RU115003U1 - SYSTEM OF PRODUCTION OF RAW MATERIAL FROM THE UNDERGROUND LAYER, CROSSED BY A WELL OF A WELL WITH A LOT OF LATERAL CHANNELS - Google Patents

Abstract

1. A system for extracting raw materials from a subterranean formation traversed by a wellbore with multiple lateral channels, comprising:! a set of side injection channels extending into the subterranean formation from the wellbore; ! a set of side production channels extending into the subterranean formation from the wellbore, the set of side production channels being spaced apart from the set of side injection channels; ! a perforated liner having a jetting nozzle attached thereto, remaining in each of the lateral injection and production channels upon completion; ! separation of injection in the wellbore; ! a wellbore production separation isolated from the injection separation and associated with surface fluid treatment equipment; ! an injection pipeline in the wellbore associated with the injection section; and! production pipeline in the wellbore, isolated from the injection section and associated with the production section. ! 2. The system of claim 1, wherein the wellbore is cased, the system comprising:! a plurality of injection ports and a plurality of production ports defined at spaced apart locations in the well casing; and! wherein a set of a plurality of side injection ports and a set of a plurality of side production ports are configured to pass through the subterranean formation from a plurality of injection ports and a plurality of production ports, respectively. ! 3. The system of claim 1, wherein the wellbore is cased, the system comprising:! at least one section removed from the casing to define at least one open interval; and! moreover, a plurality of side channels for injection and production in the subterranean formation is made with

Description

The utility model relates to the production of heavy oil or minerals from underground oil formations. Namely, the proposed utility model relates to a heavy crude oil production system using steam injection into a plurality of lateral or radial injection channels extending from a corresponding plurality of channels formed in casing pipes or a primary wellbore, or passing from an interval in a wellbore into a formation after removal well casing sections.

It is known that in order to produce a fluid, such as crude oil or minerals, from wells crossing an underground reservoir, multilateral channels are formed from the main or main, usually vertical, wellbore by rotary drilling or expansion of the wellbore, as set forth in US Pat. 4880067, No. 4928767 and reprinted US patent 33660 under the authorship of Jelsma, or by means of hydraulic jet blasting or drilling, as set forth in US patent No. 5853056 and No. 6125949 under the authorship of Landers or in US patent No. 626394 8 and No. 6,668,948, authored by Buckman et al.

However, these devices contain inflexible steel columns and to ensure vertical drilling contain a drill bit. These inflexible steel columns cannot usually be used in deviated sections of wellbores, since they cannot easily follow the line of inclined sections of the wellbore.

In addition, many of the existing underground side channel forming tools include drillstrings using flushing fluids provided with surface controlled pumps. This is disadvantageous due to excessive wear and high maintenance costs, which is due to the very high average injection liquid pressures that are required to develop the required liquid pressure for the side channel jet purge.

Some existing side channel forming systems employ jet drilling systems that direct water at high constant pressure for jet purging through the formation to form side channels. This canal jet drilling process is usually too slow due to the fact that a constant fluid pressure is used. It has been determined that variable or pulsed jet purging of the side channels is faster and more effective for forming side channels. However, for jet purge equipment, including coiled tubing or articulated piping, it is undesirable to develop a pulsed high pressure on the surface to achieve the desired pulsed high pressure in the side channel at a depth of the wellbore. It would be highly beneficial to develop a pulsed high pressure fluid jet fluid in the well environment.

Other such systems include devices that use abrasive fluids to cut a section of the casing and penetrate sideways into the surrounding subterranean formation. The use of abrasives in jet flushing fluids is particularly detrimental to the life of the pumping equipment located on the surface.

Closest to the proposed one is a device for pumping coolant and extracting highly viscous oil from an inclined well, including a casing lowered into an inclined well cemented to an inclined section and provided with two groups of perforations, the first of which is made directly behind the cemented casing section, and the second in its final part, tubing string (tubing), packer, centering and isolating the annular space of the tubing string in horizontal chastke. The inclined section of the well is made upstream of highly viscous oil within the formation, while the casing outside the first and in front of the second group of perforations is provided with additional packers, the tubing string at the end is plugged and the outside on the tubing string in front of the first group of perforation holes of the casing from the mouth a self-sealing cuff was installed, passing through the annular space of the tubing string from the formation to the mouth, and in the tubing string above the self-sealing cuff, the first group p dial openings communicating the inner space of the tubing with an annulus above the self-sealing collar, while a submersible pump is installed in the tubing string above the radial channels, and closer to the end of the tubing string, a second group of radial holes is made behind the packer, communicating the inner space of the tubing string with the annulus of the column Tubing, and in the string of tubing between the two groups of radial holes installed check valve (RF patent No. 2408781, E21B 43/24, 2010).

