for jamming, development, flushing or well start-up. In this case, the removable part (case) of the disconnector 21, after checking for tightness from below and / or above the packer 4, can be disconnected from the rigid clutch with the packer 4 through its non-removable part and left in an airtight connection with it (see Fig. 3) or separated from it (see figure 4) with the rise of the pipe string 2 upward relative to the packer 4.

In the wellbore 1, two packers 4, 5 (see FIG. 5) with corresponding liners from pipes 2 with one or more downhole chambers 9, 10, 11, 12, 31 with removable valves can be lowered sequentially onto the pipe string 2 with one run while the lower packer 4 is planted mechanically without or with the emphasis of its liner 2 (bottom) on the bottom (see figure 5) or on the shoulder (if any) of the wellbore 1, and the upper packer 5 is planted hydraulically or hydromechanically, or pulsed after checking for leaks from the bottom and / or top of the lower packer 4.

In the installation, the hydraulic packer, in the particular case (see Fig. 6, 7, 8), may consist of one or more parts of the barrel 36 with internal bores 37 (Fig. 6, 7), external grooves 38 and radial (hydraulic) holes 39, support nuts 40, 41, cups 42, cylinder (body) 43, forming with the barrel 36 a hydraulic chamber 44 connected to the cavity 45 of the barrel 36 through radial (hydraulic) holes 39, rings (bushings) 46 (see. 6, 8), cone 47 with dies 48 and a die holder (without or with a protective unit to exclude spontaneous flap shear screws) 49 connected to the barrel 36 by shear screws (if installed in two rows, the upper one with a smaller number serves to fix the die holder 49 in the upper position at the time of the packer landing to avoid spontaneous release of the packer) or shear ring 50 (see Fig. .6, 8) or 7 (see figure 1). To increase the reliability of the installation in the barrel 36 of the packer, a sliding sealing sleeve (sleeve) 51 (see Fig. 7) can be installed with the possibility of moving under mechanical (using a percussion instrument pulled by rope equipment) or hydraulic (after lowering the receiving valve and creating pressure by the unit) by exposure, isolation (before moving) and connecting (after moving) the hydraulic chamber 44 through the radial hole 39 with the cavity 45 of the barrel 36. In this case, before the movement of the sleeve 51 in the barrel 36, the operation packer (in particular, the upper packer setting at landing and pressure testing for leaks its lower packer) when the pressure in the pipe string. On the lower part of the trunk of the packer 36 (see Fig. 8), one or more circulation holes 52 and radial channels 53 are made. In this case, stops 53 are placed in the channels 53 (in the form of cams, stoppers, balls, etc.), and from the inside of the barrel 36 a sliding sealing sleeve (sleeve) 55 with an external groove 56 for stops 54 is installed to enable the packer to be torn off (with sleeve 55 moving down) without cutting (without cutting or bypassing) its shear screws (or shear ring) 50 under difficult conditions (for example, after long-term use of the packer) to avoid the likelihood of tearing the pipe string when releasing the packer with an extra tightness. The sliding sealing sleeve (sleeve) 51 (see Fig. 7) or 55 (Fig. 8) of the packer can be additionally made with radial channels 57 (see Fig. 9), in which the supports 58 interacting with the barrel 36 (in the form balls, cams, stoppers, etc.) with the possibility of abutment on top of them with a shock wire tool at the upper position of the sliding sealing sleeve (sleeve) 51 or 55, as well as radial movement into the inner bore 59 of the barrel 36 at the extreme lower position of the sleeve (sleeve) 51 or 55 and releasing the impact tool down Erez itself to receive the displacement sleeve (sleeve) 51 or 55 all the way down.

The hydraulic anchor (see Fig. 6, 10, 11, 12), rigidly connected to the barrel 36 of the packer, in the particular case, may consist of a sleeve 60, a housing (cylinder) 61 with one or more rows of radial channels 62 located in spring-loaded movable sealed dies 63 with limited strokes due to the slats 64 mounted on the housing 61. The dies 63 form a non-axial hydraulic channel 65 with the barrel 36 (in particular, connected in the well with the bottomhole formation zone). At the same time, hydraulic openings 66 and one or more grooves with sealing elements 67 are made on the upper part of the packer barrel 36, hermetically separating the housing 61 into two parts, the upper of which communicates with the cavity 45 of the packer barrel 36 through the hydraulic openings 66, and the lower one with the under-packer the space (with the bottom of the formation) through a non-axial hydraulic channel 65 to ensure radial movement of the upper dies of the armature from internal pressure (in order to prevent spontaneous release of the packer when it is planted and operated wells, in particular, when pumping cold working medium), and the lower dies - from external overpressure (for example, bottomhole or reservoir pressure). Thus, the anchor reliably eliminates the upward movement of the packer barrel 36 in the event of a pipe string deformation due to a temperature change and / or pressure change.

In the particular case, the packer barrel 36 (see Fig. 6) can be rigidly connected to the armature body 61 between two divided parts or rows of radial channels 62, the upper of which communicates with the cavity 45 of the packer barrel 36 through hydraulic holes 66, and lower - with under-packer space through a non-axial hydraulic channel 65 to ensure the operation of the armature, both from external and internal overpressure. The barrel 36 (see figure 10) can be equipped with o-rings 67, in particular, dividing the rows of radial channels 62 of the armature between its two parts.

In the radial channels 62 of the housing 61, pistons 68 can be installed under the movable sealed dies 63 (see FIG. 11), forming hydraulic chambers 69 with them, disconnected from the cavity 45 of the packer barrel 36 and connected through the hydraulic channel 65 to the under-packer space to ensure actuation anchors from internal and external pressure. Between the housing 61 of the anchor and the barrel 36 of the packer (see Fig. 12) two pistons 70 and 71 are interconnected, the cavity 72 formed above the upper piston 70 being hermetically disconnected and completely filled with liquid, the cavity 73 between the pistons 70 and 71 hydraulically connected to the cavity 45 of the barrel 36 of the packer through the hydraulic holes 66, and the cavity 74 under the lower piston 71 is hydraulically connected to the under-packer space (with the bottom of the formation) to ensure the armature is triggered from both external and internal overpressure.

