RU2636842C1 - Method and arrangement for controlled injection of liquid through formations - Google Patents

Abstract

FIELD: oil and gas industry.

SUBSTANCE: in well on tubing string, an arrangement of underground equipment is lowered including funnel/beveled end, a lower packer device, a deep-well research complex with geophysical cable, a well filter with a sludge trap, an injection valve without choke/blind insert, an upper packer device with a cable inlet. A device for sealing cable inlet and a head reinforcement with cable inlet are installed at the wellhead. An interface is installed on the surface, which makes it possible to read the parameters of the injected liquid in online mode and with the possibility for storing data and transferring data to a removable device and/or transmission of data over the GSM communication. Seating of packer devices and their pressing is carried out. The liquid is fed into pipe string cavity. The parameters of injected fluid injected into the lower formation are measured by means of deep research complex. By subtracting the flow rate of liquid pumped into the lower formation from the total flow rate of the injected fluid, the flow rate of the fluid injected into the upper formation is determined. The diameter of the union insert is selected according to formation injectivity and formation pressure. The union/blind insert of the injection valve is lowered, and controlled injection of liquid is carried out.

EFFECT: providing controlled injection of liquid into two formations by measuring the parameters of injected fluid with minimum number of pulling and running operations.

9 cl, 1 dwg

Description

The invention relates to the oil industry, in particular to equipment for simultaneous and separate injection of fluid into injection wells that have opened two layers. Provides the possibility of using one descent of the layout to carry out an adjustable injection of fluid into the reservoirs, to measure the injection parameters into each reservoir.

The well-known method of Sharifov (RF Patent No. 2253009, IPC E21B 43/14, Fig. 7, publ. 05/27/2005) for simultaneous and separate operation of formations of one injection well, including the descent into the well of a string of pipes, upper and lower packers, landing nodes in in the form of a borehole chamber or a nipple with a removable valve for supplying a working agent through them, respectively, to the lower and upper layers, landing and crimping of the packer. During crimping, the minimum absorption pressure of each formation is determined. The working agent is pumped from the mouth into the cavity of the pipe string at a given pressure, directing it to the upper and / or lower layers through the corresponding valves in the landing nodes. The total consumption of the working agent, wellhead pressure and / or temperature in the cavity of the pipe string and the annulus of the well are measured on the surface. The bottomhole pressure of the upper layer, the pressure in the pipe string and the annulus at the depth of the removable valve in the seat assembly above the packer are determined. Find the flow rate of the working agent injected into the upper layer through a removable valve, subtract it from the total and determine the flow rate of the working agent injected into the lower layer. Compare the actual costs of the working agent for the formations with their design values. Moreover, when they differ, the wellhead pressure is changed and / or removable valves (retrievable control units) from the landing units using cable technology are removed for one or both layers. Their characteristics and / or parameters are determined and changed. After that, each removable valve is re-installed in the corresponding landing unit using cable technology and pumping of the working agent through them into the corresponding layers is continued.

The disadvantages of this method is that for the injection of the working agent into the reservoirs, several downhole chambers or nipples are used, while the number of tripping operations required to install and replace removable valves, as well as the metal consumption of the installation are increased, the parameters of the working reagent are measured by lowering the devices in well on the rope, that is, it is instantaneous measurement or the device is left in the well chamber instead of the valve, then information is read out only after lifting the device, i.e. the costs of conducting work on the study of the reservoirs are increasing, and there is no real-time information, the descent of 2 or more borehole chambers is necessary, the chambers are installed on each formation separately, equipped with one or more removable valves, the cable technique changes in one descent only one removable valve, respectively, expensive layout maintenance during its operation in the well.

A device is known for regulating the injection of fluid into formations (RF Patent No. 42858, IPC E21B 43/20, publ. December 20, 2004), consisting of a planting tool, a packer body with an annular ledge, with an elastic cuff, a mandrel, and a throttling unit. The latter is a nozzle plugged at the top with a fitting at the bottom. Below the plug along the perimeter of the nozzle, holes are made connecting the internal space of the device with the well zone. The nozzle is installed inside the landing tool, above the packer. Below the packer is the lower pipe, equipped with a filter, based on the bottom of the well when installing the device.

A disadvantage of the known device is that the injection is controlled only in the lower layer without the possibility of regulating the injection in the upper layer, and also that in order to change the diameter of the nozzle passage channel, the entire device must be completely removed.

