RU2664989C1 - Method of eliminating proppant deposition conditions during well completion - Google Patents

Abstract

FIELD: mining.

SUBSTANCE: method of completion of the well, including elimination of the condition of proppant deposition, which occurred on the interval of the productive zone. Method comprises creating a well, and securing at least a lower portion of the well by casing string, as well as installation of a shut-off valve in casing string, while the shut-off valve creates a removable barrier for fluid flow in the barrel. Barrier is removed by moving the shut-off valve in case of proppant deposition. With overcoming of the barrier for the passage of fluid, it is opened to the effect on the length of casing string of the window into the subterranean formation at or below the mark of the shut-off valve. Additional injection is carried out to pump the sludge through exposed windows, at this condition for proppant deposition is eliminated.

EFFECT: technical result consists in improvement of efficiency of well completion.

16 cl, 33 dwg

Description

CROSS RELATION TO RELATED APPLICATIONS

[0001] This application claims priority to the provisional patent application US Provisional Patent Application No. 62 / 059,517, filed October 3, 2014, entitled названием Method For Remediating A Screen-Out During Well Completion ’and US Provisional Patent Application No. 62 / 116,084, registered February 13, 2015, under the name ʺ Method For Remediating A Screen-Out During Well Completionʺ, which are fully incorporated by reference in this document. This application is related to the US Patent Appl. No. 13 / 989,728, registered May 24, 2013, under the name ʺ Autonomous Downhole Conveyance System ’which is published as US Patent Publ. No. 2013/0248174. This application is also related to the US Patent Appl co-pending patent application. No. 13 / 697,769, registered November 13, 2012, entitled emblyAssembly and Method for Multi-Zone Fracture Simulation of a Reservoir, Using Autonomous Tubular Units которая, which is published as US Patent Publ. No. 2013/0062055. Both applications are fully incorporated by reference in this document.

BACKGROUND OF THE INVENTION

[0002] This section presents various aspects of the technique that may be associated with examples of embodiments of the present invention. This consideration may contribute to a better understanding of specific aspects of the present invention. Accordingly, it should be understood that this section must be read in the light of what has been said and not as an acknowledgment of a known technique.

FIELD OF THE INVENTION

[0003] This invention relates generally to the field of work in a wellbore. More specifically, the invention relates to completion methods in which multiple zones of a subterranean formation are fractured in stages.

GENERAL REVIEW OF TECHNOLOGY

[0004] In the drilling of oil and gas wells, a well is performed using a drill bit that is fed down at the lower end of the drill string. After drilling to a predetermined bottom location, the drill string and bit are removed and the wells are cased with casing. In this case, an annular space is formed between the casing string and the surrounding formations.

[0005] Typically, cementing is performed to fill or “pressurize” the annular space of the cement pillars. The combination of cement and casing strengthens the well and provides separation of the layers behind the casing.

[0006] It is common practice to install multiple casing strings with successively decreasing outer diameters in the wellbore. The first column may be called a direction. The direction is used to isolate and protect freshwater aquifers located at a shallow depth from contamination by borehole fluids. Accordingly, this casing is almost always cemented completely from the bottom to the surface.

[0007] The drilling process and the subsequent cementing of casing strings of successively decreasing diameter is repeated several times under direction until the design depth of the well is reached. In some cases, the last casing string is a liner, that is, a casing string that does not have a part extending to the surface. The last casing string, called the production casing string, is also usually cemented at the installation site. In some completion options, the production casing (or liner) has swellable packers or packers outside the casing spaced at selected production intervals. This creates compartments between packers for separation of zones and their target processing for intensification of inflow. In this case, the annular space can simply be filled with sand.

[0008] As part of the completion process, the production casing is perforated at the desired elevation. This means that the transverse holes are shot through the casing and the cement column surrounding the casing. Perforations allow the passage of reservoir fluids into the well. In an embodiment of swellable packers or individual compartments, a firing punch punches the casing, providing an influx of reservoir fluids from the rock formation into the well in the corresponding zone.

[0009] After perforation, fracturing is usually carried out in the corresponding zone. Hydraulic fracturing consists of pumping water with friction reducers or viscous fluids (usually liquefied by shear of non-Newtonian gels or emulsions) into the formation at such high pressures and feed rates that the reservoir rock breaks and forms a network of cracks. Hydraulic fracturing fluid is usually mixed with proppant, such as sand, crushed granite, ceramic balls or other granular materials. The proppant serves to hold the crack (s) open after the hydraulic pressure is released. In the variant of the so-called “low-permeable” or unusual formations, the combination of cracks and injected proppant significantly increases the filtration capacity of the treated reservoir.

[0010] For additional processing of the formation to stimulate the inflow and to clean the near-stem zones at the bottom, the operator can select “Acid treatment” of the formations. Processing is performed by injecting an acid solution into the bottomhole zone of the well and through perforations. The use of an acid treatment solution is particularly preferred when the formation contains carbonate rock. In the work, the completion producing company pumps concentrated formic acid or other acidic composition into the well and directs the fluid to selected production zones. The acid helps dissolve the carbonate material, while opening up the pore channels through which hydrocarbon fluids can pass into the well. In addition, acid helps dissolve the drilling fluid that could enter the formation.

[0011] The use of hydraulic fracturing and acid treatment of the formation to stimulate the flow described above is a routine part of the work in the oil industry, carried out in individual oil and gas bearing reservoirs (or "production zones"). Such productive zones can have up to about 60 meters (100 feet) of total vertical thickness in the subterranean formation. Recently, wells have been completed with horizontal passing through an oil and gas producing formation, with a possible horizontal passage of 5,000, 10,000, or even 15,000 feet (1525, 3050, 4575 m).

[0012] When there are multiple or layered formations subject to hydraulic fracturing, or a very thick oil and gas bearing formation (more than about 40 meters or 131 feet), or in the case of completion of a horizontal well with large waste, more complex processing techniques are required to obtain processing in whole design reservoir. In this regard, the operator company must separate the various zones or sections to ensure not only the perforation of each individual zone, but also its adequate fracturing and processing. With this method, the operator is confident that the fracturing fluid and stimulation stimulation fluids are pumped through each group of perforations and in each productive zone to effectively increase the filtration capacity at each required depth interval.

[0013] Separation of the various zones for pre-operational processing requires stepwise processing of the intervals. The indicated, in turn, includes the use of so-called abduction methods. In the terminology of the oil industry, “lead” means that the injected fluid is diverted from the entrance to one group of perforations so that the fluid mainly enters only a given productive zone. In the event that multiple productive zones are subject to perforation, this requires the implementation of numerous stages of abstraction.

[0014] To isolate selected production zones, various diversion techniques may be employed in the well. In many cases, mechanical devices are used, such as bridge frac plugs, downhole shutoff valves, sliding couplings (known as “frac couplings”), and baffle / plug combinations.

[0015] A problem encountered in some cases during “perforation and fracturing” is the so-called proppant loss. Proppant prolapse occurs when proppant injected as part of a hydraulic fracturing slurry densely fills cracks and perforations in the near-wellbore zone. This creates blockage, so that the continuation of the injection of the suspension into the cracks requires injection pressures that exceed safe limits for the downhole equipment or wellhead equipment. Functionally, this causes interruption in hydraulic fracturing and requires the cessation of pumping and well cleaning before resuming work. During hydraulic fracturing in a horizontal well, proppant loss interrupts well construction and causes cost overruns.

[0016] In the event that the operator pumps the slurry while maintaining a workable perforating gun in the well, the operator is able to eliminate proppant loss by shooting a new group of perforations during pumping. The above can be done if a multi-zone formation treatment technique is used to stimulate the inflow. In this case, the operator transmits a signal to the layout of the bottom of the drill string, which includes various firing perforators having associated charges. Examples of multizone formation treatment techniques for stimulating inflow using such a bottom hole assembly include the JITP method and the Hydraulic Fracturing Method using the annulus behind the flexible tubing (ACT Frac). In these methods, essentially continuous processing of the zones takes place.

[0017] The bottom hole configurations used for the JITP and ACT Frac methods are preferred because they allow the operator to perforate the casing in different production zones and then sequentially separate the corresponding production zones so that the fracturing fluid can be pumped into several production zones in one flight to the well. Fortunately, each of these multi-zone formation treatment techniques for stimulating inflows also makes it possible to create, if necessary, proppant discharge zones for well cleaning by perforating a new rock section (JITP) or simple proppant circulation with leaving a well using a flexible pump the compressor pipe in the wellbore (ACT Frac) in case of proppant loss. At the same time, in more traditional completion variants, where the formation is treated to stimulate the inflow in the same zone or where multiple groups of perforations are processed simultaneously, proppant fallout cases may require replacement of the completion equipment on the surface and significant slowdown of work.

[0018] Not so long ago, a new type of completion procedure has been developed in which so-called stand-alone tools are used. These tools are discharged into the well and are not controlled from the surface; instead, these tools include one or more sensors (such as a casing collar locator) that communicate with the controller on the tool to automatically determine the location in the wellbore. When a stand-alone tool is fed by a pump to the bottom of the well, the controller first of all identifies the design depth and transmits the actuation signal, which determines the response. If the tool is a bridge plug, the plug is installed in the wellbore at the required depth. Similarly, if the tool is a firing punch, one or more detonators are initiated to produce “shots” in the casing and the surrounding subterranean formation. Unfortunately, self-contained firing perforators cannot be pumped into the well when proppant loss occurs; thus, they fall into the class of completion options that require replacement of completion equipment on the surface during proppant loss.

[0019] In addition, it has been found that even the JITP and ACT-Frac procedures are vulnerable to proppant prolapse complications in the uppermost zones at the perforation and fracturing stages. (This is shown in FIG. 1F and described below.)

[0020] Accordingly, there is a need to provide a method for cleaning a well under proppant failure without interrupting the injection process. Additionally, there is a need to create a completion technique that enables the deployment of an autonomous perforating tool in the wellbore even when proppant falls out.

