RU60615U1 - INSTALLATION FOR SIMULTANEOUSLY SEPARATE INFLATION OF A WORKING AGENT IN THREE PRODUCTIVE LAYERS - Google Patents

Abstract

The utility model relates to the oil and gas industry and can be used to maintain reservoir pressure during oil production. Installation for simultaneous-separate injection of the working agent into three productive formations with a planting tool contains equipment mounted in the production casing of the well on the tubing string, including a plug or a planting nipple with an extractable valve, borehole chambers, three packers, a crimping nipple and centralizers, and a plug or a fitting nipple with an extractable valve is installed on the lower end side of the tubing string. An additional landing tool is installed on the tubing string, with the first packer of the mechanical action of the axial installation located between the lower and middle productive strata, the second packer of the mechanical action of the support unit located between the middle and upper productive strata, and the hydraulic action packer located above the upper productive stratum and above it, on the tubing string, a crimping nipple is located, and above the last, on the tubing string, become planting tool is disposed between the packers three centraliser, the downhole camera installed between centralizers one, two cameras are installed downhole below the first packer mechanical action and one axial fitting borehole chamber with circulation valve mounted above the packer hydraulic action. The result is an increase in the efficiency of the technology of simultaneous-separate injection (ARI) of the working agent in several productive horizons.

Description

The utility model relates to the oil and gas industry and can be used to maintain reservoir pressure during oil production.

Known installations for injecting a working agent into a reservoir containing a pipe string with one or more packers and regulators for supplying a working agent (see Mirzadzhanzade A.Kh. book “Technology and technique for oil production” M., Nedra, 1986, or catalog “Equipment for separate operation of multilayer oil and gas wells ”, TsINTIkhimneftemash., 1988, p. 43-45), as well as RU patent No. 22253009, class. E 21 B 43/14, 05.27.2005.

However, the reliability of these installations is not high enough, which is associated with leakage of seals at the junction of the equipment lowered into the well on the pipe string.

The closest to the utility model in terms of technical nature and the achieved result is a unit for simultaneous and separate injection of the working agent into three productive formations, containing equipment mounted in the production casing of the well on the tubing string, including a plug or a fitting nipple with an extractable valve, well chambers , three packers, a crimping nipple and centralizers, and a plug or a landing nip are installed on the tubing string from the lower end spruce retrievable valve (see. the utility model patent RU №52917, Cl. E 21 B 43/14, 27.04.2006).

However, in this installation, the packers are lowered into the well on the tubing string without a planting tool, which allows changing the tubing string without lifting the rig itself, which, as field practice shows, dramatically reduces the reliability of the launch equipment. This is due to the fact that during the operation there are leaks on the threaded seals of the tubing string and the layout of the equipment installed in the well ceases to fulfill its purpose. In the case of the descent of mechanical packers with the installation of a hydraulic packer between them under the upper productive horizon, due to the larger diameter of the hydraulic packer, the likelihood of it jamming during extraction increases, with partial shedding of rock from the upper productive horizon, while it is impossible to set strictly

a fixed load from the pipe string to the upper mechanical packer, which not only reduces its service life, but can also lead to breakage.

The objective of the present utility model is to increase the service life of the installation by changing only the tubing string if they are depressurized and prevent the installation from jamming when it is lifted, as well as increase the service life of mechanical packers by installing a strictly fixed load from them pipe columns.

The technical result achieved by the implementation of the utility model is to increase the efficiency of the technology of simultaneous-separate injection (ARI) of the working agent into several productive horizons (formations) through one injection well in a multilayer field for additional hydrocarbon production.