A known installation for simultaneous and separate injection of the working agent into two productive formations, comprising well chambers mounted in the production casing of the well on the tubing string, two packers and a plug or fitting nipple with an extractable valve mounted from the lower end of the tubing string . The lower packer is made of hydromechanical action, the upper packer is made of mechanical action with a support unit or hydromechanical action and is equipped with a hydraulic anchor. Both packers have a hole for the passage of the geophysical cable. Downhole chambers are installed first under the lower packer, the second between the lower and upper packers and the third with a circulation valve above the upper packer. The first and second downhole chambers are made with replaceable calibrated fittings for pumping the planned volumes of the working agent into the well, and the third downhole chamber is made with a crimping nipple. On the pipe string are additionally installed pipe and annular pressure and temperature sensors located above the lower and middle borehole chambers, connected in series with each other and with a ground-based recording unit with a geophysical cable, fixed to the pipe string with protectors (RF Patent No. 102368, IPC E21B 43/14, published on 02.27.2011).

A disadvantage of the known device is that it does not allow simultaneous separate and sequential injection of the planned volumes of fluid into the formations through one well, since only the total injectivity of all formations of the well is measured by the wellhead flowmeter.

The known method of simultaneous-separate injection of fluid in the reservoir with the ability to measure the parameters of the injected fluid and installation for its implementation (RF Patent No. 2552405, IPC E21B 43/14, 47/06, publ. 06/10/2015), including the descent into the well on a pipe string installations containing lower and upper packers, centralizers, an injection distribution device equipped with autonomous manometers, installation and pressure testing of packers, fluid supply to the pipe string, calculation of fluid flow rates in the reservoirs based on the differential pressure on the upper and lower fittings, compared the actual fluid flow rate for the formations with the given values, the rise, when they differ, of the extracted part of the injection distribution device to the surface, installation of upper and lower fittings into the seats of the extracted part of the injection distribution device, descent to its landing in the body of the injection distribution device, the implementation of controlled injection liquids, installation lift upon completion of work. The installation consists of a layout of underground equipment lowered into a borehole on a pipe string, including a centralizer funnel, a lower packer, a centralizer sub, an injection distribution device, an upper packer, an extension cord. The injection distribution device consists of a hull and extractable parts, equipped with autonomous pressure gauges. The upper and lower fittings are installed in the recoverable part of the URZ with the possibility of extracting both fittings in one round trip.

A disadvantage of the known device is the ability to read information only when removing an autonomous pressure gauge, and only one parameter is pressure. If it fails, there are no reserve sources for determining the parameters of the injected fluid, which can be used to judge the parameters of the injected into the reservoirs.

Closest to the claimed technical essence and the achieved result (prototype) both in part of the method and in the part of the device, is a method and device for controlled injection of fluid into formations (RF Patent No. 2495235, IPC E21B 43/14, publ. 10.10. 2013), which consists in the fact that a layout including a lower packer, a disconnector, an injection distribution device, an upper packer, a disconnector is lowered into the well on the tubing string. The lower part of the layout is equipped with a funnel or shank, and the upper part of the layout is equipped with an extension. Above the lower and upper packers, a centralizer is installed. Install and compact packers. Lower the depth meter with the plug above the last seat. They supply fluid to the tubing, determine the total fluid flow. Lower the cork into the seat, supply fluid to the tubing, determine the flow rate of the fluid pumped into the lower layer. Subtract it from the total flow rate and find the flow rate of the fluid pumped into the upper reservoir. The actual fluid flow rates for the formations are compared with predetermined values. With their difference, the extracted part of the injection distribution device is lifted to the surface. Install the upper and lower fittings in the seats. The extracted part of the URZ is lowered into the tubing before its landing in the hull of the URZ. Carry out adjustable injection in the reservoirs. To isolate one of the layers, a plug is installed instead of the fitting. At the end of the work, the installation is hoisted. The layout lowered into the borehole on the tubing string includes lower and upper packers, disconnectors, a funnel / liner, centralizers and a fluid distribution device.

The disadvantage of this method and layout is the need to lower the deep flow meter to carry out only one single parameter - measuring the flow rate of the injected fluid without the possibility of recording parameters for a long period, for example a month, in addition, when one of the layers is turned off, errors may occur due to changes in the injection mode. In addition, the descent on the cable of both the flowmeter and the plug, the flowmeter and the extractable part of the injection distribution device has an increased emergency risk in case of sticking and non-disconnection of the extractable part of the URZ from the descent tool.