SUMMARY OF THE INVENTION

[0021] The methods described herein provide various advantages when drilling and completing oil and gas wells. Specifically, methods for completing a well are provided.

[0022] In one aspect, a method of completing a well first includes creating a well. The well forms a trunk that extends into the subterranean formation. The well can be made essentially as a vertical well; more preferably, the well is drilled by a directional or even horizontal well.

[0023] The method also includes securing the well with a production casing string. Production casing is assembled from a number of steel pipe links that are screwed end to end.

[0024] The method further includes installing shutoff valves in the production casing. The shutoff valves may be lowered into the casing or embedded in the casing during assembly. Shutoff valves create a removable barrier for the passage of fluid in the barrel. Preferably, the stop valve is a sliding sleeve with a seat that receives the ball, and the ball is dropped from the surface to create a pressure seal on the seat. The clutch is held in place by shear pins, which are cut off when the pressure above the clutch exceeds a predetermined value. This opens the window for processing the zone or stage of processing. If the calculated proppant deposition pressure is exceeded during processing, the additional shear pins holding the saddle must be sheared, releasing the stop valves in the well. Other types of valves may also be used as described below.

[0025] The method also comprises perforating the production casing. The casing is perforated over a length of the first production zone in the subterranean formation. The first productive zone is located at or above the mark of valves. The perforation process involves shooting charges into the casing, piercing through the surrounding cement sheath and penetrating into the surrounding rock skeleton, forming an underground formation. The above is performed using a firing punch in the well.

[0026] The method in the next step includes injecting the suspension into the well. The suspension contains fracturing proppant, which preferably carries a water-based medium.

[0027] The method further includes pumping the suspension under pressure sufficient to move the shutoff valves and to overcome the barrier to the passage of fluid. The above is carried out in response to the occurrence of proppant prolapse conditions in the interval of the first productive zone during suspension injection. The movement of the shutoff valves opens the window to the subterranean formation at a length of the production casing string at or below the mark of the shutoff valve.

[0028] The method further includes additionally pumping the suspension through open windows, while eliminating the condition for proppant to fall above the stop valves.

[0029] In one aspect of the method, the stop valve is a sliding sleeve. In this case, the movement of the shutoff valves to open to the action of the windows on the length of the production casing string includes the movement or “slip” of the sleeve to open the action of one or more windows made in the sliding sleeve. The specified may include cutting the mounting pins.

[0030] In another embodiment, the method further includes installing a fracture baffle at a length of the production casing string. The fracturing wall is located above the sliding sleeve but at or below the mark of the first productive zone. The fracturing baffle may be part of a sub that is screwed into the production casing near the sliding sleeve at the initial stage of descent into the well. The rupture disk is then pumped down the wellbore in front of the slurry. The disk is pumped to a depth directly above the shutoff valves before the disk fits on the fracture baffle. In this embodiment, the rupture disk is configured to rupture under a pressure that is greater than the proppant deposition pressure, but preferably less than the pressure required to move the shutoff valves.

[0031] If necessary, the operator can pump a fluid (such as a water-based fluid) under pressure through an exposed sliding clutch window, creating microscopic cracks in the subterranean formation below the first production zone. The operator performs this step before the pump delivers the rupture disk to the well.

[0032] In another embodiment, the stop valves are the first breakable plug. The first breakout plug must have a first breakout design parameter. Windows are perforations that are installed in the production casing in the second production zone below the first production zone. In this embodiment, the movement of the shutoff valves to open the windows includes the injection of a suspension under pressure that exceeds the calculated breakthrough parameter of the first breakable plug. If necessary, in this embodiment, the method further includes installing a second and third breakable plug at a length of the production casing string at or below the second production zone to create a domino effect in case of multiple proppant drops. The second and third breakthrough plugs must have a breakthrough design parameter that is equal to or greater than the first breakout design parameter.

[0033] In another aspect, the movable stop valve is a ball check valve, and the windows are perforations pre-installed in the production casing in the second production zone below the first production zone. In this case, moving the shut-off valves to open the windows involves injecting the suspension under pressure, which causes the ball to lose its pressure-sealed seal on the seat. The loss of a ball of its working under pressure seal can be created by ensuring the crushing of the ball, ensuring the dissolution of the ball or ensuring the destruction of the ball.

[0034] In a preferred embodiment, perforating the production casing comprises pumping an autonomous firing punch into the well, and firing a firing punch in the interval of the first production zone. An autonomous firing punch arrangement includes a firing punch, a depth gauge for detecting the location of the arrangement in the well, and an on-board controller. “Autonomous firing” means programming the controller in advance to transmit the actuation signal to the firing punch and ensuring firing by one or more detonators when the locator has recognized the predetermined location of the firing punch in the borehole length. In one aspect, the depth gauge is a casing collar locator, and the onboard controller interacts with the casing clutch locator to correlate the casing collar alignment over the length of the well with depth according to an algorithm. The casing coupling locator identifies the coupling by detecting magnetic anomalies along the casing wall.

[0035] It was found that the firing punch, locator, and airborne controller together should be sized and configured to be deployed in the well as an autonomous unit. In this application, “stand-alone unit” means that the layout does not have direct control from the surface. In other words, the tool layout does not receive a signal from the surface indicating the time the tool was activated. Preferably, the layout of the tool is released into the well without a working rope. The layout of the tool either falls due to gravity in the well, or is pumped to the bottom of the well. At the same time, a rope without an electric line, such as a cable rope, can be used if necessary.

[0036] In another aspect, an autonomous firing gun assembly is deployed in the well after eliminating proppant failure conditions. The arrangement of a shooting perforator is used to shoot a new group of perforations in the interval of the first productive zone. Thus, a new hydraulic fracturing can be initiated in the specified production zone.

BRIEF DESCRIPTION OF THE DRAWINGS

[0037] For a better understanding of the present invention, some illustrations, diagrams, and / or flowcharts of the process are attached to the description. It should be noted that the drawings show only selected embodiments of the inventions, not limiting their scope, since the invention may have other equally effective embodiments and applications.

[0038] FIG. 1A - 1F show a sequence of side views of the bottom of the well. The well goes through a completion procedure in which firing punchers and sealing balls for perforations are used in stages. This procedure is well known.

[0039] FIG. 1A shows a well provided with an attachment in the form of an operational casing string. Packers for the annular space are installed along the length of the well to isolate selected underground zones. Zones are indicated by ʺAʺ, ʺBʺ and ʺCʺ.

[0040] FIG. 1B, a perforated zone A of a well is illustrated. Additionally, cracks are formed in the subterranean formation in zone A using hydraulic fracturing by any known technique.

[0041] FIG. 1C, it is illustrated that a plug is adjacent to the packer between zones A and B. Additionally, a firing punch is shown performing new perforations in zone B.

[0042] FIG. 1D illustrates the injection of a fracturing fluid or suspension into a well, with artificial fractures created in the subterranean formation in zone B.

[0043] FIG. 1E, it is illustrated that the sealing balls for the perforations are dropped into the well, as a result of which the perforations in zone B are sealed. Additionally, the firing drill is now shown in zone C. The casing is perforated in zone C.

[0044] FIG. 1F illustrates pumping a fracturing fluid or suspension into a well. Artificial cracks are created in the subterranean formation in zone C.

[0045] FIG. 2A through 2F is a sequence of side views of the bottom of the well. The well goes through a completion procedure in which firing punchers and plugs are applied in stages. This procedure is well known.

[0046] FIG. 2A shows a well with an operational casing string. Packers for the annular space are installed on a segment of the length of the well to isolate selected underground zones. Zones are indicated by ʺAʺ, ʺBʺ and ʺCʺ.

[0047] FIG. 2B illustrates well zone A perforated using a firing punch. The cork is lowered into the well with a firing punch.

[0048] FIG. 2C, it is illustrated that cracks have been formed in the subterranean formation in zone A using fracturing fluid. The proppant is now visible placed in the annular space in zone A.

[0049] FIG. 2D, it is illustrated that the second plug is adjacent to the packer between zones B and C. Additionally, a firing punch is shown performing perforations in zone B.

[0050] FIG. 2E illustrates that a fracturing fluid is pumped into a well with artificial fractures created in a subterranean formation in zone B.

[0051] FIG. 2F, it is illustrated that the third plug is adjacent to the packer between zones B and C. Additionally, a firing punch is shown performing perforations in zone C.

[0052] FIG. 3A to 3F show a sequence of side views of the bottom of the well. The well undergoes a completion procedure in which firing perforators, hydraulic fracturing couplings and discarded balls are used in stages. This procedure is known.

[0053] FIG. 3A shows a well with an operational casing string. Packers for the annular space are installed on a segment of the length of the well to isolate selected underground zones. Zones are indicated by ʺAʺ, ʺBʺ and ʺCʺ.

[0054] FIG. 3B, it is illustrated that the ball is dropped onto a fracture sleeve in zone A.

[0055] In FIG. 3C, it is illustrated that hydraulic pressure is applied to open a fracturing sleeve in zone A by pumping fracturing fluid into a well. Additionally, cracks are created in the subterranean formation in zone A. The proppant is visible placed now in the annular space in zone A.

[0056] FIG. 3D illustrates that the second ball is dropped. The ball sat on the fracturing sleeve in zone B.

[0057] FIG. 3E, it is illustrated that hydraulic pressure is applied to open the fracturing sleeve in zone B by pumping the fracturing fluid into the well. Additionally, cracks are created in the subterranean formation in zone B. The proppant is visible placed now in the annular space in zone B.

[0058] FIG. 3F illustrates that the third ball is dropped. The ball sat on the fracturing sleeve in zone C. Zone C is ready for processing.

[0059] FIG. 4A to 4F show a sequence of side views of the bottom of the well. The well undergoes a completion procedure, in which shutoff valves are used, while actuating or moving shutoff valves opens a window in the production casing in an innovative application.

