RU216106U1 - The layout of the simultaneous-separate operation of wells - Google Patents

Abstract

The utility model relates to oilfield equipment, in particular to downhole installations for simultaneous-separate operation of wells. The layout of the simultaneous-separate production and injection consists of two coaxially arranged strings of tubing, an electric centrifugal pump unit, a distribution unit, a mechanical packer, a bypass line, a docking device and wellhead fittings. Liquid production from the upper formation is carried out by installing an electric centrifugal pump, the produced liquid is lifted along the annular space between the tubing, pumping is carried out by internal tubing with a protective coating.

This utility model is aimed at improving the reliability of layouts for simultaneous-separate operation of wells.

Description

The utility model relates to oilfield equipment, in particular to downhole installations for simultaneous-separate operation of wells. The layout of the simultaneous-separate operation of wells is designed for the simultaneous-separate production and injection, consists of two coaxially arranged columns of tubing with a diameter of 89 mm 12 and 48 mm 13, an electric centrifugal pump 2A of size 8, a submersible motor 7 with a diameter of 81 mm with a power cable 16, ball check valve 9, distribution unit 11, mechanical packer 3, bypass line 17 with a diameter of 33 mm, docking device 4 and wellhead fittings 14. clamps 15 in the places of flange connections, bottom fastening 6. The distribution unit 11 is designed for movable connection of the assembly units and separation of the flows of the produced fluid from the upper 5 and lower formation 2. To isolate the layers, a packer assembly 3 with a hydraulic anchor 18 is used, autonomously installed in the well , packer assembly connection with the WSE layout is carried out by means of a docking device 4. The production of fluid from the upper reservoir 5 is carried out by installing an electric centrifugal pump 2A of size 8, the rise of the produced fluid occurs along the annular space between the tubing 89 mm 12 and the tubing 48 mm 13, injection is carried out into the lower reservoir 2 along the tubing 48 mm 13 with an internal protective coating to reduce the rate of corrosion and hydroabrasive wear, then through the bypass line 17 and tubing 60 mm 19. The essence of the utility model is illustrated in Fig. 1.

Technical result:

Improving the reliability of the layout of the simultaneous-separate operation of wells.

The utility model relates to oilfield equipment, in particular to well assemblies for simultaneous-separate operation of wells.

Known bypass system for simultaneous-separate operation [patent for PM No. 183576 U1 RU; E21B 43/14; E21B 17/026 published on 09/26/2018], containing an upper sleeve, made with the possibility of connection from above with a string of lift pipes, and from below with an electric drive pump unit, and a lower sleeve, made with the possibility of connection from above with an electric drive pump unit, and from below with a pipe suspension, at least two columns of tubes with an outer dimension of at least 10 and not more than 25 mm at the top and bottom connected to the glasses and located along the generatrix to the electric drive pump are used as pipes that ensure the movement of fluid between the glasses. As the mentioned pipes, for example, for a well with a casing string with a diameter of 146 mm, in which the technology of simultaneous-separate production from two layers is implemented, up to 3 strings of pipes with an outer dimension of 16 mm and a wall of 2 mm can be used, which are located along the generatrix to the electric size 5 pump with a maximum outer diameter of 103 mm and parallel to two power cables, and for a well with a casing string with a diameter of 168 mm, up to 3 tubing strings with an outer dimension of 20 mm and a wall of 2 mm can be used, which are located along the generatrix to the electric drive pump of size 5 with a maximum outside diameter of 103 mm and parallel to two power cables. At the same time, the internal channels of the tube columns through the internal channels of the upper and lower sleeves are hydraulically connected to the tubing string and the tubing suspension, respectively. Coiled tubing or cut-to-length pipes can be used as tubes, the installation of which is carried out, for example, using a fitting connection.

The disadvantage of this layout is the low service life in corrosive environments due to the small wall thickness of the bypass tubes, the complexity of installing the bypass system, and the bypass line is not load-carrying - accordingly, the load from the underlying equipment is perceived by the upper ESP.

A bypass system of a pumping unit is known [patent for PM No. 125271 RU, E21B 47/00, published on February 27, 2013], consisting of a Y-block with a plug, to one outlet of which a bypass pipe string is suspended by means of a breakaway coupling, connector and nozzles, and to a pump unit is connected to the second outlet through a breakaway coupling and a balancing valve, containing a submersible pump and a submersible electric motor equipped with a support pipe, while the bypass pipe string and the pump unit are fastened together by protectolizers and a seat. This assembly is intended for conducting geophysical surveys of a well with an operating ESP.

On the basis of bypass systems, dual systems have been developed for separate operation of facilities, which includes a dual system with a sealed bypass line, consisting of a fork, a displacement unit, valve and pump nozzles, a sealed bypass load-carrying line and clamps for fastening cable lines, as well as two complete installations of electric centrifugal pump (see the article "Equipment for WEM and bypass systems. Operating experience" JSC "Novomet-Perm" in the magazine "Arsenal Neftedobychi" No. 20 September 2017, p. 26-27).

The disadvantage of this arrangement is the lifting of products along one tubing lift, respectively, to determine the flow rate and water cut by object, it is necessary to stop one ESP.

