UA100078C2 - Well flow control system - Google Patents

Abstract

Flow control systems and methods for use in hydrocarbon well operations include a tubular and a flow control apparatus. The tubular defines a well annulus and includes an outer member defining a flow conduit. Fluid communication between the well annulus and the flow conduit is provided by permeable portion(s) of the outer member. The flow control apparatus is disposed within the flow conduit and comprises conduit-defining and chamber-defining structural members. The conduit-defining structural member(s) is configured to divide the flow conduit into at least two flow control conduits. The chamber-defining structural members) is configured to divide at least one of the at least two flow control conduits into at least two flow control chambers. Each of the flow control chambers has at least one inlet and one outlet, each of which is adapted to allow fluid flow therethrough and to retain particles larger than a predetermined size.

Description

TECHNICAL FIELD OF THE INVENTION

This invention relates, in general, to systems and methods of extracting hydrocarbons from underground reservoirs.

More specifically, the present invention relates to systems and methods of regulating the flow of unwanted particles from underground reservoirs through well equipment to the surface.

BACKGROUND OF THE INVENTION

This section introduces the reader to various technical aspects related to embodiments of the present invention. This description provides useful information for a better understanding of the specific techniques of this invention. Accordingly, it is to be understood that this section should be read with such an approach and not as an admission of the prior art.

Extraction of hydrocarbons from underground reservoirs usually involves a well that is completed with a cased or uncased casing. In options with a cased barrel, a casing is placed in the well and the annular space between the casing and the well is filled with cement. Through the casing and cement, perforation is performed in the production zones to create an inflow of reservoir fluids (such as hydrocarbons) from the production zones into the pipeline in the casing. In addition or alternatively, the supply of fluid can be carried out from the pipeline in the casing to the underground formation, for example, in injection operations. Although this document deals generally with extraction operations and fluid flow in the direction of extraction, the principles and technologies described in this document apply similarly to the supply of fluid in the direction of injection. A production column (or injection column) consisting of one or more pipes is placed inside the casing, forming an annular space between the casing and the production column. Formation fluids pass into the annular space and then along the extraction column to the surface through the pipe of the production column. In uncased applications, the production string is placed inside the well without casing or cement. Reservoir fluids pass into the annular space between the formation and the production column and then through the production column to the surface.

Modern oil and gas wells, in general, pass through numerous underground formations of various types and reach ever greater depths and/or lengths (for example, horizontal wells with a large deviation from the vertical). In addition, usually oil and gas wells pass through numerous reservoirs and work in them during the life cycle of the well. In some implementations, wells may pass through multiple reservoirs during any given production operation. Additionally or alternatively, a well may pass through a single manifold operating as multiple manifolds as a result of changes in reservoir properties in the manifold and/or manifold dimensions.

The ever-increasing complexity of operations in modern hydrocarbon extraction often requires an increase in the complexity of the design and completion of the well. The design of oil and gas wells usually includes geological modeling to estimate reservoir and reservoir properties.

Modeling usually includes input from geological and seismic surveys, as well as data from exploratory wells and/or adjacent wells in the field. Such modeling allows scientists and engineers to identify preferred well locations and preferred well drilling parameters. For example, flow rate, mud density, and several parameters related to the drilling operation can affect long-term well operation. Although the models and the technology underlying the models are constantly evolving, scientists and engineers are dealing with approximations of previously collected data. Drilling operations are dynamic, multi-parameter, where changes in one parameter can affect multiple parameters throughout the life cycle of the well.

Although the drilling program can significantly affect well performance during the life cycle, well completion is often considered to be the determinant of well performance after construction. In this document, the term "completion" is used for technological processes and equipment designed to ensure safe and efficient well operation. The point from which the termination process begins may depend on the type and design of the well. At the same time, during the construction of the well, many options are used and many works are performed, which have a significant impact on the productivity of the well. Accordingly, completion plans are often prepared for the drilling operation based on models and collected data. Accordingly, completion plans are often adjusted based on data collected during drilling operations to further optimize both injection and production well performance.

Regardless of the accuracy or completeness of the data available during the final adjustment of the completion plan and during the implementation of the completion in the well, the evolution of the well, the evolution of the reservoir and the evolution of the formation during the operation of the well make most of the completions inadequate for the entire life cycle of the well. Accordingly, complex overhaul technologies have been developed, which provide operators with changes to the end of the well after the start of production and/or injection operations. In addition, several attempts have been made to develop a flexible or pushable completion that can be changed during operation of the well without pulling the completion equipment from the well. Many of these methods of infused completion require the presence of mechanical equipment in the well, controlled from the surface and having two or more variable configurations. Although the concept of adapted completion is important, the harsh operating conditions in the well and the long life cycle of wells in general make it difficult to attempt to manipulate these mechanical devices with multiple configurations at the wellbore. Moreover, the need to actuate these systems from the surface creates a time delay when the results of delayed downhole conditions are detected and observed at the surface, and only then can a control signal be sent to the downhole equipment to perform a transition between configurations.