The disadvantages of this device include a fairly large flow rate of the coolant, the absence of a powerful energy source, as well as some complexity of the heat exposure scheme, which ultimately reduces the efficiency of the development process, increasing unit costs per unit of production.

The objective of the proposed utility model is to increase the reliability of the system, increase reservoir pressure, as well as provide a new effective system for the production of heavy oil or minerals from an underground formation, which facilitates the use in deeper and heavily curved wells for multilateral channel formation in the underground layers surrounding the wellbore wells by pumping a fluid, a gaseous substance, or a gas-liquid mixture into the earth’s reservoir through many lateral injection channels, going laterally or radially from the wellbore, and production from an underground reservoir under development through many lateral production channels, also passing laterally or radially from the wellbore and spaced from the set of injection channels;

The technical result obtained by the implementation of the proposed utility model is:

- the task of separating the injection and separating the production in the wellbore in isolation from each other and so that each of them is appropriately associated with a set of lateral or radial injection channels and production channels that extend from the wellbore into the underground formation;

- the production of heavy oil from an underground oil reservoir by injecting steam into an underground oil reservoir from a surface source through an injection pipeline extending to a compartment in the well that is associated with a plurality of lateral injection channels extending laterally or radially from the wellbore, and production from a well being developed a heavy oil reservoir using a plurality of lateral production channels extending from the wellbore to a production compartment in the well that is isolated from the injection compartment; and

- production of heavy oil or minerals from an underground oil reservoir using lateral injection and production channels, which either pass into the earth’s reservoir from holes or windows that are formed in an open well or casing, or extend from an interval in the wellbore resulting from removing one or more sections of the well, or casing, or an open well in or near the formation being developed.

Many lateral production channels are formed in the subterranean formation from the wellbore and spaced from the injection channels. Lateral production channels are associated with a production unit in the well or casing, which is isolated from the injection unit, for example, by one or more packers. A production pipeline extends from the surface through a borehole or casing to surface treatment equipment. A production pipeline is also associated with separating production through openings or windows in the well or casing or through an interval that exists due to the removal of one or more sections of the well casing.

When the raw material is heavy oil, steam from a source on the surface is pumped into the injection compartment through the injection pipeline and enters the reservoir through the many lateral injection channels. The steam is directed into the formation under steam pressure and causes the heating of heavy oil, thereby reducing its viscosity and allowing it to move or force flow through the formation under steam pressure. Radial production channels are designed to receive heated heavy oil from the formation and conduct it to the production department in the well or casing. A production pipeline extending from the production separation to the surface and having any of a variety of suitable downhole injection systems conducts heated and less viscous heavy oil, any released natural gas, or any water from the formation or water condensed from the vapor into the processing equipment produced fluid, which is located on the surface.

When the extracted raw material is a mineral that can be released from the formation by chemical leaching, the chemical leaching reagent is injected from the source on the surface and is conducted into the formation through an injection pipeline, an injection compartment and a set of radial injection channels, which are mainly located above the lateral production channels.

The essence of the utility model is illustrated by drawings.

The accompanying drawings illustrate only a typical embodiment of a given utility model and therefore should not be construed as limiting its scope, since other equally effective embodiments are allowed for the utility model.

The drawings show:

Figure 1 is a schematic illustration of the lower section of the well.

Figure 2 is a schematic illustration showing a well for injecting steam or a chemical agent through radial channels and another well having similar lateral or radial channels for production from the formation.

FIG. 3 is a schematic illustration showing a mineral production area having a plurality of wellbores, each of which has a plurality of side channels for injecting steam or a chemical agent located in or near the formation being developed and having collection trunks extending sideways through the formation and intersecting with receiving collectors that collect the formation fluid and allow the formation and production of formation fluid.

Figure 4 is a partial sectional view of a well showing holes or windows in a well or casing and side channels extending into the earth formation from holes or windows of casing or from open wellbores or from an open hole section of a well.