In the installation, a disconnector (mechanical and hydraulic action) without or with a telescopic stroke (see Fig. 13), in the particular case, may contain a barrel (fixed part) 75 and a housing (removable part) 76 with grooves 77 (under the sleeve retainer), an adapter 78, an abutment 79 (with inner and outer collars) with communicating holes 80 (may not be) and radial channels (grooves) 81 for the retainer 82 (for example, in the form of cams or balls for rigid engagement of the body with the barrel). It also contains a sliding sealing sleeve (sleeve) 83 without or with shear screws 84, sealing rings 85, an inner bore 86 under the retainer 82, outer grooves 87, communicating holes 88 (may not be), and an inner bottom (for automatically connecting the body to the barrel ) sleeve 89 (without or with a collet), fixed with a retainer 84 (for example, 84 shear brass screws, collet or ring, etc.), a removable upper 90 sleeve (for percussion instrument or non-return valve, for example, KPP-57.15 or KPP -46, KPP-40, etc.), fixed with supporting ring 91. The stop 79 is internally equipped with sealing cuffs 92 (in the form of chevron and fluoroplastic or rubberized metal rings) and connected to a tip 93 having a stopper or collet 94 to prevent rotation of the barrel 75 relative to the housing 76. To increase the reliability of the disconnector on its housing 76, at least one conical or cylindrical circulation hole 95 (without or with a thread) is made, connecting the inner and outer cavities of the disconnector when moving the sleeve 83 in the housing 76 from the upper annogo to the lower end position. One or more threaded cylindrical holes 96 with shear (in particular, brass) screws 97 (for example, in the particular case of M6 in the amount of 2 pieces) above the outer groove 87 of the sliding sealing sleeve 83 between the sealing rings 85 can also be made on the housing 76 fixing its initial position and eliminating the spontaneous operation of the disconnector when it is lowered into the well. In this case, the sliding sealing sleeve 83 (for example, see Fig. 9) can also be made with radial channels 57 placed in them by bearings 58 in the form of balls or cams interacting with the housing 98, with the possibility of an abutment on them of an impact rope tool at the top the position of the sleeve 83, as well as the radial movement into the inner bore 99 of the housing 98 with the lowest position of the sleeve 83 and the release of the percussion cable tool down through itself to obtain information about the operation of the disconnector. When re-lowering into the well of the housing 76 (without or with a lock 82) of the disconnector in its circulation (hydraulic) holes 95, plugs 100 (without or with seals) can be installed for tightness. In the particular case, after creating an axial load (in particular, within 1-3 tons), the sleeve 83 is moved to the packer 4, 5 or 6 (using a percussion tool using cable technology or hydraulically after installing the check valve in the sleeve 83) until the outer shoulder of the stop 79 after successive cutting of the screws 84 (in the particular case, 3-4 screws are installed during the descent) and 97 (in the particular case, 2 screws). In this case, the bore 86 falls at the level of the latch 82 and allows it to be radially moved into the bore 86, thereby disengaging the housing 76 from the barrel 75. From this moment, the o-ring 85 is located below the holes 95, which provides a hydraulic connection of the internal and external cavity of the disconnector for liquid circulation through the channel (or slots) formed between the housing 76 and the sleeve 83, and through the openings 95 of the housing 76. Thus, information about the disconnection is obtained without additional interference between the pipe string the housing 76 with the barrel 75. After receiving the information, you can lift the pipe string with the housing 76 from the barrel 75 above the planted packer. To automatically connect the housing 76 to the wellbore 75 on the surface of the well or on the stand, the body 76 is assembled with the sleeve 83 (in the lower position) and the screws 84 (in particular, all screws are installed to exclude the possibility of cutting them when the body 76 is inserted into the well 75). Also, to eliminate the likelihood of premature movement of the sleeve 83 from the lower to the upper position during descent, shear screws 97 (for example, two screws) can be installed in the upper groove 87 between the lower rings 85 on the case 76. When the case 76 enters with a sleeve 89 into the barrel 75 of the sleeve 83 moves to the upper position and latches into the upper groove 77.

In the installation, a disconnector (hydraulic action) without or with a telescopic stroke (see Fig. 14-15), in the particular case, may consist of one or more parts of the barrel 101 (fixed part) with a shoulder 102, landing surfaces 103 (under a removable valve Gearbox, A or plug), radial holes 104 and / or 105, casing 106, sealing elements (rings) 106 and 108. Casing 106 with sealing elements 108 form the upper 109 and lower 110 of the chamber with the barrel 101, hydraulically connected, respectively, with cavity 111 of the barrel 101 and / or with the space behind the casing 106. K In addition, the disconnector also includes a stop 112 with shear screws 113, a retainer 114, a housing (removable part) 115 with an adapter 116 and a cylinder 117 with internal sealing lips 1 18 (in the form of chevron and fluoroplastic or rubberized metal rings), a collet ( during the initial descent of the casing) or shoe (during the lower descent of the casing) 119. To increase the reliability of the disconnector between the casing 106 and the barrel 101, the latch 114 is made with the possibility of fixing the casing 106 relative to the barrel 101 not rigidly with the upper initial and rigid (or not ECTS) at the lower position. Between the casing 106 and the barrel 101 there is a disconnector 120 in the form of an annular piston with its focus on the shoulder 121 of the barrel 101 having one or more external and internal sealing elements 107, 108. A groove 122 is made under the disconnector 120 on the barrel 101 and a snap ring is installed in it 123. On the disconnector barrel 101, if two rows of radial holes 104 and 105 are made, the cavity 111 is hydraulically connected to the upper 109 and lower 110 chambers (there are no channels or slots 124). In this case, between the chambers 109 and 110 on the barrel 101, a seat 125 is made for installing a removable non-return valve and for ensuring the actuation of the disconnector when the overpressure in the pipe string is increased. Channels 126 can be formed on the casing 106 (see FIG. 15). In the installation, the disconnector is triggered by excessive pressure in the pipe string (see Fig. 14) or from annular pressure (see Fig. 15). In this case, the screws 113 are cut off and the casing 106 is moved down and fixed (in particular, rigidly) in the lower position by the latch (stop) 114 in the groove of the casing 106, thereby removing the collet petals 119 from the collar 102. When lifting and re-lowering the casing 115, its collet replace with re-entry shoe.