This problem is solved, and the technical result is achieved due to the fact that the installation for simultaneous and separate injection of the working agent in three productive formations contains equipment mounted in the production string of the well on the tubing string, including a plug or a fitting nipple with an extractable valve, well chambers , three packers, a pressure test nipple and centralizers, and a plug or a landing nipple with an extractable valve are installed on the lower end of the pump-compress column pipes, on the tubing string an additional planting tool is installed, with the first packer of the mechanical action of the axial installation located between the lower and middle productive strata, the second packer of the mechanical action of the support unit located between the middle and upper productive strata, and located above the upper productive stratum hydraulic packer and above it, on the tubing string, there is a crimping nipple, and above the last on the tubing string GOVERNMENTAL pipes installed planting tool is disposed between the packers three centraliser, the downhole camera installed between centralizers one, two cameras are installed downhole below the first packer mechanical action and one axial fitting borehole chamber with circulation valve mounted above the packer hydraulic action.

The effectiveness of the technology in multilayer fields is mainly achieved due to the targeted redistribution and injection of the working agent across injection wells to maintain the design reservoir pressure (RPM) in the formation fluid extraction zone and, due to this, additional hydrocarbon production at the development sites. Disaggregation of terrestrial communications for

pumping a working agent allows to reduce the length and number of pipelines and increase the reliability of their work, especially in the autumn-winter periods due to a decrease in the likelihood of hypothermia and freezing associated with an increase in its volume and pumping speed.

The installation with the landing tool and the upper installation of the hydraulic packer eliminates the rise of the installation when changing the string of tubing and reduces the likelihood of it jamming in the borehole production string.

Due to the directed effect of the injection of the working agent on the displacement of the formation fluid in the direction of the faces of the producing wells, conditions are created for additional hydrocarbon production and maintaining the initial or design formation pressure (RPM), while using this installation for simultaneous-separate injection of the working agent it seems possible to separate the groups reservoirs into separate reservoirs, depending on the conditions and tasks of operation, to ensure the injection of the working agent into several reservoirs of one injection well, to regulate the flow of the working agent for each layer of the injection well by selecting the appropriate fitting or regulator for them in the borehole chamber.

As a result, it is possible to reduce capital investments for drilling new wells, for developing fields by reducing the number and direction of pipelines and building pumping stations and accelerating the development of multilayer fields with a limited number of wells.

The drawing shows the installation diagram for simultaneous-separate injection of the working agent with the landing tool.

The installation diagram shows:

1 - production casing;

2 - tubing string (tubing);

3 - borehole chamber with a circulation valve;

4 - landing tool;

5 - crimping nipple;

6 - hydraulic action packer (upper packer);

7 - centralizers installed between the hydraulic action packer and the second mechanical action packer of the support installation;

8 - downhole chambers with flow controllers or fittings installed between centralizers 7;

9 - the second packer of the mechanical action of the support installation;

10 - centralizers installed between the second packer of the mechanical action of the support unit and the first (lower) packer of the mechanical action of the axial installation;

11 - downhole chambers with flow controllers or fittings located between the centralizers 10;

12 - the first (lower) packer of the mechanical action of the axial installation;

13 - downhole chambers with flow controllers or fittings located under the first packer 12 of the mechanical action of the axial installation;

14 - a cap or a landing nipple with an extractable valve;

15 - upper reservoir;

16 - average reservoir;

17 - lower reservoir.

The installation is assembled in the following sequence from the bottom up: from the bottom to the tubing 2, a plug or a landing nipple 14 with an extractable valve is installed, then the borehole chambers 13, the first packer 12 of the mechanical action of the axial installation, three centralizers 10 with the borehole chambers 11 between them, the second packer of the mechanical action of the support installation 9, three centralizers 7 with downhole chambers 8 between them, a hydraulic packer 6, a crimping nipple 5, a planting tool 4 and above it a downhole chamber 3 with a circulation valve. Before the installation is launched into the borehole, the borehole chambers 8, 11 and 13 are closed with blind plugs.