[0060] FIG. 4A shows a well with a sliding sleeve screwed in line with a production casing. The ball is pumped into the well to actuate the sliding sleeve.

[0061] FIG. 4B illustrates that the ball is seated in a saddle of a sliding sleeve. The clutch is actuated, the window has opened. In addition, hydraulic fluid is pumped into the well to open small cracks.

[0062] FIG. 4C shows another view of the well of FIG. 4A. Here, the rupture disk is pumped down the wellbore.

[0063] FIG. 4D illustrates that the rupture disk sits in the saddle of the septum. The seat is located upstream of the sliding sleeve. In addition, the production casing is perforated above the baffle seat.

[0064] FIG. 4E shows another view of the well of FIG. 4A. Here, the fracturing fluid is pumped down the wellbore and passes through the perforations. Cracks form in the subterranean formation.

[0065] FIG. 4F illustrates that fracturing fluid continues to be pumped down the wellbore in response to the occurrence of proppant prolapse conditions. The injection pressure led to a breakthrough of the rupture disk, allowing the suspension to move down the wellbore and towards open windows.

[0066] FIG. 5A and 5B illustrate an alternative method for completing a perforated well. Here, the rupture disk is again seated in the saddle of the partition. However, instead of using a sliding sleeve, the well is separately perforated below the burst disk.

[0067] FIG. 5A shows a borehole with a rupture disc that sits in a saddle of a septum. The well accepted perforations, both above and below the baffle saddle. In the underground reservoir, hydraulic fracturing is carried out through the upper perforations.

[0068] FIG. 5B shows another view of the well of FIG. 5A. Hydraulic fracturing continues to be pumped down the wellbore in response to the occurrence of proppant prolapse conditions on the upper perforations. The injection pressure led to the breakthrough of the rupture disk, providing the suspension moving down the wellbore and to the lower perforations.

[0069] FIG. 5C shows a well with a ball sinking into a fracture plug. Perforations are located in the wellbore, both above and below the fracture plug. In the underground reservoir, hydraulic fracturing is carried out through the upper perforations.

[0070] FIG. 5D shows another view of the well of FIG. 5C. Hydraulic fracturing continues to be pumped down the wellbore in response to the occurrence of proppant prolapse conditions on the upper perforations. The injection pressure caused a shear of the seat in the plug for fracturing, providing the suspension moving down the wellbore and to the lower perforations.

[0071] FIG. 6A and 6B illustrate another alternative method for completing a perforated well. Here, the bursting disk again sat in the saddle of the partition. Additionally, the second lower rupture disk sat in the saddle of the partition below the lower group of perforations.

[0072] FIG. 6A shows a well with an upper rupture disc that sits on a saddle of an upper baffle. Perforations are placed in the wellbore, both above and below the upper saddle of the baffle. In the underground reservoir, hydraulic fracturing is carried out through the upper perforations.

[0073] FIG. 6B shows another view of the well of FIG. 6A. Hydraulic fracturing continues to be pumped down the wellbore in response to the occurrence of proppant prolapse conditions on the upper perforations. The injection pressure led to a breakthrough of the upper rupture disk, providing the suspension moving down the wellbore and to the lower perforations.

[0074] FIG. 7A and 7B illustrate an alternative method for completing a perforated well. Here, a ball check valve is used in the wellbore. The well is separately perforated below the stop valves.

[0075] FIG. 7A shows a well with a collapsing ball that sits in the saddle. Perforations are placed in the wellbore, both above and below the saddle. In the underground reservoir, hydraulic fracturing is carried out through the upper perforations.

[0076] In FIG. 7B shows another view of the well of FIG. 7A. Hydraulic fracturing continues to be pumped down the wellbore in response to the occurrence of proppant prolapse conditions on the upper perforations. The injection pressure caused the destruction of the ball, providing the suspension moving down the wellbore and to the lower perforations.

[0077] FIG. 8 is a flowchart of a completion method in one embodiment. The method uses shutoff valves, which can be actuated to open to the action of a group of windows below the perforations, while the condition of proppant loss is eliminated.

DETAILED DESCRIPTION OF SOME EMBODIMENTS

Definitions

[0078] As used herein, the term "hydrocarbon" refers to an organic compound that includes mainly, if not exclusively, hydrogen and carbon elements. Hydrocarbons may also include other elements such as, but not limited to, halogens, metals, nitrogen, oxygen and / or sulfur. Hydrocarbons are generally divided into two classes: aliphatic or normal-chain hydrocarbons, and cyclic or closed-chain hydrocarbons, including cyclic terpenes. Examples of hydrocarbon containing materials include any form of natural gas, oil, coal, and bitumen that can be used as fuel or converted to fuel.

[0079] As used herein, the term "hydrocarbon fluids" refers to a hydrocarbon or mixtures of hydrocarbons that are gases or liquids. For example, hydrocarbon fluids may include hydrocarbon or mixtures of hydrocarbons, which are gases or liquids under formation conditions, processing conditions, or ambient conditions (15 ° C to 20 ° C and a pressure of 1 atm). Hydrocarbon fluids may include, for example, oil, natural gas, coal methane, shale oil, pyrolysis oil, oil, pyrolysis gas, coal pyrolysis product, and other hydrocarbons in a gaseous or liquid state.

[0080] As used herein, the terms "production fluids" and "production fluids" refer to liquids and / or gases extracted from an underground formation, for example, an organic-rich rock formation. Produced fluids may include both hydrocarbon fluids and non-hydrocarbon fluids. Operating fluids may include, but are not limited to, oil, natural gas, pyrolysis shale oil, gas for chemical synthesis, coal pyrolysis product, carbon dioxide, hydrogen sulfide and water (including steam).

[0081] As used herein, the term "fluid" refers to gases, liquids and combinations of gases and liquids, as well as combinations of gases and solids and combinations of liquids and solids, and combinations of gases, liquids and solids.

[0082] As used herein, the term "gas" refers to a fluid in the gas phase at a pressure of 1 atm and a temperature of 15 ° C.

[0083] As used herein, the term "oil" refers to a hydrocarbon fluid containing mainly a mixture of condensable hydrocarbons.

[0084] As used herein, the term "subsurface" refers to geological layers below the earth's surface.

[0085] When used in this document, the term "layer" refers to any identifiable underground zone. The formation may be one or more oil and gas bearing layers, one or more hydrocarbon-free layers, a roof and / or sole of any geological formation.

[0086] The terms “zone” or “production zone” refer to a portion of a formation containing hydrocarbons. Alternatively, the formation may be an aquifer.

[0087] For the purposes of this application, the term "production casing" includes a liner or any other tubular product fixed in the wellbore in the interval of the production zone, which may or may not reach the surface.

[0088] As used herein, the term "well" refers to a wellbore made underground by drilling and installing pipes underground. The well may have a substantially circular cross section or a cross section of another shape. As used herein, the term “well”, referring to a wellbore in a formation, may be used interchangeably with the term “wellbore”.

Description of Selected Specific Embodiments

[0089] The inventions are described herein for some specific embodiments. However, although the following detailed description is specific to particular embodiments or applications, it is only illustrative and does not limit the scope of inventions.

[0090] Some aspects of the inventions are described using various figures. In some figures, the top of the drawing faces the surface, and the bottom of the drawing faces the bottom of the well. Although the wells typically undergo completion in a substantially vertical orientation, it is understood that the wells may also undergo completion by being directional and / or even horizontal. When the terms “upper and lower” or “upper” and “lower” or “lower” are used with reference to the drawings or in the claims, they indicate the relative location in the drawing or relative to the conditions of the claims and not necessarily orientation in the ground, since the present the invention can be used regardless of the orientation of the well.

[0091] Completion options in unusual reservoirs have an increased length. Both in vertical and horizontal shafts, such wells require the placement of numerous groups of perforations and numerous fractures. Known completion options, in turn, require the addition of downhole equipment that increases the cost, complexity, and risk of such completion options.

[0092] Several techniques are known for fracturing multiple zones in large well boreholes typical of hydrocarbon production operations. One such technique involves the use of shooting perforators and sealing balls for perforations that are lowered into the well in stages.

[0093] FIG. 1A-1F show a sequence of side views of the lower portion of well 100 with large waste. Well 100 undergoes a completion procedure in which firing punchers 150 and sealing balls 160 for perforations are used in stages.

[0094] First, in FIG. 1A, well 100 is shown. Well 100 is secured by production casing 120. Production casing 120 forms a long row of pipe links screwed end-to-end with threaded connections. Production casing 120 provides a bore 105 for transporting fluids to and from well 100.

[0095] Production casing 120 is located in the surrounding subterranean formation 110. Packers for annular space are installed along the length of the casing 120 to isolate selected subterranean zones. Three illustrative zones are shown in FIG. 1 are indicated as ʺAʺ, ʺBʺ and ʺCʺ. Packers, in turn, are indicated by 115A, 115B, 115C and 115D and, in general, are located between the zones.

[0096] It is required to perform perforation and hydraulic fracturing in each of zones A, B, and C. FIG. 1B illustrates the perforated zone A. The perforations 125A are made by detonating the charges associated with the firing hole punch 150. Additionally, cracks 128A are created in the subterranean formation 110 in zone A. Cracks 128A are created using hydraulic fracturing by any known technique.

[0097] It is noted that in conjunction with the creation of cracks 128A, proppant hydraulic fluid 145 is used. The proppant is usually sand and is used to keep the 128A crack open after the hydraulic pressure is released to the formation 110. It is also noted that after the working fluid 145 is injected, a thin annular gravel filter remains in the area formed between the casing 120 and the surrounding formation 110. The above is seen between packers 115A and 115B. The gravel pack preferably supports the surrounding formation 110 and helps to keep fines from entering the barrel 105.