In the installation, in some cases, the mechanical action packer without or with an anchor (see Fig. 16) may consist of a barrel 127 with an external shoulder or stop 128, an adapter 129, o-rings 130 and cuffs 131, a casing 132 with threaded radial holes 133 for shear screws 134 and tip 135. To increase the reliability of the packer, an adjusting nut 136 is installed outside the adapter 129. The barrel 127 and the casing 132 are structurally fixed (not rotating) relative to each other. To ensure the operation of the packer, an axial load is created from the weight of the pipe string, while the screws 134 are cut off and the barrel 127 with the nut 136 are mixed downward relative to the tip 135 with the casing 132, as a result of which the sleeve 131 is deformed under the load of the pipe string.

A removable valve (see Fig. 17, 18) installed in the pocket of the borehole chamber, in a particular case, can be made with an axial through or non-through passage channel 137, radial through holes 138, two opposite fittings 139 and 140, free or spring-loaded non-return valves 141, 142 with limited strokes. Also, the pocket 143 of the borehole chamber (see FIG. 19) can be made from above with an internal groove 144 for the retainer 145 and, accordingly, a removable valve is made with the upper retainer 145 (for example, in the form of a collet, a spring ring, or a split spring ring).

On the non-removable part - the barrel 21 of the disconnector (see Fig. 4), after disconnecting and removing from the well its removable part - the housing, guide 146 can be lowered and installed using cable technology (in particular, for a well with ESP or USGN, and etc.) for passing rope tools through it. Also, slots 147 can be made on the removable or non-removable part of the disconnector (see Fig. 14) to control the flow rate of the medium when changing its telescopic course by moving the location of the housing 115 with the cylinder 117.

The burt 148 of the wellbore 1 (if there is no collar in the production casing itself) for the possibility of supporting a mechanical packer on it (see Fig. 3) can be made separately (for example, in the form of a mechanical anchor) and lowered using a cable technique or lowered onto a casing pipes and fixed at a predetermined depth in the barrel 1 before lowering into the installation well.

The installation works (figure 1, 3, 5) with an operational fluid pressure or fluid pressure from the producing (one or more oil, gas, gas condensate, water) formations of one well as follows. After the installation is launched into the wellbore 1, the existing reservoirs (for example, A, B and C) are mastered by swabbing the fluid in the pipe string 2 or by supplying a working medium (gas, nitrogen, etc.) to it through the valves 33, 34 or mastered by starting pump operation 28. When developing or exploring formations simultaneously in all well chambers 9, 10, 11, 12, 13, 14 or in one or more of them, removable valves 15, 16, 17, 18, 19, 20 are installed, respectively in the form of a circulation valve (fitting or regulator) or there are no removable valves in them. In the case of development, research or alternate operation of the layers separately in each of the borehole chambers 9, 10, 11, 12, 13, 14, respectively, removable valves 15, 16, 17, 18, 19, 20 are installed in the form of a blind plug, this ensures the opening of only one layer when closing other layers.

For each layer, the corresponding project flow rate is set using each open of the removable valves 15, 16, 17, 18, 19, 20 in the form of a fitting or regulator. With ARD, the actual total flow rates in the layers can be determined by measuring the total flow rate at the mouth or in the pipe string 2, in particular, by lowering the flow meter to the section from the mouth to the upper fitting 20 (for three or more layers A, B, C) or 18 (for two layers A and B). In this case, the flow rate for the lower reservoir A is measured by lowering the flow meter between the nozzles 16 and 17. For the reservoir B, the flow rate is determined as follows: the flow meter between the nozzles 18, 19 is lowered and the total flow rate for two reservoirs A and B is measured, and then the flow rates of the lower reservoir are subtracted from it. And the production rate of B is found. Also, the production rate for the upper formation B is determined by subtracting the total production rate for the two reservoirs A and B from the total production rate.

The installation works (figures 1, 3, 5) with ARI or PZ of the working medium in the injection layers of one well as follows.

After the installation is lowered into the well for one or several formations, the design costs of the working medium are established using the wellhead regulator (nozzle) and each of the removable valves 15, 16, 17, 18, 19 open in the form of a nozzle or regulator without or with check valves, and through them, the working medium is pumped into the strata. At the same time, the actual total water flow through the strata can be determined by measuring the total flow rate at the mouth or in the pipe string 2, in particular, lowering the flow meter to a depth from the mouth to the upper fitting 20 (for three or more layers A, B, C) or 18 ( for two layers A and B). Water flows for the lower layer A can be measured by lowering the flow meter between the nozzles 16 and 17. For layer B, the water flow is determined as follows: lower the flow meter between the nozzles 18, 19 and measure the total flow for two layers A and B, and then the water flow is subtracted from it lower reservoir A and find the water flow for reservoir B. Also, the water flow for the upper reservoir B is determined by subtracting the total water flow for the two reservoirs A and B. from the total water flow

Also, depending on the variant of the used ORZ installation, the study of the injection well layers can be carried out as follows:

- when planting and crimping each packer from below and / or from above, it is possible to determine the minimum absorption pressure (conventionally assumed to be equal to the current reservoir pressure) and / or injectivity of each of the layers;

- during injection, it is possible to measure the total flow rate (for example, in two layers) of the medium on the well surface, wellhead pressure and / or temperature in the cavity of the pipe string and the annulus of the well, determine the bottomhole pressure of the upper undivided reservoir (by the annulus), and then the pressure in pipe string and annular space at a depth of a removable valve (nozzle) above the packer, based on them, find (by calculation) the flow rate of the medium (water) according to formula (1), pumped through the nozzle into the upper undivided layer, then subtract it from the total and determine the flow of working fluid (Q), the injection into the lower layer of disjunct.

where μ = 0.8 is the expenditure coefficient;

F - cross-sectional area of a removable valve - fitting, m ² ;

ΔР - pressure drop across the valve, kg / cm ² ;

ρ is the density of water, kg / m ³ .