5 is a partial cross-sectional view of a well showing a cased hole in a well with an open portion of the well or a remote section of the casing of the well to open the interval of the earth formation, and showing side leaching channels of the mineral or channels provided with linings with injection slots and extending into the earth formation from the wellbore in the open interval.

FIG. 6 is a sectional view of a flushing lining assembly for stabilizing an injection opening.

FIG. 7 is a sectional view showing the lining flushing assembly of FIG. 6 and illustrating a pull-out release unit.

Fig. 8 is a sectional view of a heavy oil production system representing a preferred embodiment of the proposed utility model.

Description of a preferred embodiment of the device.

1 shows a subterranean formation development system 10 including one or more primary boreholes 12 of a well that are cased by a casing string of a well 14. Primary wellbores 12 cross an underground reservoir 16 from which heavy viscous crude oil and natural gas are to be extracted or which contains mineral components that can be mined by a chemical leaching process.

The tubing string 18 for injection passes from the surface through the borehole or casing 14 and is fixed in place by packers 20 and 22 or by any other suitable means for supporting and orienting it in the wellbore. Below, the open end 24 of the injection tubing string 18 is connected to the injection compartment 26 in the well or casing, which is insulated, for example, by packers 22 and 28, which provide insulation in the well or casing.

From the isolated injection compartment 26, there is a set of laterally oriented injection channels or channels 30 and 32 that are formed in the formation being developed 16 and extend from the borehole wall or from a similar set of holes or windows 34 and 36 that are formed in the borehole or casing 14 with appropriate drilling, milling or cutting tools or any other suitable means. In the case of producing heavy crude oil from an underground reservoir 16, steam from a suitable “S” source located on the surface, as shown in FIG. 2, is usually pumped through tubing string 18 for injection into the well injection or casing section 26 14. From the injection branch 26, steam enters the set of injection channels 30 and 32 and enters the underground reservoir, where it heats the heavy crude oil and reduces its viscosity and also increases the pressure in the reservoir. Formation pressure caused by steam pressure causes heated and less viscous crude oil to move through the formation to a lower pressure zone where it can be collected and produced. In most cases, a well pump is provided for pumping the collected produced fluid to the surface; however, in many cases, production from a well is prompted by injection pressure or vapor pressure.

Although only two injection channels 30 and 32 oriented radially or sideways are shown in FIG. 1, it is obvious that any suitable number of injection channels or shafts can be formed, as is evident from the underground mining model of FIG. 3.

For well development, the tubing string 38 for production extends from the surface to the open hole in the well or through the casing string 14 and is fixed by the packer 20 or any suitable anchor device. The lower open end 40 of the production tubing extends below the packer 20 and is open to separate production 42 within the borehole or casing 14, which is isolated by the packers 20 and 22. Typically, the pump should be positioned to pump the collected formation fluid from separation of production through the tubing for output to the surface; however, in some cases, formation pressure increased by steam or the pressure of the injected fluid causes the produced fluid to flow to the surface to the surface fluid processing equipment. Many side channels or production shafts, two of which are shown as 44 and 46, extend into the reservoir 16 from the holes or windows 48 and 50 that are formed in the well or casing. Production channels may not be lined, as shown in Figure 4, or lined with flexible perforated lining as shown in Figure 5, depending on the characteristics of the reservoir being developed. The lateral production channels 44 and 46 can also be formed in one pass by the operation of the sidetracking tool, which is used to form the lateral injection channels 30 and 32. Lateral production channels 44 and 46 are open for separating 42 production wells or casing. As mentioned above, for heavy oil production, heating and formation pressure caused by vapor pressure cause heated and less viscous crude oil to move along the formation into side production channels 44 and 46, which conduct the produced oil and gas through openings or windows 48 and 50 into the compartment 42 casing production wells. When the pump is not in use, then crude oil and gas are forcibly moved by formation pressure into the tubing 38 for production, which conducts it to the surface, where it is then received by equipment “P” on the surface to separate gas and to store, process or transport fluid .