The disadvantages of this method and layout include mechanical packers, which isolate the layers, which limit the scope of the layout only in vertical trunks or with a small angle of curvature due to their design feature of packing only from the weight of the tubing, which in a horizontal well may not be enough transmitted to packers and isolation of injection intervals may be insufficient.

The problem solved by the invention is the implementation of a controlled injection of fluid into the formations with a minimum number of tripping operations of tubing and cable technology, an increase in the period of reliable operation of the installation, as well as the possibility of controlled injection into two layers in horizontal wells, reducing the risk of complications and accidents during operation with cable technology.

The technical result of the proposed method and installation is to increase the production of reservoirs and the intensification of oil production, rational and efficient use of energy while maintaining reservoir pressure, reducing drilling volumes by using the bore of one well, increasing the profitability of individual wells when connecting other development facilities by making it possible to obtain reliable information on the parameters of the injected fluid over a long time well operation without additional descent - lifting the tubing, without additional descent - lifting the devices with cable technology, in the same injection mode from the wellhead, changing the injection mode for each formation, if necessary, by installing a removable plug-in insert of the injection valve in vertical and horizontal wells, with minimal complications during assembly directional or horizontal wells (packers ABM-PE, ABM-PSK), conducting research with each formation separately, with minimal cost for the wellhead for fluid supply to different layers.

The specified technical result is achieved by the implementation of a method of controlled fluid injection into the reservoirs, including descent into the well on the pipe string of the layout of underground equipment, planting and crimping packers, pumping fluid from the mouth into the cavity of the pipe string, determining the total fluid flow rate injected into the reservoirs, measuring fluid flow rate by one of the strata, determining the flow rate of the fluid in the other stratum by subtracting the previously measured flow rate from the total flow rate, and adjustable injection of fluid through it according to formation layers, in which, according to the invention, an arrangement of underground equipment is lowered into a well on a tubing string including a funnel / beveled end, a lower packer device, an in-depth research complex with a geophysical cable, a downhole filter with a sludge trap, an injection valve without a plug / plug inserts, an upper packer device with a cable entry, a cable entry sealing device and wellhead fittings with a cable entry are installed at the wellhead and an interface on the surface ys, which allows you to read online the parameters of the injected fluid with the ability to save data and transfer to a removable device and / or transfer data via GSM communication, packer devices are planted and crimped, fluid is supplied to the pipe string cavity, measured using an in-depth research complex the parameters of the injected fluid into the lower reservoir, by subtracting the flow rate of the fluid injected into the lower reservoir from the total flow rate of the injected fluid, determine the flow rate of the fluid injected into the upper layer, according to the known characteristics of the layers, the diameter of the inserted insert is selected, the studied / deaf insert of the injection valve is lowered and the adjustable fluid injection is carried out.

In addition, an ABM-PSK type cuff packer with cable entry is used as the upper packer device, and a cuff type packer, such as ABM-PE, is used as the lower packer device, and a centralizer is installed above the lower and / or upper packer device.

The technical result is achieved by applying an arrangement for controlled injection of fluid into the reservoirs, including a lower packer device, an injection valve, an upper packer device, which, according to the invention, further includes a downhole filter with a sludge trap and an in-depth research complex with a geophysical cable mounted above the lower packer device below the valve injections, wellhead fittings with a cable entry and a cable entry sealing device at the wellhead, and an interface at the surface, allows one to read in-line injection fluid parameters to store and transfer data to the removable device and / or transmission of GSM data connection.

Moreover, the lower part of the layout is a funnel / beveled end.

In addition, the cuff packer type ABM-PSK can be installed as the upper packer device, and the cuff type packer, for example ABM-PE, as the lower packer device. In addition, a centralizer may be installed above the lower and / or upper packer.