For example, if you take F = 0.785d ² -0.785 × 0.008 ² = 0.0000502; ΔP = 20; ρ = 1000, then Q = 219.12.

- during the study, it is possible to determine the injectivity of each of the layers, isolating one or more layers from the cavity of the pipe string by installing removable valves in the form of a blind plug in the corresponding borehole chambers, and then ensure the medium is injected into one layer at one or several different flow rates, measure and / or determine the appropriate pressure in the pipe string, on the basis of which to build the dependence of the flow rate on the pipe pressure at the depth of each formation;

- during the study, it is possible to measure and / or determine, in a particular case, the pressure in the pipe string at the depth of the removable valves when medium is pumped through them into the layers, and then for each layer, respectively, to determine the actual flow rates of the working agent from the dependence of the flow rate on the pipe pressure ;

- during the study, it is possible to measure, in a particular case, the wellhead pressures in the pipe string and measure the total well costs corresponding to them and determine the costs for individual strata, based on which to build the dependences of the change in the total well flow and the costs of the strata on the wellhead pressure, then set and set the wellhead pressure necessary to ensure the injection mode of the total flow rate in the well and the flow rate for individual layers, adjust the injection mode by changing the diameter of the wellhead or wellhead Utsera or by the wellhead pressure regulator "behind";

- conditionally, when the friction losses in the pipe string are constant (in particular, above the upper packer, if the pipe string is lowered with a relatively larger diameter) for two medium flow rates (Q ₁ , Q ₂ ) and wellhead pressures (Ru ₁ , Ru ₂ ), the pick-up coefficient (CRC) can be defined as follows:

An ORD or PD installation for a pump well can mainly be used to disaggregate development facilities through the use of technology and equipment for the simultaneous or simultaneous separate operation of several production facilities (formations or interlayers) with one well equipped with a pump unit (for example, ESP, USGN and other). Moreover, its purpose is as follows:

- alternating production of fluid from each discovered (two or more) production facilities of one pumping well using technology and a PD installation that allows you to disconnect objects from each other and operate only one of them (for example, an underlying or overlying formation, or another formation between them) with temporary isolation by cutting off, respectively, of another or other production facilities until the next underground well repair associated with a replacement pump or with the need to eliminate complications during operation (E.g., flooding, gas indications, sand, and so forth.);

- simultaneous and separate production of fluid from two (in some cases, more) discovered production facilities (productive formations) of one pumping well using the technology and an ORD shut-off unit, which allows to separate objects between themselves, to investigate and determine their parameters both in joint and during separate operation of one of the objects before and after the descent into the well of the pumping unit;

- alternate and simultaneous separate production of fluid from every two working (at least three open) production facilities of one pumping well using technology and a shut-off unit PD and ORD, which allows you to disconnect objects from each other and operate only two of them (for example, underlying and overlying reservoirs or reservoir between them, etc.) with temporary isolation by cutting off, respectively, another or other production facilities until the next underground well repair associated with a pump change or with the need Axle eliminate complications existing during operation (e.g., water cut, gas indications, sand, etc.);

- simultaneous production of fluid from several (two or more) discovered production facilities (productive formations) of one pumping well with the help of technology and an ORD control unit that allows you to separate objects from each other and operate the formations, differentially affecting their operating mode - set your own formation optimum bottomhole pressure.

In the installation, if the pump 28 is made hollow, then the study and production accounting for the layers are carried out similarly for the fountain and gas lift wells. And if the pump 28 is not used hollow, then the design and selection of the type and size of the pump during the ARD can be carried out with respect to increased wellhead pressure and / or lowered total production rate of the formations to increase the range of formation studies with the aim of counting production by formations.

Research and registration of products by formations at PD of a pumping well. In this case, the fluid is pumped out by the pumping unit after a certain period of time (until the subsequent underground repair of the well) from only one open layer of the well, and all other layers are isolated from the pipe cavity using removable valves in the form of a blind plug. In this case, at the time of operation of each of the layers, the measured production rate of products extracted from it (oil Q _n , gas Q _r and water Q _c ) corresponds to the production of oil, gas and water from the well.

Research and registration of products by formations in the course of the production of openings or workstations and workings of the pumping well (if the removable valve for the formation or formations is made in the form of a cut-off) is carried out as follows.

Well studies (for example, for two layers) are first carried out on two open layers (in particular, the parameters of the well’s operation are measured in the initial mode), and then on one layer (with a high flow rate) when the shutter isolates the work of another layer (with a lower flow rate), in particular, due to changes in the dynamic fluid level in the annulus. The dynamic level of the liquid is raised or the shutter is closed mainly by reducing the through-hole of the wellhead regulator or fitting, and in a particular case, part of the produced product from the tubing string can be transferred to the annulus through the level stabilizer, topped up or pumped into the annular and / or tubular well space of an adjustable and measured flow rate of a one-component medium from an external source, for example, a pump, booster unit, an adjacent well, or an RPM line. Open reservoir studies are carried out for one or several (2-3) values of the dynamic fluid level in the annulus with changed fluid flow rates at the wellhead and / or measured under static conditions, the fluid level or static pressure at the depth of the pump or reservoir to determine the reservoir pressure of the open reservoir . According to the results of the study of two reservoirs of the well (with one or several modes), the parameters and dependencies between them are determined, first for two operating reservoirs, and then for one open formation when cutting off the work of another (for example, lower) formation: fluid flow rate (Q _ji ), water cut (n _inji ), dynamic level (N _di - _{beat by an} echo sounder), buffer pressure (P _bi ), wellhead pressure (P _уi ) and temperature (T _уi ), annular pressure (P _ni ) at the pump depth (s using telemetry system or removable pressure gauge in the borehole chamber (if any), the diameter (d _Шi ) of the hole of the wellhead regulator or fitting, and, accordingly, calculate the pressure (P _Зji , P _пji ) at the depth of the open formation using the methods of distributing the pressure of the medium in the annulus of the pump well.