[0098] In the next step, fracturing of zone B is performed. This is shown in FIG. 1C. In FIG. 1C, it is illustrated that plug 140 is adjacent to packer 115B between zones A and B. Additionally, firing punch 150 is installed in zone B. Additional charges associated with firing punch 150 are detonated to produce perforations 125B.

[0099] Then, as shown in FIG. 1D fracturing fluid 145 is pumped into the bore 105. Artificial cracks 128B are created in the subterranean formation 110 in zone B. In addition, a new perforating gun 150 is lowered into the well 100 and installed in zone C. Sealing balls 160 for the perforations are discharged into the well.

[00100] FIG. 1E illustrates the next step in completing a multi-zone well 100. In FIG. 1E, the sealing balls 160 for the perforations penetrated the barrel 105 and landed in zone B. The sealing balls 160 for the perforations seal the perforations 125B.

[00101] In FIG. 1E, it is also noted that the firing punch 150 is raised in the barrel 100 to zone C. The remaining charges associated with the firing punch 150 are detonated to produce new perforations 125C. After punching, the fracturing fluid 145 is pumped into the barrel 105 behind the firing punch 150.

[00102] Finally, in FIG. 1F illustrates additional injection of fracturing fluid 145 into well 100. Specifically, fracturing fluid 145 is pumped through new perforations 125C in zone C. Artificial fractures 128C are created in subterranean formation 120 in zone C. The explosive charges in firing punch 150 are expended and the firing punch is lifted from well 100.

[00103] The multi-zone completion procedure of FIG. 1A - 1F is known as the Just Perforate Punching (JITP) method. The JITP method is a highly efficient method, due to the fact that the hydraulic fracturing fluid can be fed into the well when the firing hammer is in the well. When perforations are broken and cracks are created, the sealing balls for the perforations are discarded. When the sealing balls for the perforation holes sit on the perforation, the firing hammer drill is shot in the next zone. These steps are repeated for numerous zones until all charges of firing perforators are used up. A new plug 140 is then installed, and the process is started again.

[00104] The JITP method requires small volumes of washing and makes it possible to control proppant deposition in zones. However, the method requires drilling numerous plugs in the well with a large waste. In addition, even this procedure is vulnerable to proppant loss in the uppermost zone at the multi-zone processing stage. In this regard, if proppant prolapse occurs along illustrative zone C during injection, the well should be flushed. This is because the suspension 145 cannot be completely pumped through the perforations 125C and into the formation, due to the presence of sealing balls 160 for perforations in zone B and bridge plug 140 above zone A.

[00105] An alternative completion procedure that is used is a conventional plug and perforation plug and perforation technique. This is illustrated in FIG. 2A - 2F. In the drawings of FIG. 2 shows the installation sequence in side views of the lower part of well 200. Well 200 undergoes a completion procedure in which plugs 240 for perforating and firing perforators 250 are used in stages.

[00106] In FIG. 2A shows a well 200 with a production casing 220 attached. Well 200 is identical to well 100 of FIG. 1A. Well 200 is secured by production casing 220. Production casing 220 provides a barrel 205 for transporting fluids to and from well 200. Production casing 220 is located in the surrounding subterranean formation 210.

[00107] The packers for the annular space are again located along the casing 220 to separate selected subterranean zones identified as ʺAʺ, ʺBʺ and ʺCʺ. Packers, in turn, are indicated by 215A, 215B, 215C and 215D.

[00108] To complete well 200, each of zones A, B, and C is perforated. In FIG. 2B, the perforating gun 250 is lowered into the barrel 205. The perforating gun 250 is installed in zone A. The perforations 225A are created in the production casing 120 by detonating charges associated with the perforating gun 250.

[00109] Together with the firing punch 250, a plug 240A is installed. In practice, the plug 240A is typically lowered into the barrel 205 at the lower end of the firing punch on the wireline 255. In other words, the plug 240A and the firing punch 250 are lowered into the well 200 together before detonating the charges.

[00110] Then, the fracturing fluid 245 is injected into the newly created perforations 225A. Proppant fracturing fluid 245 is injected under pressure to pass through perforations 225A and into formation 210. In this way, artificial fractures 228A are created.

[00111] In FIG. 2C, it is illustrated that cracks 228A were created in subterranean formation 210 in zone A. The proppant is now visible in an annular space in zone A. Thus, a gravel filter is formed in some way.

[00112] In the completion method shown in the drawings of the sequence of FIG. 2, the punching and fracturing process in zone A is repeated in conjunction with zones B and C. FIG. 2D, it is illustrated that the second firing punch 250 and the second plug 240B are lowered into the well 200. The firing punch 250 is installed in zone B and the plug 240B is adjacent to the packer 215B. Additionally, charges associated with the firing punch 250 were detonated by performing new perforations 225B in zone B.

[00113] Then, the fracturing fluid 245 is injected into the newly created perforations 225B. Proppant fracturing fluid 245 is injected under pressure to pass through perforations 225B and into formation 210. In this manner, and as shown in FIG. 2E, create new artificial cracks 228A.

[00114] The “Plug and Perf” process is repeated for zone C. In FIG. 2F, it is illustrated that the third firing hammer drill 250 is lowered into the barrel 205 adjacent to zone C, and the third plug 24 ° C is adjacent to the packer between zones B and C. Additionally, the firing hammer drill 250 is shown to perform perforations in zone C. It is clear that there are cracks (not shown) are then created in subterranean formation 210 in zone C using a fracturing fluid (also not shown).

[00115] To perforate multiple zones, the Plug and Perf process requires the use of numerous separate plugs. These plugs, in turn, must be drilled before operation. Additionally, the “Plug and Perf” process requires large volumes of flushing and is also vulnerable to proppant loss. In this regard, if proppant prolapse occurs in any zone during injection, the well should be flushed. This happens because the suspension cannot be completely pumped through the perforations and into the formation or further down the wellbore due to the presence of a bridge plug (such as a 240C plug) immediately below the project area.

[00116] Another completion procedure that is used includes installing multiple fracturing couplings (or “fracturing couplings”) along the production casing. The above is known as ending “with ball and sleeve”. The completion technique with ball and sleeve is illustrated in FIG. 3A - 3F. In the drawings of FIG. Figure 3 shows a number of side views of the lower part of well 300. Well 300 passes a completion procedure where fracturing couplings 321 are applied in stages.

[00117] The first in FIG. 3A shows well 300. Well 300 is identical to well 100 of FIG. 1A. Well 300 has an operational casing 320 fastener that provides a barrel 305 for transporting fluids to and from well 300. Packers 315A, 315B, 315C 315D for the annular space are installed along the length of the casing 320 to isolate selected underground zones. Zones are indicated by ʺAʺ, ʺBʺ and ʺCʺ.

[00118] In the completion methods shown in the sequences of FIG. 1 and FIG. 2, each of zones A, B, and C is sequentially perforated. However, in the sequence of the completion process of FIG. 3, 321A, 321B, 321C couplings are used for fracturing. Fracturing couplings 321A, 321B, 321C are successively opened using balls 323A, 323B, 323C. The specified provides the opening of windows to the impact on the length of the operational casing string 320.

[00119] Referring now to FIG. 3B, it can be seen that fracturing sleeve 321A is installed in zone A. Ball 323A is dropped into well 300 and sits in a saddle associated with fracturing sleeve 321A.

[00120] In FIG. 3C, it is illustrated that hydraulic pressure is applied to open the fracture sleeve 321A. Woven was produced by pumping hydraulic fracturing fluid 345 into barrel 305. As shown in FIG. 3C, fracturing fluid 345 passes through fracturing sleeve 321A into the annular zone between production casing 320 and the surrounding subterranean formation 310 and into the formation 310 itself. Cracks 328A are created in the subterranean formation 310 in zone A. Additionally, proppant placed in the annular is now visible. space in zone A.

[00121] In the method of completing the sequence of the drawings of FIG. 3, the process of opening the sleeve and hydraulic fracturing in zone A is repeated in conjunction with zones B and C. FIG. 3D illustrates that the second ball 323B is dropped into the well 300 and sits on the sleeve 321B. The 321B coupling is located in zone B.

[00122] In FIG. 3E, it is illustrated that hydraulic pressure is applied to open the fracture sleeve 321B. This is done by pumping hydraulic fracturing fluid 345 into well 300. Cracks are created in subterranean formation 310 in zone B. The proppant is now visible in the annular space in zone B.

[00123] The “ball and sleeve” process is repeated for zone C. FIG. 3F illustrates that the third ball 323C is dropped into the barrel 305. The ball 323C sits on the fracture sleeve 321C adjacent to zone C. It is understood that cracks (not shown) are then created in subterranean formation 310 in zone C.

[00124] The use of couplings 321A, 321B, 321C, as shown in the sequence of FIG. 3 reduces the flushing volumes required for completion. This, in turn, reduces the negative impact on the environment. At the same time, the use of multiple couplings creates a higher risk associated with equipment and a higher risk of proppant loss. If proppant prolapse occurs in any zone during injection, a well flush should be performed. This happens because the suspension cannot be completely pumped through the perforations and into the reservoir, due to the presence of a sealed coupling.

[00125] With the recognition of the need for “high-precision reservoir treatment to stimulate the influx”, the number of stages may increase in the future for a given length of the well. At the same time, the experience of working the formation to stimulate the inflow in one zone showed that when dividing the trunk into smaller areas for processing, the risk of proppant loss increases. This means that the chances of pumping into easily processed rock are reduced. Eliminating the proppant failure for completion only with hydraulic fracturing couplings is very costly and usually involves underground well repair and removal (i.e., destruction) of equipment placed in the well during drilling operations.