On the right side of FIG. 2, a whole system 52 of injection wells and production wells is shown, comprising a primary wellbore 56 that intersects the underground production section 54. The primary wellbore 56 is open or cased with a casing string 58 of the well. For mineral extraction by chemical leaching, the chemical leaching fluid is usually pumped into the upper set of side channels, and the leached mineral and leaching fluid forming the produced fluid are collected in the lower set of side channels. From a steam or fluid source “S” for injecting chemicals, an injection line 60 conducts steam or chemical components to a controlled valve 64, which is controlled by pressure and / or temperature 68. The injection line 72 passes from the controlled valve 64 of the injected fluid through an open hole in the borehole or casing or open hole 58 in the borehole and is fixed and positioned within the casing string by packers 74 and 76 or any other suitable means for anchoring and positioning its lower end relative to the well or casing. When anchoring and sealing is used with packers 76 and 78, the packers create insulation in the well and install an isolated injection compartment 80 in the well or casing. Injection line 72 is configured to inject steam or chemical components into a sealed or insulated injection compartment 80 and thereby induce injection of steam into the formation through the side injection channels.

Side channels 82 and 84 of the injection pass into the reservoir from holes or windows 86 and 88, which are formed in the borehole or casing and serve to inject the injected steam or chemical components from the sealed or insulated compartment 80 of the injection into the developed reservoir for production from the oil formation or gas or for the extraction of other minerals, for example, by chemical leaching. It should be borne in mind that for steam-activated heavy oil production, steam is pumped into the lower set of side channels and the produced fluid is collected in the upper set of side channels. Conversely, for mineral extraction, the chemical leach component is pumped into the upper set of side channels, and the leached mineral and residual leach fluid that make up the produced fluid are collected in the lower set of side channels. Lateral production channels 81 and 83 also extend from the wellbore to the formation being developed and are spaced from injection channels 82 and 84, as shown. The lateral production channels are connected to the production compartment 85, which is isolated in the borehole by packers 74 and 76. The production pipeline 77 is open to the production compartment 85 and serves to conduct the produced fluid to the production equipment “P”, which is located on the surface. Especially when the production piping system is equipped with a pump for pumping the produced fluid to the surface, a controlled valve 79 and a pressure gauge 81 can be used to monitor and control production.

One or more adjacent wells in the production area, for example, shown generally at 90 on the left side of Figure 2, are likewise provided with side channels 92 and 94 for injecting steam or chemicals and production channels 93 and 95 that extend from the well into the underground well of interest layer. For the production of heavy crude oil or minerals, steam or chemical components injected into the formation through a system of 52 injection wells may be prompted to move through the formation into an adjacent production well 90. The produced components of the well 90 are then enclosed in one or more tubing strings for injection and production, which are isolated in the well or casing with packers and, if necessary, are fixed and positioned in the well or casing with anchor devices or packers, which also serve as a support function for anchoring and orienting tubing strings for injection and production.

Figure 3 shows a schematic illustration 100 in plan, which is part of the layout of the production area, which is particularly suitable for the extraction or development of deposits of mineral components by chemical leaching. The area of heavy oil and natural gas production may be of a similar nature. The production area of FIG. 3 includes a plurality of primary, typically vertical, wells bore 102 that extend from the surface to one or more subterranean formations of interest and are typically at least partially cased by casing strings. A plurality of lateral or radial channels 104, 106, 108 and 110 extend laterally into the reservoir from holes or casing windows that are formed at one or more desired depths of the casing. Steam, in the case of heavy oil, or chemical components, in the case of chemical leaching, are induced to flow from one or more S sources to one or more wells 102 and are pumped into the formation through lateral or radial channels that enter the formation from the well into the order discussed above in connection with FIGS. 1 and 2. Each of the wells may be provided with both injection equipment and production equipment, as shown in FIG. 1, or may be an injection well and production well, as shown in FIG. .2.

For the extraction of minerals, the lateral channels 107, 109 and 111 of the reservoir are usually formed in the lower part of the underground mineral-containing strata and are usually oriented sideways. The collector channels are connected to reservoir reservoirs 114, 115, and 116, which receive and collect leached chemical materials along with the residual leach fluid. The collected fluid is then removed from the reservoir tanks by pumps or any other suitable system for extracting the fluid, and then transfers it to suitable processing or processing equipment that is located on or near the surface of the earth.

4, a cross-sectional view illustrates a wellbore 120 that is cased by well casing 122. The holes shown at 124, 126, and 128 are formed in the casing of the well by any suitable means, and radial channels or channels 130, 132 and 134 extend in the earth formation of interest from the holes or windows of the casing of the well.