Determination of production by layers in the absence of a packer above the upper layer (if the upper layer is not fragmented) is carried out as follows. On the basis of i = (1-3) -measurements of the parameters obtained during the operation of two layers, measure and / or determine the pressure (P _нi ) at the pump intake, and then the bottomhole pressure (P _Зji ) at the depth of the upper layer. Next, the pump is stopped (if there is no reservoir pressure) and annular wellhead pressure (P _у ) and dynamic level (H _d ) of fluid in the annulus of the well are measured in a stable mode, and then the reservoir pressure (P _PL1 ) of the upper reservoir is determined on their basis. Then determine the flow rate of the upper reservoir fluid:

- if studies were carried out before the pump was launched, then according to the obtained bottomhole pressure P _s1 , as well as on the basis of the indicator curve Q _j = f (P _{s, j = i} ) and Q _j = f (ΔP _{s, j = 1} ), t. e. productivity coefficient (K _CR1 ) and reservoir pressure (P _PL1 ) determine the flow rate (Q ₁ ) of the liquid of the upper layer;

- if no studies have been carried out before the pump is launched, then based on measurements of parameters at 2 ÷ 3 modes obtained during operation and / or stopping only the upper layer, the corresponding pressure (P _ni ) at the pump depth and the bottomhole pressure (P _З1i ) at the depth are _determined the upper layer, and then build the dependence Q _j = f (P _zabj ) and calculate the parameters of the upper layer according to the formula (for j = 1),

where n is the number of modes;

ΔQ _ji - change in fluid flow rate when changing ix modes for the j-th formation, m ³ / day;

ΔP _zji - change in bottomhole pressure when changing ix modes of the j-th formation, corresponding to ΔQ _ji , MPa;

- compare the obtained bottomhole pressure at the depth of the upper layer (P _s1 ) during the joint work of two separated layers on the constructed dependence Q _j = f (P _zbj ) for the upper layer and determine the corresponding actual flow rate (Q ₁ ) of the upper layer (see Fig. 20) or the latter is found based on the productivity coefficient (K _CR1 ) and reservoir pressure (P _PL1 ) of the upper layer.

From the total measured production (Q) for two layers, the products (Q ₁ ) of the upper layer are subtracted and the flow rate (oil - Q _n2 , water - Q _B2 and gas - Q _g2 ) of the other layer is determined from the balance of oil, water and gas production.

Determination of production by layers during separation by the packer of the upper layer is as follows. Based on i = (1-3) -measurements of the parameters obtained during the operation of two layers, measure and / or determine the pressure (P _ni ) at the pump intake, and then the pipe pressure (P _пji ) at a depth of at least one formation: if removable valves for both layers are installed in the form of a cutter, then the pipe pressure (P _pji ) is determined at the depth of one of them (in particular, the upper layer) in the range from the pressure of its opening to the closing pressure of the other cutter; if the removable valves for one layer are installed in the form of a cutter, and for the other in the form of a regulator (or fitting), then the pipe pressure (P _пji ) is determined at the depth of the regulator. In the absence of reservoir pressure (P _PLJ ) of the investigated formation, the pump is stopped (if a removable valve in the form of a regulator is installed for it in the borehole chamber) and wellhead pressure (P _у ) and dynamic level (N _d ) of fluid in the annulus are measured in stable mode the space of the well or pressure at the depth of the pump, and then based on them determine the reservoir pressure (P _PL ) of the investigated formation. Based on measurements of parameters at 1 ÷ 3 modes obtained during operation of only one layer (when cutting off the work of another layer), the corresponding pressure (P _ni ) at the pump intake and pipe pressure (P _пji ) are measured and / or determined at a depth of at least at least one studied formation. Based on the measurements of the parameters and the found pressures, the flow rates are constructed depending on the dynamic level Q _j = f (H _d ) and on the pipe pressure Q _j = f (P _пj ), and the actual flow rates (Q _j ) corresponding to the obtained dynamic levels (H _dj ) or pipe pressures (P _pj ) for the same layer during the joint work of two layers (see Fig.20, 21, 22). Where in Fig.20, 21: line 1 is the bottomhole or pipe pressure of the undivided layer, corresponding to a dynamic level of N _d during the joint work of two layers; line 2 is the flow rate dependence on the bottomhole or pipe pressure for the upper non-separated reservoir, corresponding to the closed state of the lower reservoir by the cutter at a pressure P _p2 greater than the opening pressure of the lower reservoir cutter from the pipe pressure P _o2 ; where in Fig.22: line 1 is the actual dynamic level during the joint work of two layers; line 2 - Q ₁ = f (H _d ) during the operation of the upper layer.

Next, the products of the studied formation are subtracted from the total measured production and the flow rate (oil, water and gas) of another formation is determined from the balance in oil, water and gas production.

Research and accounting of products by formations in the ORD of a pumping well (with removable control valves). With the simultaneous production of fluid from several (2-5) discovered productive formations, they differentially affect their operating mode using the corresponding removable valves in the form of a regulator or fitting. When ARD with a regulatory installation determine the flow rate in the layers as follows:

- also measure the total flow rate (Q), water cut (n _in ), dynamic level (H _d - beat off with an echo sounder), buffer pressure (P _b ), annular wellhead pressure (P _y ) and temperature (T _y ), pressure in the annulus (P _nz ) at the depth of the pump (using a telemetry system or a removable pressure gauge in the borehole chamber, if any) and, accordingly, the pipe pressure (P _p1 ) at the depth of the upper reservoir is calculated;

- determine from the previously obtained dependence Q ₁ = f (P _p1 ) the flow rate of the upper reservoir (Q ₁ ) corresponding to the found pipe pressure P _p1 for this item;

- subtract from the total flow rate (Q) the found flow rate (Q ₁ ) of the upper formation and, accordingly, for the obtained flow rate difference (Q * = QQ ₁ ), the calculation of the pressure distribution in the pipe over the section from the upper formation to the subsequent formation is continued, as a result of which the pipe pressure (P _p2 ) at the depth of the underlying formation;

- determined from a previously prepared depending Q ₂ = f (P _n2) flow rate downstream reservoir (Q ₂₎ corresponding to the found tubing pressure P _n2 on the item;

- the flow rate for the remaining layers (if any) is determined similarly to the determination of the flow rates of the first and second layers.