[00126] For these and possible other reasons, it is necessary to modify the procedures presented in the processes, the sequence of FIG. 1, the sequence of FIG. 2 and the sequence of FIG. 3. Specifically, the replacement of the borehole plugs and couplings with shutoff valves, which creates a barrier for the fluid, but the barrier for the fluid can be selectively removed using increased injection pressures to open the window passing through the production casing. In this method, the suspension can be pumped through a window that is open when exposed to this. This ensures continuous injection of fracturing fluids in the well, even when proppant prolapse occurs.

[00127] Various methods for creating shutoff valves in the wellbore, which removes the barrier for the passage of fluid at the bottom, are provided and described below.

[00128] In FIG. 4A-4F show a sequence of side views of the lower portion of well 400. Well 400 undergoes a completion procedure that includes perforation and fracturing of the at least one production zone. Well 400 forms a bore 405 that has passed through subterranean formation 410. In the illustrative sequence of FIG. 4, well completions 400 are performed in a horizontal orientation.

[00129] In FIG. 4A, well 400 is shown. Well 400 is being completed with production casing 420. Production casing 420 is a series of steel pipe links screwed end-to-end. Production casing 420 provides a path for fluids to and from well 400.

[00130] The annular zone 415 is located between the production casing 420 and the surrounding rock skeleton of the subterranean formation 410. The annular zone 415 is filled with cement, as is known in the drilling and completion technique. In the case of the use of so-called swellable packers in the annular zone 415 (see, for example, packers 115A, 115B, 115C and 115D, set of drawings of Fig. 1), the annular zone 415 is not cemented.

[00131] Fracturing sleeve 440 is installed in production casing 420. Fracturing sleeve 440 forms a hydraulically controlled stop valve. This shutoff valve may be, for example, a Falcon Hydraulic-Actuated Valve from Schlumberger limited, Sugar Land, Texas. The fracturing sleeve 440 includes a seat 442. The seat 442 is dimensioned to receive the ball 450. As shown in FIG. 4A, ball 450 is dropped and moves down the wellbore 400, as indicated by arrow B, to seat 442. After landing in seat 442, ball 450 should seal through hole 445 in sleeve 440.

[00132] As shown in FIG. 4A, well 400 also includes a baffle saddle 462. The baffle saddle 462 forms a sub that is screwed in line with the production casing 420. The baffle saddle 462 is dimensioned to receive the rupture disc shown in FIG. 4C and 4D at 460.

[00133] In FIG. 4B shows the following view of well 400. Here, ball 450 sat in seat 442 of fracture sleeve 460. Ball 450 provides a substantial pressure seal that creates a fluid barrier in barrel 405.

[00134] In FIG. 4B also illustrates that fracturing sleeve 440 has moved. This means that the ball 450 exerted pressure on the seat 462, causing the sleeve 440 to shift causing one or more windows 455 to act. The pressure is applied by injecting fluid into the well and applying fluid pressure using pumps (not shown) on the surface.

[00135] You can also see that to some extent fracturing has occurred. At least one small fracture 458, or “microcrack”, is created in the subterranean formation 410 as a result of injection of fluids under pressure. Preferably, the fluid is brine or other water-based fluid that invades the near-wellbore zone of the well.

[00136] Below FIG. 4C and 4D are considered together. In FIG. 4C illustrates the installation of a burst disk 460 in the barrel 405. The burst disk 460 is pumped to the bottom of the well, as indicated by arrow D. FIG. 4D, the rupture disk 460 sat in the saddle 462 of the septum. A baffle saddle 462 is located near the fracture sleeve 440 and immediately above the newly exposed flow passage windows 455.

[00137] The rupture disc 460 includes a diaphragm or other pressure sensitive device. The pressure sensitive device has a breakthrough design parameter. When the pressure in the barrel 405 exceeds the calculated breakthrough parameter, the disc 460 should break through, providing a through passage of fluid. Prior to breakthrough, disc 460 creates a barrier to the passage of fluid through barrel 405.

[00138] Also in FIG. 4D shows a new group of perforations 478. Perforations 478 are created passing through casing 420 and into subterranean formation 410. Perforations were shot using a perforating gun (not shown). The firing punch can be a selectively firing firing punch, which produces, for example, 16 shots. The firing punch has associated charges that detonate to produce shots from the firing punch at the surrounding production casing 420. Typically, the firing punch 420 comprises a column cassette with cumulative charges distributed along the length of the firing punch 420 and oriented according to specifications.

[00139] Alternatively, the firing punch may be part of a stand-alone firing punch arrangement, such as described in US Patent Publ. No. 2013/0062055. The layout of the autonomous firing punch is made with the possibility of release into the well 400 and is self-governing. In this regard, the layout does not require a wireline cable and does not need any other mechanical connection or electronic connection with equipment outside the well. The on-site delivery method may include gravity delivery, pumping by a pump or a downhole tractor.

[00140] The layout of a self-contained firing punch generally includes a firing punch, depth gauge, and airborne controller. The depth gauge may, for example, be a casing collar locator that measures magnetic flux when the assembly is lowered into the well. Anomalies in magnetic flux are interpreted as casing couplings located along the length of the casing. The location of the layout in the wellbore becomes known as a result of counting the couplings along the length of the casing when the layout moves down the well.

[00141] The on-board controller is programmed to transmit the drive signal. The signal is transmitted to the firing hammer when the layout has reached the selected location on the length of the well. In the embodiment of FIG. 4B, such a location has a depth that is higher than the fracture sleeve 440 and is in the production zone. To confirm the location, the controller can be pre-programmed according to the well-known casing or formation logs. The controller compares the readings taken in real time by the casing collar locator or other logging tool with a preloaded log.

[00142] The stand-alone arrangement may also include a power source. The power source may be, for example, one or more lithium batteries or a rechargeable battery. The power supply must be located in the casing together with the on-board controller. The firing punch, the location tool, the on-board controller and the battery together are sized and configured to be deployed in the wellbore as an autonomous unit.

[00143] The stand-alone arrangement forms an elongated body. The arrangement is preferably made of a material that is brittle or “brittle”. In this regard, it is made with the possibility of destruction when the charges associated with the firing punch detonate.

[00144] The completion arrangement is preferably equipped with a special tool location algorithm. The algorithm provides the tool with accurate tracking of the casing collars in the path to the selected location at the bottom of the well. US Patent Appl. No. 13 / 989,726, registered May 24, 2013, discloses a method for actuating a downhole tool in a wellbore. This patent application is entitled eth Method of Automatic Control and Positioning of Autonomous Downhole Tools ʺ. The application is published in the publication US Patent Publ. No. 2013/0255939.

[00145] According to the publication of US Patent Publ. No. 2013/0255939, the operator must first obtain the casing collar locator (LM) locator dataset from the well. The foregoing is preferably accomplished using a conventional casing collar locator. The casing collar locator (LM) is lowered into the well using a wireline or electric cable to detect magnetic anomalies along the length of the casing. The LM data set correlates continuously recorded magnetic signals with the measured depth. More specifically, the depths of the casing sleeves can be determined based on the length and speed of the wireline cable pulling the wireline tool LM. In this way, perform the first logging diagram LM for the well.

[00146] In practice, the first LM log is loaded onto a processor that is part of the on-board controller. The on-board controller processes the depth signal data generated by the casing collar locator. In one aspect, the on-board controller compares the generated signals from the position locator with a given physical signature obtained for the well objects from the previous LM log.

[00147] The on-board controller is programmed to continuously record magnetic signals as the stand-alone tool passes the casing couplings. In this way, a second LM log is performed. A processor or an on-board controller converts the recorded magnetic signals of the second LM log using a moving-window statistical analysis. Additionally, the processor compares the transformed second well log with a first step with the first well log during deployment of the downhole tool to correlate values indicating the locations of the casing couplings. This is preferably performed using a comparison algorithm with the sample. The algorithm correlates individual peaks or even groups of peaks representing locations of casing couplings. In addition, the processor is programmed to recognize the selected location in the wellbore, and then transmit the activation signal to the controlled downhole device or tool when the processor has recognized the selected location.

[00148] In some cases, the operator may have access to a wellbore diagram providing accurate information regarding the placement of downhole markers, such as casing sleeves. The on-board controller can then be programmed to count the casing couplings, while determining the location of the tool as it moves down the wellbore.

[00149] In some cases, the production casing may be specifically designed with so-called short links, that is, given links only, for example, 15 or 20 feet (4.6 or 6.1 m) in length, different from the “standard” length selected an operator to complete a well, such as 30 feet (9.2 m). In this case, the on-board controller may use the non-uniform arrangement provided by the short links as a means of checking or confirming the location in the wellbore when moving the completion assembly along the casing.

[00150] In one embodiment, the method further comprises transforming the LM dataset for the first LM log. The indicated is also performed using a statistical analysis using the moving window method. The first LM log is loaded into the processor as the first converted LM log. In this embodiment, the processor compares, with a certain step, a second transformed LM log with a first transformed LM log to correlate values indicating the locations of the casing couplings.

[00151] It is understood that the depth may be any other logging tool. For example, an onboard depth gauge may be gamma ray logging equipment, density logging equipment, neutron logging equipment, or other logging equipment. In this case, the controller compares the readings in real time from the logging tool with a preloaded chart of gamma-ray or neutron logging. Alternatively, the depth gauge may be a location sensor (such as an infrared (IR) reader) that detects markers installed along the casing (such as an IR transceiver). The on-board controller transmits the actuation signal to the firing punch when the location sensor recognized one or more selected markers along the casing.

[00152] In one embodiment, the algorithm interacts with an onboard accelerometer. An accelerometer is a device that measures the acceleration that occurs during free fall. The accelerometer may have functionality on several axes to detect the absolute value and direction of acceleration as a vector quantity. Being in touch with analytical software, the accelerometer provides confirmation of the position of the object.

[00153] Further details for the tool location algorithm are disclosed in US Patent Publ. No. 2013/0255939 mentioned above. This sister application for joint review is fully incorporated by reference in this document.