The difference between this technology and the known one is that

1. For one descent of the layout on the tubing, the ability to take several parameters of the injected fluid (pressure, temperature and fluid flow) with the output of readings to the surface and read in real time or transmit data via GSM communication, save the entire download mode in the memory unit. Information about the parameters of the injected fluid flows to the surface constantly. No need to stop the injection to lower the flow meter and other devices. The pressure in the interpacker space can also determine the tightness of the lower packer, if the pressure in the tubing is equal to the pressure in the annulus, then the lower packer is leaky. According to the temperature readings, it is also possible to determine whether injection into the reservoirs occurs. An increase in temperature in the interpacker space, relative to the temperature in the tubing, indicates the absence of injection into the upper layer. In the event of a flow sensor failure, it is possible to calculate the flow rate of the fluid into different reservoirs using data from pressure sensors: knowing the diameter, the bore of the inserted insert on each reservoir and the pressure and density of the fluid supplied, it is possible to calculate the amount of fluid supplied separately for each reservoir.

2. The layout includes a downhole filter with a sludge trap, which allows cleaning the supplied liquid from solid suspensions with accumulation in the sludge trap, allowing long-term operation of the well without additional lifting of the assembly to the surface. In the known arrangements, the absence of a downhole filter leads to the deposition of large particles of fluid on the sensors of the deep measuring complex and to incorrect readings of the parameters of the injected fluid.

3. The deep measuring complex, which is a means of measurement, allows you to transfer and save reliable data on the parameters of the supplied fluid: temperature, pressure, flow.

4. The layout may include packer devices ABM-PE and ABM-PSK of the cuff type, which do not require mechanical and hydraulic manipulations for packing and the ability to use the layout for wells with large curvature, and for vertical and directional wells with an angle of up to 45 ° mechanical packer devices installed by axial movement are used.

5. The descent of the injection valve without the plugged-in insert and the fluid supply allows, in addition to reducing the number of tripping operations, to saturate the formations more quickly, and thereby ensure quick operation of the field.

6. The accident rate of the method is reduced due to the descent by the cable technique of only one inserted insert without a flow meter

The layout diagram for controlled injection of fluid into the reservoirs is shown in FIG. one.

The layout includes the following equipment (bottom-up):

1 - beveled end (funnel),

2 - lower packer device,

3 - centralizer

4 - in-depth research complex (GIC),

5 - downhole filter with a sludge trap,

6 - geophysical cable,

7 - injection valve,

8 - top packer device,

9 - centralizer

10 - clams

11 - tubing (tubing),

12 - sealed cable entry device (UGVK),

13 - interface.

The chamfered end (funnel) 1 is designed for uniform flow of fluid into the lower layers. The lower packer device 2 is designed to isolate the lower strata, it is possible to use a packer supported by a well wall of any well-known manufacturer of packers or an ABM-PE lip packer (RF patent No. 163837) for horizontal wells. Centralizers 3 and 9 are used for coaxial placement of equipment on tubing 11 in the well and are used only when working in directional and horizontal wells. An in-depth research complex (GIC) 4, which is a measuring instrument with installed vortex sensors, which allows monitoring the injection parameters: temperature, pressure and the amount of injected liquid. The downhole filter 5 with a sludge trap is designed to clean the supplied fluid and accumulate sludge in a special receiver. A single-core geophysical cable 6 for supplying a signal from the GIC 4 to the interface located at the wellhead 13. The injection valve 7 has the ability to control the amount of fluid supplied through the reservoirs by dumping or lowering a retractable inserted insert from the wellhead into the tubing (not shown in the diagram ) Removing the insert is carried out by cable technology with a special catcher (not shown in the diagram). The upper packer device 8 is designed to isolate the upper layers, made with cable entry, focusing on the lower packer with the upper armature hydraulic or in the form of a packer sleeve type ABM-PSK (RF patent No. 164217, 163121). Clasps 10 were used to fasten the geophysical cable to the tubing along the entire length of the tubing. Tubing 11 is designed to suspend all tools and equipment from the wellhead and have a length depending on the characteristics of the well. The hermetic cable entry device (UGVK) 12 at the wellhead is designed to seal the geophysical cable at the outlet of the well. Interface 13, which allows you to read online the parameters of the injected fluid, with the ability to save data and transfer them to a removable device, also has the ability to transmit data via GSM communication.

The layout depending on the curvature of the well can additionally be equipped with rigid centralizers 3 and 9 located above the packer devices 2 and 8.

The method of controlled injection of fluid into the reservoirs is carried out in the following sequence.