With simultaneous production of fluid from several (2-5) reservoirs, they are subjected to constant depression by using a bottomhole pressure regulator, and only one reservoir is operated without a regulator (open or with a fitting) to coordinate the characteristics of the pump and the reservoir system. In case of production and production of formations with bottomhole pressure regulators, their production and composition of the products from repair to repair are constant, and for a formation without a regulator, production is determined by deducting the production of all strata with regulators from the total output.

In addition to the above, the installation can also be used for downhole injection of medium from one formation into another formation or a combined method, in particular, it is used to operate one formation in a fountain way, and the other formation of one well - in a pumping way, and is also used to pump or utilize the medium in one layer, while producing fluid from another layer of one well.

Claims (37)

1. Packer disconnecting installation for the operation of wellbores, including lowered into the wellbore on a pipe string having an open or plugged lower end, a pump, one or more downhole chambers with removable valves for fluid flow, a nipple for a removable valve and one packer installed above reservoir or between reservoirs, or several packers of mechanical, hydraulic, hydromechanical or pulsed action, placed above and between the reservoirs in any combination, and at least one packer connected to one or more of the elements - an anchor, a telescopic connection, a disconnector, a liner, a filter, characterized in that the pump is connected rigidly or loosely to the packer located below it and has an external sealing casing that is capable of isolating the pump intake from the annulus and its hydraulic connection with a cavity of the pipe string, while above the pump casing a borehole chamber with a removable valve is installed, which is made with an axial through or not through channel and radial openings or two opposite fittings with free or spring-loaded check valves with limited strokes to exclude the possibility of fluid flow from one formation to another. 2. The packer disconnecting apparatus according to claim 1, characterized in that a flow meter is installed between the borehole chamber and the pump to measure the flow rate and, accordingly, the volume of fluid pumped from the upper reservoir into the lower reservoir. 3. Packer disconnecting installation according to claim 1, characterized in that it includes several mechanical packers with corresponding shanks and one or more downhole chambers with removable valves for uncoupling the layers and adjust their parameters. 4. Packer disconnecting installation according to claim 1, characterized in that several hydraulic packers and one mechanical packer, or vice versa, with corresponding shanks and one or more well chambers with removable valves for releasing the layers and regulating them, are lowered onto the pipe string into the well bore parameters. 5. Packer disconnecting installation according to claim 1 or 4, characterized in that a lower hydromechanical or hydraulic packer and one or more upper mechanical packers with corresponding shanks and one or more downhole chambers with removable valves for releasing the formations are lowered into the wellbore and regulation of their parameters. 6. Packer disconnecting installation according to claim 1, characterized in that the anchor is made of mechanical or hydraulic action with the possibility of temporary failure from a given internal or external or internal and external pressure. 7. The packer disconnecting installation according to claim 1, characterized in that the telescopic connection is installed either above the upper packer to compensate for changes in the length of the pipe string during operation, or between packers for the sequence and reliability of the failure of the packers when they are lifted. 8. A packer disconnecting installation for operating wellbores, including one or more wellbore chambers located in a wellbore on a pipe string having an open or plugged lower end, with removable valves for flowing the produced or injected medium, a nipple for a removable valve, and several packers placed above and between the layers, and at least one of the mentioned packers is made of hydraulic action and is connected to one or more of the elements - an anchor, a telescopic connection, a connector an adapter, a shank, a pump and consists of one or several parts of the barrel with internal bores, external grooves and radial holes, a cylinder forming a hydraulic chamber with the barrel connected to the barrel cavity through radial holes, support nuts, cuffs, rings, cones with dies and die holder associated with the barrel with shear screws, characterized in that the hydraulic packer is either configured to temporarily fail from a predetermined internal overpressure, while a sliding sealing sleeve is installed on the barrel with the ability to move under mechanical or hydraulic stress, disconnect or connect the hydraulic chamber through radial holes with the barrel cavity, respectively, to temporarily exclude the possibility of actuation or to ensure the hydraulic packer is triggered by increasing pressure in the pipe string, or it is made with the possibility release, both by mechanical action due to shear screws shearing, and by hydraulic action I reduce the load on the pipe string, and to ensure the possibility of hydraulic release on the lower part of the barrel, one or more circulation holes and radial channels are made, in the latter there are stops in the form of cams, stoppers or balls, while a sliding sealing sleeve with an outer sleeve is installed inside the barrel groove under the stops, and the circulation holes in the barrel are made with the possibility of connecting its cavity with the annular space when moving the sliding sealing bush in the barrel ki from the upper fixed to the lower extreme position, while the stops in the radial channels of the barrel are placed with the possibility of support through the ring on the shear screws at the upper fixed position of the sliding sealing sleeve for cutting, as well as with the possibility of radial movement into the outer groove of the said sleeve and free passage under ring, without cutting off the shear screws at the lowermost position of the sliding sealing sleeve to relieve additional load on the pipe string when the hydraulic packer breaks tions. 9. Packer disconnecting installation according to claim 8, characterized in that the anchor is made of mechanical or hydraulic action with the possibility of temporary failure from a given internal or external or internal and external pressure. 10. Packer disconnecting installation according to claim 8, characterized in that the telescopic connection is installed either above the upper packer to compensate for changes in the length of the pipe string during operation, or between packers for the sequence and reliability of the failure of packers when they are lifted. 11. Packer disconnecting installation according to claim 8, characterized in that the disconnector above the packer is made of hydraulic or mechanical action with the possibility of obtaining information about its operation without interference pipe string. 