[00154] To prevent premature actuation, a series of slide gate valves is provided. US Patent Appl. No. 14 / 005,166 describes the layout of a firing punch discharged from wellhead equipment. This application was registered on September 13, 2013, under the name ʺ Security System for Autonomous Downhole Tool ’. The application was published as US Patent Publ. No. 2013/0248174. FIG. 8 and the corresponding consideration of gate valves in this published application are incorporated herein by reference.

[00155] After shooting perforations, the operator begins hydraulic fracturing. In FIG. 4E shows the movement of slurry 470 through a bore 405. The slurry is pumped to the bottom of the well as indicated by arrows S. When slurry 470 reaches perforations, the slurry invades subterranean formation 410, creating tunnels and microcracks 478 in the rock.

[00156] It is noted that the rupture disk 460 prevents the suspension from moving downward into the windows 458 for the passage of flow in the fracture sleeve 440. It is important that the burst disk 460 is made with a design parameter of the breakthrough, the value of which is higher than the design pressure of the fracturing. Ideally, the completion operator or engineer should determine the estimated fracture pressure in advance based on geomechanical modeling, field data and / or from field experience. A burst disk having a breakthrough design parameter with a value well above the fracture pressure is selected to prevent an emergency breakthrough during injection.

[00157] Finally, in FIG. 4F illustrates proppant prolapse conditions. Sand or other proppant densely filled the perforations 475 and cracks 478, even to the point where the additional suspension can no longer be pumped. This occurs when the water (or other) carrier goes into the reservoir, leaving sand particles in place.

[00158] The surface operator must recognize that a proppant loss condition has occurred while observing the operation of the surface pumps. In this regard, the pressure should increase rapidly in the well, giving readings of rapidly growing pressure on the surface. In normal operations, the operator is required to reduce the injection speed to prevent the pressure in the barrel from exceeding the calculated breakout parameter and maximum circumferential and tensile stresses in the casing and to prevent damage to the ground shutoff valves. The operator can then expect the well to flow back using bottomhole pressure to push the proppant-saturated slurry back from the well and to the surface. In known procedures, if the speed is insufficient, the proppant should be deposited in the casing and at the interval of the heel of the well, creating a proppant bridge that must be removed mechanically in order to continue working. On the other hand, if the pressure decreases too quickly on the surface, a high proppant flow rate can cause significant abrasive damage to the valves and pipe wiring when passing through pipes of much smaller diameter.

[00159] In the innovative method shown in the sequence of the drawings of FIG. 4, the proppant prolapse problem is removed by self-cleaning. In this regard, the overpressure created by pumping and hydrostatic pressure of the proppant-saturated suspension during proppant deposition should cause the diaphragm to rupture in the rupture disk 460. Such a case is shown in FIG. 4F.

[00160] As can be seen in FIG. 4F, a through hole 465 is formed in the rupture disk 460. The suspension 470 remaining in the wellbore now moves through the through hole 465. Additionally, the suspension 470 moves through the flow passage window 455 of the fracturing sleeve 440. Thus, the problem of proppant loss is removed.

[00161] In the method shown in the sequence of the drawings of FIG. 4, the rupture disk 460 serves as a stop valve. Shut-off valves “open” in response to pressure in the wellbore that occurs during proppant failure. When the shutoff valve 460 opens, the barrier for the fluid to flow down the wellbore is removed, exposing the flow passage window 455 to the impact. This, in turn, relieves excess pressure in the wellbore.

[00162] It is noted that the rupture disk 460 is actually a possible feature in the sequence method of FIG. 4. The method can be modified by eliminating the rupture disk 460 and simply applying the fracture sleeve 440 as a stop valve that opens. In this case, the sleeve 440 is held in its closed position during punching and fracturing, and opens only if increased pressure occurs in the wellbore, indicating proppant loss. As a result, the flow passage windows 455 open in step of FIG. 4E and not FIG. 4B.

[00163] In another embodiment, the rupture disc is used without a fracture clutch. In FIG. 5A and 5B show such a method.

[00164] First, in FIG. 5A illustrates well 500 undergoing completion. Well 500 passes completion in horizontal orientation. Well completion equipment 500 includes an operational casing 520 cemented in place in the surrounding subterranean formation 510. Possible cement is shown in the annular space 515 around the casing 520.

[00165] In this view, well 500, completed in two productive zones, is indicated with separate perforations, positions 575 'and 575''. The lower productive zone indicated with perforations, position 575 ', has been subjected to hydraulic fracturing. Cracks are shown somewhat schematically at 578 '. The upper productive zone indicated by 575 ″ perforations is also fractured. Cracks are shown at 578 ''.

[00166] In FIG. 5A, the rupture disk 560 is pumped into the barrel 505. The disk 560 sits in the saddle 562 of the partition. The saddle 562 of the partition is installed above the lower productive zone and the corresponding perforations 575 '. Thus, the rupture disk 560 is located between the lower group of perforations 575 'and the upper group of perforations 575''.

[00167] The burst disk 560 includes a pressurized diaphragm 564. The diaphragm 564 has a burst pressure that is higher than the design fracture pressure for the upper perforations 575 ″. Specifically, the disk 560 is configured to rupture in the event of proppant loss during hydraulic fracturing of the upper perforations 575 ''. Thus, the calculated breakout parameter for the bursting disk 560 and its diaphragm 564 is designed to approximate the pressure that should occur in the well bore 500 in the event of proppant failure.

[00168] In FIG. 5B shows that a proppant prolapse condition has occurred. You can see that the suspension 570 moved past the upper perforations 575 and moved along the barrel 505 to the lower group of perforations 575 '. The increase in pressure due to proppant loss caused a rupture of the diaphragm 564 working under pressure, with the creation of a new through hole 565 in the rupture disk 560. The suspension 570 should pass to the lower group of perforations 575 ', as indicated by arrows S. Thus, the rupture disk 560 serves essentially pressure relief valve.

[00169] In another embodiment, a fracturing plug is used that can be cut off in response to a proppant prolapse condition. In FIG. 5C and 5D show such a method.

[00170] First, in FIG. 5C is shown, as in FIG. 5A, well 500 undergoing completion. Well 500 passes completion in horizontal orientation. Well completion equipment 500 includes an operational casing 520 cemented in place in the surrounding subterranean formation 510. Possible cement is shown in the annular space 515 around the casing 520.

[00171] Fig. 5C, the fracture plug 580 is installed together with the casing 520. The fracture plug 580 can be, for example, a Halliburton composite fracture plug with a ball, cage and seat. Fracture plug 580 includes a saddle 584 with dimensions for receiving ball 550. Ball 550 sat in saddle 584 above the lower productive zone and corresponding perforations 575 '. Thus, the ball 550 is located between the lower group of perforations 575 'and the upper group of perforations 575''.

[00172] The fracture plug 580 includes shear pins 582 configured to release in response to fluid pressure in the barrel 505, which is greater than the proppant deposition pressure during fracturing of the upper perforations 575 ″. the indicated pressure is higher than the design fracture pressure for the upper perforations 575 ''. The saddle 584 is held by shear pins that release the stop valves (ball 550 and saddle 584) when the design pressure drop is exceeded, most likely due to proppant falling into the upper 575 ° formation.

[00173] In FIG. 5D shows that a proppant prolapse condition has occurred. You can see that the suspension 570 moved past the upper perforations 575ʺ and moved down the barrel 505 to the lower group of perforations 575 '. The increase in pressure due to proppant loss caused the pins 582 to be cut off on the fracture plug 580, allowing the suspension 570 to move to the lower group of perforations 575 ', as indicated by arrows S. Ball 550 and seat 584 fall in well bore 500. Thus, the device with the ball and seat of the releasable fracture plug 580 serves essentially as a pressure relief valve.

[00174] In another embodiment, two rupture discs are used between the upper and lower productive zones without a fracture clutch. In FIG. 6A and 6B show such a method.

[00175] First, in FIG. 6A shows well 600 undergoing completion. Well 600 passes completion in horizontal orientation. Well completion equipment 600 includes an operational casing 620 cemented in place in the surrounding subterranean formation 610. Possible cement is shown in the annular space 615 around the casing 620.

[00176] In FIG. 6A, well 600 completed completion in the interval of two production zones indicated by separate perforations, positions 675 'and 675''. The lower productive zone indicated by the perforations, position 675 ', was fractured. Cracks are shown somewhat schematically at 678 '. The upper productive zone indicated by 675 '' perforations also underwent hydraulic fracturing. Cracks are shown at 678 ''.

[00177] In FIG. 6A, the upper 660 ″ rupture disc is pumped down the barrel 605. The 660 ″ disc seated on the 662 ″ seat of the upper baffle. The saddle 662 '' of the upper partition is installed above the lower productive zone and the corresponding perforations 675 '. Thus, the rupture disk 660 ″ is located between the upper group 675 ″ and the lower group 675 ″ of perforations.

[00178] The upper rupture disk 660 ″ includes a 664 ″ pressure operated diaphragm. The diaphragm 664 ″ has a burst pressure higher than the design fracture pressure for the formation 610. Specifically, the disk 660 ″ is configured to rupture in the event of proppant failure during fracturing of the upper perforations 675 ″. Thus, the calculated breakout parameter for the rupture disk 660 ″ and its diaphragm 664 ″ is adopted to approximate the pressure in the well 600 in the event of proppant failure.

[00179] Well 600 also includes a lower rupture disk 660 '. The lower rupture disk 660 'was previously pumped down the barrel 605 in front of the upper rupture disk 660''. The lower rupture disk 660 'is sized for passage through the saddle 662''of the upper baffle and landing in the saddle 662' of the lower baffle. The saddle 662 'of the lower partition is installed below the lower productive zone and the corresponding perforations 675'.

[00180] Lower rupture disc 660 'also includes an aperture 664 operating under pressure.' The diaphragm 664 'has a burst pressure higher than the calculated breakout parameter for the upper burst disk 660''. Specifically, the disk 660 'is configured to withstand even the predicted proppant loss during hydraulic fracturing of the upper perforations 675''.