The assembly is run on the tubing in the following composition and sequence: beveled end 1, lower packer 2, in-depth GIC 4 research complex with a logging cable 6 to the wellhead, logging cable 6 is attached to the tubing 11 with 10 clamps, downhole filter 5 with a sludge trap, injection valve 7 without plug / blind insert, tubing 11, upper packer 8 with cable entry, tubing 11 to the wellhead, cable entry sealing device UGVK 12, wellhead fittings with cable entry, interface 13 connected to GIK 4 through a wire ny cable 6 and connected to a power source of 220 V. The interface 13 can be read on-line parameters of injected liquid to store and transfer data to the removable device and / or transmission of GSM data communication is carried out land packer devices and their molding. The tightness of the upper packer is checked by pressure testing in the annular pressure, the tightness of the lower packer is checked by the pressure readings in the interpacker space and in the pipe.

Fluid under pressure from the wellhead is pumped through the tubing to formations separated by packer devices 2 and 8, through the injection valve 7 and the beveled end 1. The total flow rate of fluid supplied to the tubing from the surface is known. GIC 4 is located below the injection valve 7, therefore, using the GIC, the flow rate of fluid supplied to the lower reservoir is determined. The difference between the total flow rate and the flow rate into the lower reservoir is the flow rate of the fluid pumped into the upper reservoir. Without inserted inserts, the amount of fluid is not regulated by the reservoirs, however, it allows to saturate the reservoirs more quickly and thereby ensure the rapid operation of the field.

According to well-known formulas, parameters of the injected fluid (density, injection pressure) and reservoir characteristics (injectivity, reservoir pressure), the required diameter of the inserted insert is selected.

In August 2016, the packer assembly was launched at the NNN well bush of the Tevlinsko-Russkinskoye field KK with the following composition: funnel with a beveled end, tubing73 - 2 pcs., Lower mechanical packer of the PMR-122 type, tubing73 - 2 pcs., Depth Research Complex , Tubing 73 - 1 pc., Downhole filter with a sludge trap, pump valve body (without plugs), tubing 73 - 5 pcs., Top packer PU (KV) -122, tubing 73 - 1 pc., Anchor hydraulic YaG (KV) -122 , Tubing to the mouth - 271 pcs., UGVK, at the mouth an interface connected by a geophysical cable to the geophysical cable, a geophysical cable the entire length of the tubing is attached klyamsami. The upper reservoirs for injection in the interval above 2770 m, the lower reservoirs for injection below 2820 m. After the descent and installation of the layout, we tested the packers, hermetically. The fluid was supplied to the tubing, from the mouth the amount of fluid was 210 m ³ / day, the readings on the interface received from the GIC: Flow rate 140 m ³ into the lower layer, Pressure in the tube 95 atm, in the interpack space 85 atm, temperature 40 ° C. The amount of fluid supplied to the upper reservoir is calculated by the difference between the total flow rate and the flow rate into the lower reservoir: 210-140 = 70 m ³ . A decision was made to reduce injection into the lower layer and increase the volume of injection into the upper layer. They made a descent of the valve insert, using the technique of calculating the supply of 80-100 m ³ into the lower layer, with a nozzle with a diameter of 8 mm to the lower layer. The insert may also be blind for complete isolation of the lower or upper layers. Instead of descent by cable technology, it is also possible to discharge the inserted insert into the tubing 11, where it, under its own weight, reaches the landing seat of the injection valve 7. The fluid was supplied to the tubing. According to the testimony of the interface, the flow rate to the lower layer was 90-93 m ³ / day, and the liquid supply to the upper layer was 115-120 m ³ . The pressure in the tube is 92-95 atm, in the interpacker space - 77-80 atm. Carry out adjustable injection in the reservoirs. The task of increasing the injection into the upper layer was solved without complications and in a short time, for one descent of the tubing and one descent and lifting operation by rope equipment.

When fluid is supplied to the tubing 11, information is sequentially output to the interface 13 on the temperature of the supplied fluid, the pressure in the tubing and valve, the pressure in the annulus, the amount of fluid supplied to the lower layers.

All liquid parameters are reflected in real time on the interface, can be stored on removable media and transmitted via GSM communication to any point. The liquid passing through the well filter with a sludge trap is cleaned, solid suspensions do not settle on the surface of the sensors, which increases the life of the downhole equipment without lifting up to several years.