12. Packer disconnecting installation according to claim 8, characterized in that the packer bottom is equipped with one or more downhole chambers with removable valves for a lower disconnected object consisting of one or more layers, while one or more additional downhole chambers with removable valves are installed above packer for the upper object, also consisting of one or more layers, for the purpose of extraction or injection of medium through them during simultaneous and separate operation, or the selection of liquid by a pump from one layer according to a pipe string and feeding it into another formation during downhole injection with the possibility of measuring fluid flow by lowering the flow meter into the pipe string above the pump housing. 13. Packer disconnecting installation according to claim 8, characterized in that at least two packers with corresponding shanks and one or more downhole chambers with removable valves are lowered into the wellbore to the wellbore to separate the layers and control their parameters while the first packer from the bottom is a hydraulic action, and the second packer is a mechanical action, which is seated from the axial load on it by transferring fully or partially the weight of the pipe string after checking for tightness from the bottom and / or on top of the lower hydraulic packer. 14. Packer disconnecting installation according to claim 8, characterized in that at least two packers with corresponding shanks and one or more downhole chambers with removable valves are lowered into the wellbore to the wellbore to separate the layers and control their parameters while the first packer from below is a mechanical action that is triggered by the axial load on it by transferring fully or partially the weight of the pipe string, and the second packer is a hydraulic action, which is installed after checking and sealing the bottom and / or top of the lower packer mechanical action. 15. Packer disconnecting installation according to claim 8, characterized in that it includes several hydraulic packers with corresponding shanks and one or more downhole chambers with removable valves, for separating the layers and adjusting their parameters. 16. Packer disconnecting installation according to claim 8, characterized in that a lower hydraulic packer and one or more upper mechanical packers with corresponding shanks and one or more borehole chambers with removable valves are lowered into the wellbore to pipe separation and regulate them parameters. 17. Packer disconnecting installation according to claim 8, characterized in that several hydraulic packers with corresponding shanks and one or more downhole chambers with removable valves are lowered onto the pipe string to the wellbore to separate the layers and adjust their parameters, the number of shear screws installed on one hydraulic packer is distributed to all hydraulic packers. 18. Packer disconnecting installation according to claim 8, characterized in that at least two hydraulic packers with a liner and one or more downhole chambers with removable valves are lowered into the wellbore to pipe separation and control their parameters, when this, at least above the lower hydraulic packer, a disconnector is installed for the possibility of disruption and removal of each packer separately from the well. 19. Packer disconnecting installation according to claim 8, characterized in that several hydraulic packers and one mechanical packer, or vice versa, with corresponding shanks and one or more well chambers with removable valves, are lowered into the wellbore for pipe separation and regulation their parameters. 20. Packer disconnecting installation according to claim 8, characterized in that in the well chambers, the removable valves are made in the form of a regulator with one or two opposite fittings. 21. Packer disconnecting installation according to item 16 or 19, characterized in that the mechanical packer is installed loosely, or with the liner resting under it on the lower installed packer, or on the bottom, or on the anchor, or on the existing borehole bore. 22. The packer disconnecting installation according to item 21, wherein the mechanical packer consists of a barrel with an external collar or stop, an adapter, o-rings and seals, a casing with threaded radial holes for shear screws and a tip, while increasing the reliability of the packer an adjustment nut is installed outside the adapter with the possibility of changing the free play of the sealing cuffs and preventing the outflow of the upper one when it is deformed, and the casing on top under the sealing cuffs is made with possible Stu exception bleedout bottom of them, the outer diameter of the adjusting nut is not smaller than the outer diameter of the casing, and the latter, in turn, greater than the diameter of the sealing lips, wherein the barrel and the casing are configured to lock against each other. 23. Packer disconnecting installation according to claim 8, characterized in that the sliding sealing sleeve or sleeve of the packer is additionally made with radial channels in which the supports interacting with the barrel are placed in the form of cams, stoppers or balls, with the possibility of supporting the percussion rope tool from above at the upper position of the sliding sealing sleeve or sleeve, as well as radial movement into the inner bore of the barrel at the lowermost position of the sleeve or sleeve and the release of the impact cable tool bottom through itself, for information on the movement of the sleeve or sleeves down until it stops. 24. The packer disconnecting installation according to claim 8, characterized in that the anchor rigidly connected to the packer barrel consists of a sleeve, a housing with one or more rows of radial channels, spring-loaded movable sealed dies with limited strokes due to the strap installed in them on the body, which form an annular hydraulic channel with the barrel, while to increase the reliability of the packer, hydraulic holes and grooves are made on the top of its trunk, and sealing elements are installed on the latter Options sealingly separating the housing into two parts, the top of which communicates with the cavity through hydraulic packer stem hole, and the lower - a packer through the annular space fluid port, for switching the armature, both the external and the internal overpressure. 25. The packer disconnecting installation according to paragraph 24, wherein the packer barrel is rigidly connected to the armature body between its two divided parts or rows of radial channels, the upper of which communicates with the cavity of the packer barrel through radial channels, and the lower one under the packer space through an annular hydraulic channel, to ensure the operation of the armature, both from external and internal overpressure. 26. The packer disconnecting installation according to paragraph 24, wherein the armature body is made with one or more non-axial hydraulic channels, while in the radial channels of the body under the movable sealed dies are installed pistons, forming hydraulic chambers with them, disconnected from the cavity of the packer barrel and connected through non-axial hydraulic channels to the under-packer space, to ensure the operation of the armature, both from external and internal overpressure. 27. The packer disconnecting apparatus according to claim 24, characterized in that the packer barrel is provided with additional radial holes on top, while two pistons are interconnected between the armature body and the packer barrel, and the cavity formed above the upper piston is hermetically separated and filled fluid, and the cavity between the pistons is hydraulically connected to the cavity of the packer barrel through additional radial holes, and the cavity under the lower piston is hydraulically connected to the under-packer space, to ensure operation of the armature, both from external and internal overpressure. 