[00181] In FIG. 6B shows that a proppant prolapse condition has occurred. You can see that the suspension 670 moved past the upper perforations 675 '' and moved down the barrel 605 to the lower group of perforations 675 '. The increase in pressure due to proppant loss led to a breakthrough of the pressure-operated diaphragm 664 'in the upper burst disk 660'', which created a new through hole 665''in the burst disk 660''. The lower rupture disk 660 'remains intact and directs the suspension 670 to enter the lower group of perforations 675', as indicated by arrows S.

[00182] As you can see, the first rupture disk 660 ″ again serves essentially as a pressure relief valve.

[00183] In another embodiment, a fracture plug with a removable ball without a fracture sleeve is used. In FIG. 7A and 7B show such a method.

[00184] First, in FIG. 7A shows another well 700 undergoing completion procedures. Well 700 passes completion in horizontal orientation. Well completion equipment 700 includes a production casing 720 cemented in place in the surrounding subterranean formation 710. Possible cement is shown in the annular space 715 around the casing 620.

[00185] Referring to FIG. 7A, well 700 also undergoes completion in the interval of two production zones indicated by separate perforations, positions 775 'and 775''. The lower productive zone indicated by the perforations, position 775 ', was fractured. Cracks are shown somewhat schematically at 778 '. The upper productive zone indicated by 775 '' perforations also underwent hydraulic fracturing. Cracks are shown here at 778 ''.

[00186] In FIG. 7A, a ball check valve 760 is installed in the interval of the subterranean formation 710. The valve 760 comprises a sub that is screwed in line with the production casing 720. The valve 760 has a seat 762, with dimensions for receiving the ball 750. FIG. 7A, it can be seen that the ball 750 was dropped into the barrel 705 and seated in the seat 762, while creating a pressure seal that prevents the fluid from flowing further down the barrel 705.

[00187] The ball check valve 760 is mounted above the lower production zone and the corresponding perforations 775 '. At the same time, valve 760 is located below the upper production zone and the corresponding perforations 775 ''.

[00188] Ball 750 has a unique design of material that collapses in response to pressure. Instead of breakthrough pressure, it has a destructive pressure. Destructive pressure is the pressure at which the ball 750 must collapse or break or dissolve. In the device of FIG. 7A and 7B, this pressure is higher than the design fracture pressure of the subterranean formation 710. Specifically, the ball 750 is configured to fracture if proppant falls during fracturing of the upper perforations 775 ″. Thus, the calculated fracture parameter for ball 750 is adopted to approximate well pressure 700 in the event of proppant failure.

[00189] In FIG. 7A, slurry 770 is pumped down the barrel 705. An upper group of cracks 778 '' is formed. However, in FIG. 7B shows that a proppant failure condition has occurred at the level of these 778 '' fractures. You can see that the suspension 770 moved past the upper perforations 775 '' and moved down the barrel 705 to the lower group of perforations 775 '. The increase in pressure due to proppant loss caused the ball (750) to break, crush, break, and / or dissolve, creating a new through hole 765 in the seat 762. The suspension 770 should move to the lower group of perforations 775 ', as indicated by arrows S. Thus, the ball check valve 760 serves essentially as a pressure relief valve.

[00190] Preferably, for this embodiment, the downstream pressure need not be known to the completion engineer (or operator) to determine the optimal pressure to create the leak path. The processing pressure acts only on the pressure inside the ball 750, which causes its destruction or elimination. This, in turn, allows fluids to bypass the destroyed ball 750.

[00191] The methods of the present invention may be presented in a flowchart. In FIG. 8 is a flow chart of a method 800 for completing a well, in one embodiment. In conjunction with the method, the proppant loss condition in the well is eliminated.

[00192] The method 800 in a first step includes performing a well. This is shown in block 810. The well forms a trunk that extends into the subterranean formation. The well can be made essentially as a vertical well; more preferably, the well is drilled as a directional well or, even more preferably, as a horizontal well.

[00193] Method 800 also includes attaching at least a lower portion of the well to the production casing. This is provided in block 820. The production casing is assembled from a number of steel pipe links that are screwed end to end.

[00194] Method 800 further includes installing shutoff valves in the production casing. This is indicated in block 840. The stop valves create a removable barrier to the flow of fluid in the barrel. Preferably, the stop valve is a sliding sleeve with a seat that receives the ball, and the ball is dropped from the surface to create a pressure seal on the seat. Other types of valves may also be used, as noted below.

[00195] Method 800 also comprises perforating the production casing. This is shown in block 850. The casing is perforated over a length of the first production zone in the subterranean formation. The first productive zone is located at or above the mark of valves. The perforation process involves firing off charges in the casing piercing through holes in the surrounding annular zone (which may or may not have a cement sheath) and in the surrounding rock skeleton, revealing the subterranean formation. The above is performed using a firing punch in the well.

[00196] Method 800 in a next step includes injecting the suspension into the well. This is provided in block 860. The suspension contains proppant, which preferably carries a water-based medium. The suspension is pumped in sufficient volumes and under sufficient pressure to form cracks in the subterranean formation in the interval of the productive zone.

[00197] Method 800 further includes pumping the slurry under pressure sufficient to move the shut-off valves and to overcome the barrier fluid passageway. The indicated can be seen in block 870. Injection is performed in response to the occurrence of a proppant prolapse condition in the interval of the first productive zone during suspension injection. The movement of the shutoff valves opens the window to the subterranean formation at a length of the production casing string at or below the mark of the shutoff valve.

[00198] In one aspect of the method, the stop valve is a sliding sleeve. In this case, moving the shutoff valves to open the windows on the length of the production casing string includes moving or “sliding” the couplings to open the action of one or more windows made in the sliding sleeve. If necessary, the operator can pump fluid (such as a water-based fluid) under pressure through an open window before perforating the casing. This creates microscopic cracks in the subterranean formation below the first productive zone adjacent to the sliding sleeve. In this case, the operator must then mount the rupture disk on top of the sliding sleeve to seal the barrel, eliminating the passage of the suspension during hydraulic fracturing.

[00199] In another embodiment, method 800 further includes installing a fracture baffle over a length of the production casing string. The fracturing partition is located above the hydraulic fracturing stop valves, but at or below the mark of the first productive zone. The fracturing baffle may be part of a sub that is screwed into the production casing near the shutoff valves at the initial stage of descent into the well. The rupture disk is then pumped down the wellbore in front of the slurry. The disk is pumped to a depth immediately above the shut-off valve before the disk fits onto the fracture baffle. In this embodiment, the rupture disk is configured to rupture under a pressure that is greater than the proppant deposition pressure but less than the pressure required to move the shutoff valves.

[00200] In an alternative device, the rupture disk itself is a stop valve. In such a device, valves for hydraulic fracturing are not used; instead, a second bursting seat is installed below the lower productive zone. In this case, the rupture disk, which serves as a stop valve, is the upper breakable plug, and the other rupture disk is located below the breakable plug.

[00201] In another embodiment, the stop valve is a first breakable plug. The first breakout plug must have a first breakout design parameter. Windows represent perforations that are installed in a production casing in a second production zone below the first production zone. In this embodiment, the movement of the shutoff valves to open the windows includes the injection of a suspension under pressure that exceeds the calculated breakthrough parameter of the first breakable plug. If necessary, in this embodiment, the method further includes installing a second and third breakable plug at a length of the production casing string at or below the second production zone to create a domino effect in the event of multiple proppant drops. The second and third breakthrough plugs must have a second breakthrough design parameter that is equal to or greater than the first breakthrough design parameter. When a bursting plug breaks through, a new through hole is created in the bursting plug, and the barrier to the passage of fluid is eliminated.

[00202] In another aspect, the movable shutoff valve is a ball check valve, and the windows are perforations pre-installed in the production casing in the second production zone below the first production zone and below the shutoff valve. In this case, the movement of the shutoff valves to open the windows includes the injection of a suspension under pressure, which causes the ball to lose its working under pressure seals on the saddle. It is possible to create a loss of the ball of its working under pressure seal by ensuring the crushing of the ball, ensuring the dissolution of the ball or ensuring the destruction of the ball.

[00203] Method 800 further includes additionally pumping the suspension through open windows. This is shown in block 880. Thus, the proppant loss condition is eliminated. In other words, the “precipitated” suspension is discharged at the bottom of the well in the “proppant disposal zone”.

[00204] Preferably, method 800 also includes the step of estimating proppant deposition pressure over a production zone interval. This is provided in block 830. This determination step is preferably performed before installing shutoff valves on the length of the production casing string at block 840. The reason is that the operator needs to know what type of shutoff valves to use and shutoff valves with which design pressure or design pressure breakout parameter required.

[00205] In a preferred embodiment of method 800, the step of block 850, which includes perforating the production casing, comprises pumping a self-contained firing punch into the well and firing a firing punch in the interval of the first production zone. An autonomous firing punch arrangement includes a firing punch, a depth gauge for detecting the location of the arrangement in the well, and an on-board controller. “Autonomous firing” means pre-programming the controller to transmit the actuation signal to the firing punch to ensure firing with one or more detonators when the locator has recognized the target location of the firing punch over a length of the well. In one aspect, the depth gauge is a casing collar locator, and the on-board controller interacts with the casing clutch locator to correlate the alignment of the casing couplings over the length of the well with depth. The casing collar locator identifies the couplings by detecting magnetic anomalies along the length of the casing wall.

[00206] In another aspect, the on-board depth gauge is a logging tool, such as a gamma-ray logging tool, density logging equipment, or neutron logging equipment. In this case, the controller compares the readings in real time from the logging tool with a preloaded reservoir log. Alternatively, the depth gauge may be a location sensor (such as an infrared (IR) reader) that detects markers installed with the casing (such as IR transceivers). The on-board controller transmits the actuation signal to the firing punch when the location sensor recognized one or more predetermined markers along the length of the casing.