As shown in FIG. 5, at 136, a borehole is shown to be lined with casing 138 of a well in a conventional manner. The remote section or interval of the casing of the well is shown, for example, by milling or a similar operation, thereby opening the borehole wall in or near the formation being developed. Side channels or trunks 140, 142 and 144 are shown extending from the wellbore 136 into the subterranean formation. A similar set of side channels or shafts, either for injection or production, will be located above or below the side channels shown in Figures 4 and 5. The vertical spacing of the side channels of injection and production will be determined by the thickness or other factors of the reservoir being developed.

6 and 7, cases are shown where the underground development layer requires support in order to minimize the likelihood of fracture of the formation material in the jet-formed side channels. The proposed utility model also involves the use of equipment and processes for installing liners to support the formation, which are preferably perforated or have slots to allow the flow of injected fluid from the side channels into the developed formation or the flow of produced fluid into the side channels for production. Figure 6 shows a tubular lining 120 with slots, which is preferably made of polyvinyl chloride or any of a variety of polymeric materials having similar characteristics. The tubular lining is provided with many slots for flow or perforation 122, which are located essentially along its entire length.

After the side channels have been formed in the formation, for example, by drilling, hydraulic jet washing or water jetting, the jet washing unit 124 is connected to the leading end of the liner and the fluid supply pipe 126 is connected to the fluid with the jet washing nozzle 128 with using the mechanism 130 release with pulling. Fluid supply conduit 126 is typically formed by means of a flexible conduit that can be launched into the well and bent to transition into side channels that extend from the wellbore. The jet flushing nozzle 128 is provided with a plurality of hydraulic jet nozzles 132, which are arranged to directly inject, at high speed, a fluid, such as water, into the formation in the side channels. The jet nozzle 132 of the jet wash nozzle 128 may be configured to develop a reactive force that causes the jet wash nozzle 128 and liner 122 to move forward from the wellbore into the side channel in response to a jet reaction that occurs in the jet wash nozzle. After sufficient jet flushing has occurred prior to positioning the liner 120 having slots to support the formation all the way to the side channel, a pulling force is applied to the fluid supply line 126, which causes the pull-out release mechanism to be activated to disconnect the connection of the fluid supply line 126 to the nozzle 128 for jet washing. When this happens, the fluid supply pipe 126 is simply removed from the lining having slits and removed from the well. This process is repeated until all desired side channels are provided with liners to support the formation. After this, the shanks prevent the destruction of the formation material in the side channels, and the cuts or perforations of the cladding provide an effective flow of the injected fluid into the formation and ensure the flow of produced fluid from the formation into the side channels.

8, 140 shows a preferred embodiment of a steam-fed heavy oil recovery system according to the proposed utility model. Shown is borehole 142, which is cased with casing 144 in the usual manner. The well or casing is provided with upper and lower sets of holes or windows 146 and 148, or alternatively, part of the casing may be purged, milled, or otherwise formed to open one or more desired intervals in the wellbore. Sets of side injection channels 150 and production side channels 152 are formed with vertical spacing in the surrounding reservoir. Each of the vertically positioned sets of side channels may have any desired number of side channels that extend into the reservoir for development. These side channels can be lined with a lining having slots.

The production unit, shown generally at 154, is installed in the well or casing and can be supported by a casing nozzle 156 that is mounted to the top of the casing at or above surface level. Production unit 154 includes injection line 157 receiving steam or other injected fluid from source “S”, and has an injection line 158 that extends downstream of the well casing. The injection pipeline is opened by perforating 159 a portion of the injection pipeline for the chamber or injection compartment 160, which is located between the spaced packers 162 and 164. The injection pipeline ends in a plug 166, which is located below the bottom element 162 of the packer. The lower part of the end of the injection pipe is displaced so that the tubular part, which is located between the elements of the packer, is essentially centered in the casing of the well.

The production pipe 168 also extends from the casing nozzle 156 through the well or casing, and is positioned by positioning its lower end above the upper packer member 164, and thus in the chamber or production compartment 170. An upper set of production side channels 152 are disposed to deliver the collected production fluid to the production chamber 170. A pump 172 is provided at the bottom of the production pipeline 168 and is provided with upper and lower valve elements 174 and 176 that open and close in response to a differential pressure. Pump 172 may comprise any of a variety of suitable borehole pump systems that energize the pump rocker with electricity or any other suitable method. The discharge unloading pipe 182 extends from the pump and serves to conduct the produced well fluid into conventional surface fluid receiving and processing equipment to separate gas / water and conduct the produced crude oil to a suitable storage and processing facility.