After the installation is lowered into the well to the design depth with the equipment installed on the tubing string 2 in the above sequence, the first packer 12 of the axial installation mechanical action is installed in the production string by axial up-down movement of the tubing string 2 and unloading the weight of the pipes to the value specified in the technical passport of the first packer 12 of the mechanical action of the axial installation. A “blind plug” is removed with a rope tool from at least one borehole chamber 13 under the first axial unit mechanical action packer 12. The tension of the tubing string 2 select the weight of the tool before it. The packer 12 is pressed by pressure into the annulus with a value admissible for

of this production string 1 or until the pressure of the start of liquid absorption begins, while possible circulation of liquid is observed in the tubing string 2. By unloading the tubing string 2, the second packer 9 of the mechanical action of the support unit is weighed according to its passport data. Install the “blind plug” with the rope tool into the borehole chamber 13 under the first axial installation mechanical action packer 12. A “blind plug” is removed with a rope tool from at least one downhole chamber 11 under the second packer 9 of the mechanical action of the support unit. The packer 9 is pressed by pressure into the annulus with a value admissible for a given production string 1 or until the pressure of the start of liquid absorption is observed, observing a possible circulation of fluid in the tubing string 2. Install a crimping valve in the crimping nipple 5 above the hydraulic packer 6 with a rope tool. Compress the tubing string 2 with the necessary pressure. The crimping valve is removed from the crimping nipple 5 of the packer 6 of hydraulic action by a rope tool. Unpack the hydraulic packer 6 in the production casing 1 by creating excess pressure. Remove the “blind plug” from the at least one downhole chamber 8, under a hydraulic packer 6, with a rope tool. The packer 6 is pressurized with pressure into the annulus of a value acceptable for a given production string 1, observing a possible circulation of fluid in the tubing string 2. Fitting the tubing string 2 to seal the wellhead is carried out, bearing in mind that the discharge of the tubing string the compressor pipes 2 to the hydraulic packer 6 should be within 12-15 tons. The wellhead is sealed. In the borehole chambers 8, 11 and 13, under the packers 6, 9 and 12, the fittings are installed and whether flow controllers are dependent on the planned injection volumes of the working agent. By supplying a working agent at the wellhead, they begin their test injection into formations 15, 16 and 17.

After a test injection, injectivity is determined for individual reservoirs. The simplest and most accurate is the geophysical method, which is carried out by lowering the flow meter into the absorption interval of each reservoir. If, after determining the injectivity, there is a need to adjust the injection volumes of the working agent by productive formations, then with a rope tool, the nozzles or flow regulators are changed.

After a test injection, the supply of the working agent under the specified pressure determined during the test injection at the wellhead through the tubing 2 and downhole chambers 8, 11 and 13 starts pumping the agent into the productive formations 15, 16, 17. After a certain time of pumping the agent, as a rule, from 2 to 10 days, by geophysical or other methods, the injectivity of each reservoir is determined. If the injectivity of one or several layers does not match the specified technological parameters, the diameters of the fittings or flow controllers are calculated and they are replaced by a rope tool. The well is again allowed to pump the working agent.

This useful model can find application in the oil and gas and other industries where liquid is extracted from wells.

Claims (1)

Installation for simultaneous and separate injection of the working agent into three productive formations, containing equipment installed in the production casing of the well on the tubing string, including a plug or a landing nipple with an extractable valve, well chambers, three packers, a crimping nipple and centralizers, and a plug or the landing nipple with an extractable valve is installed from the lower end on the tubing string, characterized in that on the tubing string a planting tool is installed, with the first packer of the mechanical action of the axial installation located between the lower and middle productive strata, the second packer of the mechanical action of the support unit is located between the middle and upper productive strata, and the hydraulic action packer is located above and above the upper productive stratum, on the column tubing, the crimping nipple is located, and above the latter, on the tubing string, a lander is installed, between the packer E is disposed on three centraliser, the downhole camera installed between centralizers one, two cameras are installed downhole below the first packer mechanical action and one axial fitting borehole chamber with circulation valve mounted above the packer hydraulic action.