28. Packer disconnecting installation according to claim 8, characterized in that the disconnector comprises a barrel and a housing with internal grooves, an adapter, a stop with internal and external collars and radial channels or grooves for the retainer, a sliding sealing sleeve with shear screws, o-rings, internal a bore for radial displacement of the latch, external grooves, an inner lower bushing fixed in the initial position and a replaceable upper bushing fixed with a locking ring, a cam lock or ars, sealing cuffs in the form of chevron and fluoroplastic or rubberized metal rings, a tip, stopper or collet to prevent rotation of the barrel relative to the housing, while to increase the reliability of the disconnector in the outer grooves of the sliding sealing sleeve several rows of sealing rings are installed, and between two of them at least one circular conical or cylindrical threaded hole is made on the housing, connecting the inner and outer cavities of the disconnector when placing the sleeve in the casing from the upper fixed to the lower extreme position, to obtain information on the operation of the disconnector, and one or more threaded cylindrical holes with shear screws above the lower or upper outer groove of the sliding sealing sleeve, for the reliability of fixing its initial position when running into the well, sliding the sealing sleeve is made with radial channels placed in them interacting with the barrel supports in the form of cams or balls, with the possibility of support from above on it gift cable tool with the upper position of the sleeve, as well as radial movement into the inner bore of the housing with the lowest position of the sleeve and the release of the shock cable tool down through itself to obtain information about the operation of the disconnector, the adapter is made in the form of a centralizer with an increased outer diameter and its tip is made in in the form of a reentry shoe or a centralizer with a larger outer diameter, the emphasis is made with communicating holes, while the height of the lower sleeve inside the sliding sealing sleeve is larger than the width of its inner bore for the retainer, and the distance from the upper end of the lower sleeve to the stop of the sliding sealing sleeve with its shear screws fixed is not less than the distance between the lower end of the sliding sealing sleeve at its initial position and the outer shoulder of the stop and moreover, when the housing is reentered into the well from the disconnector, a plug (plug) is installed in its circulation threaded hole. 29. Packer disconnecting installation according to claim 8, characterized in that the disconnector consists of one or more parts of the barrel with collars, landing surfaces, radial holes, a casing with internal sealing elements, forming with the barrel upper and lower chambers, hydraulically connected respectively with the cavity the barrel and / or the space behind the casing, an abutment with shear screws, a retainer, a body, an adapter, a cylinder with internal sealing cuffs in the form of chevron and fluoroplastic or rubberized metal in order to increase the reliability of the disconnector between the casing and the barrel, the latch is made with the possibility of fixing the casing relative to the barrel not rigidly at the upper initial position and rigidly or not rigidly at the lower working position, as well as between the casing and the barrel there is a disconnector in the form of an annular piston with its focus on the shoulder of the barrel, having one or more external and internal sealing elements, and a groove is made under the disconnector on the barrel and a mouth is inserted into it ovleno circlip for rigid fixation uncoupler, wherein the adapter shoe and reentering formed as a centralizer. 30. The packer disconnecting installation according to clause 29, characterized in that on the disconnector barrel there are two rows of radial holes hydraulically connecting the corresponding upper and lower sealed chambers, and between them there is a seat for a removable non-return valve to ensure that the disconnector is activated from excess pressure in pipe string. 31. The packer disconnecting installation according to claim 8, characterized in that the pocket of the borehole chamber on top is made with an internal groove for the retainer and, accordingly, the removable valve is made with the upper retainer in the form of a collet or a split spring ring. 32. A packer disconnecting installation for operating wellbores, including one or more wellbore chambers located in a wellbore on a pipe string having an open or plugged lower end, with removable valves for flowing the produced or injected medium, a nipple for a removable valve, and several mechanical packers, located above and between the layers, and at least one of the mentioned mechanical packers is connected to one or more of the elements - an anchor, a telescopic connection, a disconnector , shank, pump and consists of a barrel with an external collar or stop, an adapter, o-rings and cuffs, a casing with threaded radial holes for shear screws and a tip, characterized in that an adjustment nut is installed outside the adapter with the possibility of changing the free travel of the sealing cuffs and eliminating leakage of the upper one during its deformation, and the casing from above under the sealing cuffs is made with the possibility of excluding leakage of the lower one, the outer diameter of the adjusting nut not less than the outer diameter of the casing, and the latter, in turn, is larger than the diameter of the sealing lips, in addition, the barrel and the casing are made with the possibility of fixing relative to each other, while in the well, each mechanical packer is installed freely, or with a stop under it liner to the lower freely installed mechanical packer, or to the bottom, or to the anchor, or to the existing borehole bore. 33. Packer disconnecting installation according to p, characterized in that the mechanical packers are connected to the respective shanks and one or more downhole chambers with removable valves, for separation of the layers and regulation of their parameters. 34. Packer disconnecting installation according to p, characterized in that the telescopic connection is established between the mechanical packers for the sequence and reliability of the failure of the packers when they are lifted. 35. The packer disconnecting apparatus according to Claim 32, wherein the lower mechanical packer is equipped with one or more downhole chambers with removable valves for a lower disconnected object consisting of one or more layers, one or more additional downhole chambers with removable valves installed above the upper mechanical packer for the upper object, also consisting of one or more layers, with the aim of extracting or pumping medium through them during simultaneous and separate operation, or selection of pump fluid from one reservoir through the pipe string and feed it into other downhole injection formation under the chance of fluid flow measurement by the descent of the flowmeter in a pipe string above the pump housing. 36. Packer disconnecting installation according to p, characterized in that in the well chambers removable valves are made in the form of a regulator with one or two opposite fittings. 37. The packer disconnecting installation according to claim 32 or 36, characterized in that the pocket of the borehole chamber on top is made with an internal groove for the retainer and, accordingly, the removable valve is made with the upper retainer in the form of a collet or a split spring ring.

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