The steam-fed heavy oil production system 140 is located in the well or casing 144 using one or more centralizers 184, thereby positioning the lower end of the injection pipe at a substantially centered position within the injection compartment 160, as well as positioning the packers 162 and 164 in position to effectively isolate contact with the inside of the well or casing. The injection and production pipelines may be spaced apart by connecting devices along their length so that the pipelines do not tend to twist between the surface and the production compartment.

The proposed utility model is as follows:

Side or radial channels are formed in subterranean formations by drilling or hydraulic jet flushing from holes or windows that are formed in the well or casing at a desired depth and in the desired orientation. Alternatively, one or more sections of the well or casing at a depth of the formation being developed may be removed, for example, by a milling operation. It is preferable to run the tool for forming side channels "in one pass" into the well or casing, install it at the desired orientation and anchor either at the bottom of the wellbore or at the desired depth in the wellbore, for example, using packers and anchors. The “one-pass” side channel forming tool can also be selectively moved to two or more vertically spaced locations in the well or casing after forming a plurality of the many side channels without having to remove the tool from the well. This “in one go” feature significantly reduces the time and equipment required to prepare the well for injection of steam or chemical components, or to extract fluid from the formation that the well intersects.

Following the activity forming multilateral channels or shafts, to support the formation in order to minimize the likelihood of blocking the lateral injection and production channels in the formation having slits or perforated liners made of flexible polyvinyl chloride or any of a variety of suitable polymeric materials having similar characteristics, it is washed out in a certain place in each of side channels. When the cladding is correctly positioned in the side channel, traction is applied to the flushing fluid supply line 126 to release the release mechanism by pulling the injection nozzle, whereby the cladding and injection nozzle are in position in each of the side channels. Once this has been done, an injection tubing string adapted to communicate with a steam source or chemical leach components is positioned in the well casing from its lower open end associated with an isolated injection compartment in the well casing or well bore with which radial injection channels of the formation are also associated. The injection compartment is isolated by packers or any other suitable means. Vapor pressure or injection pressure within the injection compartment leads to the fact that steam or chemical components are pumped into the reservoir from the side or radial channels, thereby impregnating and increasing the pressure in the developed reservoir and causing the impregnated fluid to move in the reservoir to the side production channels. The lateral production channels are located relative to the injection channels so that the moving formation fluid is collected in the production channels, and then conducted to the production department in the primary wellbore. From the production branch, fluid is conducted to the surface fluid processing equipment through tubing for production either under the influence of a well pump or under pressure from the fluid being injected.

As should be obvious to specialists in this field of technology, the proposed utility model can easily be produced in other specific forms without departing from its essence and essential features. The present embodiment, therefore, should be considered only as illustrative and non-limiting. The scope of a utility model is indicated by the utility model formula and not by the previous description, and therefore all changes that fall within the range and equivalence range of the utility model formula are intended to be covered by this document.

Claims (4)

1. A system for extracting raw materials from an underground formation intersected by a wellbore with a plurality of side channels, comprising: a set of lateral injection channels passing into the subterranean formation from the wellbore; a set of side production channels extending into the subterranean formation from the wellbore, the set of side production channels being spaced with a set of side injection channels; a perforated lining having a nozzle for jet washing attached to it, remaining in each of the side channels of injection and production at their completion; the injection compartment in the wellbore; the production compartment in the wellbore, isolated from the injection compartment and associated with equipment for processing fluid on the surface; an injection pipeline in a wellbore associated with an injection compartment; and production pipeline in the wellbore, isolated from the injection compartment and connected to the production compartment. 2. The system according to claim 1, in which the wellbore is cased with casing pipes, and the system containing: a plurality of injection channels and a plurality of production channels defined at spaced locations in the well casing; and moreover, a set of many lateral injection channels and a set of many lateral production channels are made with the possibility of passage in the underground reservoir, respectively, from multiple injection channels and multiple production channels. 3. The system according to claim 1, in which the wellbore is cased with casing pipes, and the system containing: at least one section removed from the casing to define at least one open-hole interval; and moreover, a plurality of lateral injection and production channels in the subterranean formation are configured to extend from at least one open-hole interval. 4. The system according to claim 1, in which: each of the flushing nozzles has a plurality of flushing nozzles and is hydraulically started with a leaking flushing fluid to move the perforated liner laterally from the wellbore to a position substantially completely facing the lateral injection or production channel formed by the flushing nozzle.