To achieve the goal, the following techniques can additionally be used:

1. For installation in directional or horizontal wells, instead of a packer device with support on the wall of the well, an ABM-PE packer device with a sub-centralizer above the PU is installed, and instead of a packer device with a cable entry, an ABM-PSK packer device with a centralizer is installed higher than PU. These packer devices do not have an anchor device for installation, do not require additional manipulations with the tubing for packing and uncoupling, are easily installed in the horizontal section of the well, and create minimal effort when the assembly is disrupted and removed. They are equipped with reinforced cuffs which, when lowering the assembly, come into contact with the walls of the casing and, due to their construction, create minimal friction resistance. The cuffs are directed with the working part down towards a larger pressure drop. When fluid is supplied to the tubing, the cuffs are pressed against the walls of the casing and isolate the over- and sub-packer space.

2. Centralizers installed above the ABM-PE and ABM-PSK packers center the packers relative to the production string in directional or horizontal wells.

3. The funnel / tapered end serves to evenly supply fluid to the lower layers, and also serves as the beginning of the layout for passing along the entire length of the well.

Thus, the inventive method allows for controlled simultaneously-separate injection of fluid into two layers by providing the possibility of obtaining reliable information about the parameters of the injected fluid during a long period of operation of the well, without additional descent - lifting tubing, without additional descent - lifting devices by rope equipment, in one injection mode from the wellhead, changing the injection mode for each formation, if necessary, by installing a removable plug-in valve insert chki. Ultimately, the method and layout can increase reservoir production and intensify oil production, rationally and efficiently use energy while maintaining reservoir pressure, reduce drilling through the use of one wellbore, and increase the profitability of individual wells by connecting other development facilities. There is the possibility of regulating the injection in vertical, directional and horizontal wells, with minimal complications during layout upgrades, conducting research with each formation separately, with minimal cost at the wellhead for supplying fluid to different layers.

Claims (9)

1. A method of controlled injection of fluid into the reservoirs, including descent into the well on the pipe string of the layout of underground equipment, planting and crimping packers, pumping fluid from the mouth into the cavity of the pipe string, determining the total flow rate of fluid pumped into the reservoir, measuring fluid flow from one of the reservoirs , determining the flow rate of the fluid in another reservoir by subtracting the previously measured flow rate from the total flow rate and the adjustable injection of fluid through it into the corresponding reservoirs, characterized in that the compressor pipes lower the layout of the underground equipment, including the funnel / beveled end, the lower packer device, an in-depth research complex with a geophysical cable, a downhole filter with a sludge trap, an injection valve without a plug / dummy insert, an upper packer device with a cable entry, installed at the wellhead cable entry sealing device and wellhead fittings with cable entry, and on the surface - an interface that allows you to read online the parameters of the injected fluid and with the possibility of saving data and transferring to a removable device and / or transmitting data via GSM communication, packer devices are planted and crimped, fluid is supplied to the pipe string cavity, the parameters of the injected fluid are measured into the lower reservoir using an in-depth research complex, by subtracting the flow rate the fluid injected into the lower reservoir, from the total flow rate of the injected fluid, determine the flow rate of the fluid injected into the upper reservoir, according to the injectivity of the reservoir and reservoir pressure, ametra shtutsirovannoy insertion lowered shtutsirovannuyu / blank insert injection valve and carry adjustable injection fluid. 2. The method according to p. 1, characterized in that as the upper packer device using a packer sleeve type ABM-PSK with a cable entry. 3. The method according to p. 1, characterized in that as the lower packer device using a packer cuff type ABM-PE. 4. The method according to p. 1, characterized in that a centralizer is installed above the lower and / or upper packing device. 5. An arrangement for controlled injection of fluid into the reservoirs, including tubing with a funnel / tapered end, a lower packer device, an injection valve with a plugged / blind insert, an upper packer device, characterized in that the arrangement further includes a downhole filter with a sludge trap and a deep a research complex with a geophysical cable installed above the lower packer device below the injection valve, wellhead fittings with cable entry and a cable entry sealing device wellhead at the surface and - an interface that can read online parameters of injected liquid to store and transfer data to the removable device and / or transmission of GSM data connection. 6. The arrangement according to claim 5, characterized in that the lower part of the arrangement is a funnel / beveled end. 7. The arrangement according to claim 5, characterized in that the cuff packer of the ABM-PSK type is installed as the upper packer device. 8. The arrangement according to claim 5, characterized in that the cuff packer type ABM-PE is installed as the lower packer device. 9. The arrangement according to claim 5, characterized in that a centralizer is installed above the lower and / or upper packer.

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