Known installation for simultaneous-separate production and injection in one well [patent for PM No. 2598948 RU, E21B 43/14, published 10.10.2016], containing two columns of coaxially installed tubing of different diameters, an electric centrifugal pump, a device for separating flows of the injected and withdrawn fluid, a valve on the injected fluid line, a packer for separating the productive and injection layers and wellhead fittings. The disadvantages of this installation are the high corrosion rate of the internal tubing lift, due to the two-sided impact of aggressive environments, as well as the difficulty of extracting the internal tubing lift in case of sprinkling with mechanical impurities contained in the produced water.

Installation according to patent 2598948 RU are the closest in technical essence to the claimed and taken as a prototype.

This utility model is aimed at improving the reliability of the WEM layouts, simplifying dismantling.

The specified technical result is achieved due to:

- separate lifting of well fluid along coaxially arranged tubing strings with a diameter of 89 mm 12 and 48 mm 13;

- application of electric driven centrifugal pump 2A size 8;

- simplifying the fitting and connection of the tubing with the distribution unit 11 due to the clamps 15, which allow for axial movement of the ESP 2A of size 8;

- use of tubing 48 mm 13 with an internal protective coating to reduce the rate of corrosive and hydroabrasive wear;

- when pumping bottom water through the internal lift of the tubing, its sprinkling with mechanical impurities is excluded.

Before the implementation of the layout, it is necessary to carry out geophysical surveys of the technical condition of the production string, scraping in the interval of setting the packer, and gauging with a template-simulator of the layout.

The descent of the layout is carried out in three stages:

1. Installation of a packer assembly consisting of: packer 3 with the possibility of autonomous operation to isolate the productive 5 and the receiving formation 2, tubing, docking device 4, located at a minimum distance from the design depth of the ESP descent 8;

2. Running the assembly on the tubing 89 mm 12 and docking with the packer assembly, as part of ESP 2A size 8 on the tubing 48 mm 13 with a ball check valve 9 placed parallel to the bypass line 17 connected by clamps 15 in the places of flange connections. To reduce the geometrical dimensions of the layout, the body of the tubing is placed in the interval of SEM 7.

3. Running tubing 48 mm 13 with an internal protective coating and docking with a distribution unit.

The packer tightness is determined by comparing the readings of the ESP thermomanometric system and the estimated bottomhole pressure of the injected formation. The tightness of the tubing and distribution unit is determined by crimping the annular space between the tubing 89 mm 12 and the tubing 48 mm 13.

The produced liquid, pumped by ESP 2A of size 8 through tubing 48 mm 13, through the distribution unit 11 rises to the wellhead along the annular space between tubing 89 mm 12 and tubing 48 mm 13, the well flow rate is measured in the AGZU. The injected fluid from the pressure maintenance system is pumped into the under-packer space through the internal tubing lift, the injection volumes are recorded by the wellhead flow meter.

Option 2. The layout of the simultaneous-separate operation of wells is designed for simultaneous-separate production. The production of liquid from the upper formation 21 is carried out by an electric centrifugal pump 2A of size 8. The production of liquid from the lower formation 20 is carried out by an electric centrifugal pump 5 of size 22 with a submersible electric motor 24 with a diameter of 103 mm, in a casing 23. The rise of the produced liquid from the upper formation occurs through the annular space between the tubing 89 mm 12 and tubing 48 mm 13, and from the lower layer along the tubing 48 mm 13. The essence of the utility model is illustrated in Fig. 2.

Technical result:

Improving the reliability of the layout of the simultaneous-separate operation of wells.

The descent of the layout is carried out in three stages:

1. Installation of a packer assembly consisting of: a packer with the possibility of autonomous operation to isolate the layers, tubing, a docking device located at a minimum distance from the design depth of the lower ESP;

2. Running the assembly on tubing 89 mm 12 and docking with packer assembly 3, as part of ESP 2A size 8 on tubing 48 mm 13 with a ball check valve 9 placed parallel to the bypass line 17 with a tubing diameter of 33 mm, connected by clamps 15 in the places of ESP flange connections 22, ESP 5 size 22 with a submersible motor 24 with a diameter of 103 mm in a sealed casing 23, the mating part of the docking device 4.

3. Running tubing 48 mm 13 with internal protective coating and docking with distribution unit 11.

Determination of the tightness of the packer is carried out by comparing the readings of the ESP thermomanometric systems. The tightness of the tubing and distribution unit 11 is determined by pressure gauges installed at the wellhead by closing the valves on the valve 14.

Produced liquid from the upper layer 21, pumped by ESP 2A of size 8 through tubing 48 mm 13, through the distribution unit 11 rises to the wellhead along the annular space between tubing 89 mm 12 and tubing 48 mm 13, produced liquid from the lower layer 20, pumped by ESP 5 size 22 through the bypass line 17 enters the distribution unit 11 and rises to the wellhead along the tubing 48 mm 13, the flow rate for each of the objects is measured in the AGZU.

Claims (1)

The layout of the simultaneous-separate operation of wells, containing two coaxially located tubing strings with a diameter of 89 mm and 48 mm, ESP 2A size, a mechanical packer, an anchor hydraulic, a bypass line with a diameter of 33 mm, a docking device, a casing, wellhead fittings, differing in the design of the distribution node in particular by connecting tubing, using tubing 48 mm with an internal protective coating.

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