[00207] It is noted that the firing punch, locator and on-board controller together are sized and configured to be deployed in the well as an autonomous unit. In this application, “stand-alone unit” means that the layout is not directly controlled from the surface. In other words, the layout of the instrument does not respond to a signal from the surface to establish the activation time of the instrument. Preferably, the layout of the tool is released into the well without a working rope. The layout of the tool either falls due to gravity in the well or is pumped to the bottom of the well. At the same time, a working rope without an electric line, such as a cable rope, can, if necessary, be used to lift a stand-alone tool.

[00208] Preferably, the location sensor and the on-board controller operate with software according to the location algorithm discussed above. Specifically, the algorithm preferably uses moving-window statistical analysis to interpret and transform the magnetic signals generated by the casing collar locator (or, alternatively, by a logging tool). In one aspect, the on-board controller compares the generated signals with a given physical signature obtained for downhole objects. For example, logging can be done before deploying a stand-alone tool to determine the location of the casing couplings or the location of formation attributes. Corresponding casing collar depths or formation attributes can be determined based on the speed of the wireline pulling the wireline probe.

[00209] When an autonomous firing punch arrangement is used to complete a horizontal well, the operator can install hydraulically controlled stop valves on the heel of the well. Hydraulically controlled shut-off valves can be installed, for example, directly upstream from a device with a ball and a saddle of a fracture wall. Additional saddles or fracture partition rings, etc., can be installed further upstream of hydraulically operated shutoff valves with dimensions decreasing in order from top to bottom.

[00210] The preparation of a well for treatment is started by pumping the first ball. The ball sits on the lowest or deepest seat below the hydraulically operated stop valves. After landing in the saddle, the pressure in the casing is pumped up to the “design” set point. For example, a surface pressure of 10,000 psi (69 MPa) can be achieved by injecting a water-based fluid. This pressure (acting on the ball sitting in the saddle) causes the opening of hydraulically controlled shutoff valves, which exposes one or more windows to the length of the casing string. When the windows are exposed, hydrostatic and injection pressures create a small hole in the subterranean formation adjacent to the shutoff valves. Fresh water continues to be pumped to create “microcracks” in the formation. Such a crack is shown at 458 in FIG. 4B.

[00211] It is noted that the formation of “microcracks” 458 enables the operator to evaluate in real time the mechanical properties of the rock in the subterranean formation. Specifically, the operator is able to determine the level of pressure generally required to initiate a crack. This can be used as part of the “assessment” phase of block 830 described above. The operator should understand that the proppant deposition pressure should be significantly higher than a given initial fracture pressure. The operator can then select the appropriate sealing means, such as the burst disk 460 of FIG. 4C or the collapsing ball 750 of FIG. 7A, for use in a well.

[00212] The sealing means is pumped down the wellbore until it is seated in saddle 462 (or baffle ring) directly above an open hydraulically operated shutoff valve. Under this condition, the sealing means creates a barrier to the passage of fluid through the wellbore. At the same time, and as described above, the sealing means creates a “pressure relief valve” that can be opened by pressure, and a “water hammer” for proppant loss.

[00213] When a proppant prolapse condition occurs, a hydraulically controlled stop valve can be independently controlled. The shutoff valves open to provide a path for the proppant-saturated fluid in the well to be discharged from the well. The suspension passes through the windows, through the microcrack, and into the underground reservoir with the intensity of the fracture treatment. The new layout of the self-contained firing punch can then be installed in the well, pump down and then used to re-punch the problem area. Alternatively, a new arrangement of a self-contained firing punch can be pumped down the barrel to a new production zone to create perforations in the new zone.

[00214] After perforating the new zone, the well is ready for the next fracture treatment step. This is accomplished then by pumping down another removable sealing means and installing it in the saddle upstream of the hydraulically controlled stop valves. The installation of sealing means should direct fluids under pressure into a new group of perforations.

[00215] It is noted that a well can be developed with multiple saddles. Each saddle is located above its group of perforations, or above the open coupling. Numerous sealing means, or plugs, can be seated one after the other, each one with a higher design pressure. Numerous plugs have the ability to create a “domino effect”, if required, in the conditions of proppant loss. At the same time, a large number of ready-made slurry release zones are created, which ensure that the pump delivers an autonomous firing punch to the well for sequential hole punching, without the need for cable downhole tractors or work on a flexible tubing.

As can be seen, improved methods for eliminating proppant prolapse conditions are provided herein. Although it should be understood that the inventions described herein have been well calculated to achieve the benefits and advantages set forth above, it is understood that the inventions are capable of modifications, variations and changes without departing from their essence.

Claims (56)

1. A method of completing a well, comprising: creating a well containing a wellbore extending into an underground formation; securing at least a lower portion of the well with a production casing; installation of shutoff valves in the production casing, shutoff valves create a removable barrier for the passage of fluid in the barrel; perforation of the production casing in the interval of the first production zone in the subterranean formation, the first production zone is located at or above the mark of the shutoff valves; injection of the suspension into the well, the suspension contains proppant for fracturing; in response to the occurrence of proppant prolapse in the interval of the first productive zone during injection, the suspension is pumped under pressure sufficient to move the shutoff valves and overcome the barrier to the passage of fluid, while opening the window to the underground formation at the mark or below the mark of stop valves; and additional pumping of the suspension through open windows, thereby eliminating the proppant loss condition. 2. The method according to claim 1, in which the completion of the well is carried out in an underground formation in a horizontal orientation. 3. The method according to claim 1, in which the shutoff valve is a ball check valve or ball check valve with a cage. 4. The method according to claim 1, in which: stop valves are a sliding sleeve and moving shutoff valves for opening to the action of windows on a length of the production casing string includes moving a sliding sleeve for opening to the action of one or more windows made in the sliding sleeve. 5. The method according to claim 1, in which: stop valves are a rupture disk; windows are adjacent to the sliding sleeve below the first production area; and The method further comprises: water-based fluid pumping down the wellbore to move the sliding sleeve, while being exposed to the window on the length of the production casing string; before injection of the suspension, additional injection of a water-based fluid under pressure through open windows, thereby creating cracks in the subterranean formation below the first production zone adjacent to the sliding sleeve for receiving the suspension; installing a baffle saddle on a length of the production casing string, the saddle is located above the sliding sleeve, but at or below the mark of the first productive zone; feeding the rupture disk by the pump down the wellbore in front of the suspension to a depth near the stop valves; and landing of the rupture disk on the saddle of the partition, this creates a barrier to the passage of fluid; and the movement of the shut-off valve comprises a breakthrough of the rupture disk, while the rupture disk is made to rupture under pressure, which is greater than the proppant loss pressure. 6. The method according to claim 1, in which: stop valves are the first breakthrough stopper having a first breakout design parameter; windows are perforations installed in the production casing in the second production zone below the first production zone; and the movement of the shutoff valves to open the windows contains the injection of a suspension under pressure, which exceeds the calculated breakthrough parameter of the first breakable plug. 7. The method according to claim 6, further comprising the installation of the second breakable plug on the length of the production casing string at or below the mark of the second productive zone, the second breakthrough plug has a second breakthrough design parameter. 8. The method according to claim 7, in which the second calculated breakthrough parameter is equal to or greater than the first calculated breakthrough parameter. 9. The method according to claim 1, in which: shut-off valves are ball check valves; windows are perforations installed in the production casing in the second production zone below the first production zone; and moving the shut-off valve to open to the action of the windows comprises injecting the suspension under pressure, which causes the ball to lose its pressure-sealed seal on the saddle or cutting the pins to ensure cutting the saddle and moving it lower in the bore under the window. 10. The method according to claim 9, in which ensuring the ball loss of its working under pressure seal contains crushing the ball, dissolving the ball, or ensuring the destruction of the ball. 11. The method according to claim 1, additionally containing assessment of proppant deposition pressure in the interval of the first production zone before the installation of shutoff valves in the production casing. 12. The method according to claim 1, additionally containing drilling shutoff valves after eliminating the proppant prolapse condition. 13. The method according to claim 1, additionally containing in response to a failure of the shutoff valves, a change in the size of the shutoff valves and the descent of a new shutoff valve with changed dimensions into the well. 14. The method according to claim 1, additionally containing: the installation of shutoff valves in the production casing in the second production zone below the first production zone, the shutoff valves in the second production zone also creates a removable barrier to the flow of fluid in the barrel; and in response to the occurrence of proppant prolapse in the first production zone during injection, the suspension is pumped under sufficient pressure to move the shutoff valves along the second production zone and overcome the barrier to the passage of fluid, while opening the window to the underground formation on the length of the operational casing string at or below the mark of valves in the second production zone; and wherein the additional pumping of the suspension through open windows, while eliminating the proppant precipitation condition, comprises pumping the suspension through the bypass windows in the second production zone. 15. The method according to claim 1, in which: stop valves are the first breakthrough stopper having a first breakout design parameter; windows are perforations installed in the production casing below the production zone; and moving the shut-off valve to open to the action of the windows comprises injecting the suspension under pressure, which exceeds the calculated breakthrough parameter of the first breakable plug, while the suspension bypasses the first breakable plug and enters the underground formation through perforations; and the method further comprises installing a second breakable plug on a length segment of the production casing below the perforations, the second breakthrough plug has a second breakthrough design parameter that is equal to or greater than the first breakthrough design parameter. 16. The method according to claim 1, in which: shutoff valves are fracking plugs with saddles adapted to receive the ball; windows are perforations installed in the production casing below the production zone; the movement of valves to open the window contains: dumping the ball to the seat before the start of hydraulic fracturing; injection of the suspension under pressure, which exceeds the calculated shear strength of the pins on the fracture plug in response to the occurrence of proppant failure, which ensures the ball and seat are cut off from the fracture plug and move down the hole under perforations located below the production zone.

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