When extracting fluids from underground formations, especially weakly consolidated formations or formations weakened by an increase in stress in the well as a result of drilling the well and extracting fluids, solid material (for example, sand) may enter together with formation fluids. This influx of solid particles can reduce well productivity, damage underground equipment, and increase operating costs on the surface. Controlling solids or solids ingress is one example of a problem solved by finishing equipment and in the finishing process. Several methods of combating the entry of solid particles, specifically sand, into the well, used at this time in the industry, are shown in fig. 1(a), 1(5), 1(c) and 1(4). In fig. 1(a) production string or pipe (not shown) usually includes a sand filter or downhole sand control device 1 around the outer periphery located adjacent to each production zone. The sand filter prevents the flow of sand from production zone 2 into the production string (not shown) inside the sand filter 1. Slotted or perforated shanks can also be used as sand filters or downhole sand control devices.

In fig. 1(a) shows an example of an end with only a filter, without a gravel filter.

One of the most commonly used techniques to control sand intrusion into the well is gravel filter installation, in which sand or other granular material is deposited around the production string or downhole filter to create a gravel filter at the bottom of the well. In fig. 1(5) and 1(c) give examples of gravel filters in a cased and uncased wellbore, respectively. In fig. 1(r) shows the packing of the gravel filter From the outside of the filter 1, the well casing 5 that surrounds the packing of the gravel filter 3, and the cement 8 around the well casing 5. Normally, perforation channels 7 shoot through the well casing 5 and cement 8 into zone 2 extraction of underground layers around the well. In fig. 1(c) shows the gravel filter packing in an uncased wellbore, in which there is no casing string, and the gravel filter packing material

With settled around the well sand filter 1.

The option of a gravel filter includes the injection of a gravel suspension under a pressure exceeding the hydraulic fracturing pressure of the formation (gravel packing with hydraulic fracturing). In fig. 1(4) shows an example of gravel packing with hydraulic fracturing. The well filter 1 is surrounded by a packing of the gravel filter 3, which is contained inside the well casing 5 and cement 8. Perforation channels 6 in the well casing ensure the spread of gravel outside the well at the required interval. The number and location of the perforation channels are chosen for effective distribution of the installation of gravel filters outside the well casing in the interval being processed by the gravel suspension.

Deterioration of flow during production from underground formations can result in reduced well productivity or complete cessation of well production. This loss of functionality can occur for a number of reasons, including, but not limited to, the following: 1) migration of fine particles, mineral clays or formation sand; 2) inflow or approach to the well of the cone of undesirable fluids (such as water or gas); 3) formation of inorganic or organic insoluble sediment; 4) formation of emulsions or suspensions; 5) accumulation of drilling waste (such as drilling fluid additives and filter crust); 6) excessive entry of particles, such as sand, into the operational pipes and passage through them as a result of mechanical damage to the sand control filter and/or as a result of incomplete or ineffective filling of the gravel filter; 7) and mechanical failure as a result of wellbore collapse, reservoir compaction/settlement, or other geomechanical movements.

There are several examples of technology developed to solve these problems. Examples of such technology can be found in a number of US patents, including those briefly described below. For example, US patent 6,622,794 describes a filter equipped with a flow control device that includes multiple throttle openings and channels for directing and throttling the flow. The reduction of fluid flow through the filter by adjusting the throttle holes from the surface between the fully open and fully closed positions in the borehole is described. US Patent 6,619,397 describes a tool for zone isolation and flow control in horizontal wells. The instrument consists of non-perforated main pipes, filters with inlet devices, which are closed on the main pipe, and ordinary filters installed in an alternating manner.

The closable inlet devices ensure complete filling of the gravel filter on the non-perforated main pipe section, flow cut-off for zone isolation and selective flow control.

US Patent 5,896,928 describes a flow control device placed in a well, with or without a filter. The device has a labyrinth that creates a tortuous flow path or helical throttling. The degree of throttling in each labyrinth is regulated from the surface by installing a sliding coupling, so that the flow from each perforated zone (for example, water zone, oil zone) can be regulated. US Patent 5,642,781 describes a downhole filter jacket composed of overlapping elements in which the holes provide the passage of the fluid alternately through constriction and expansion and create a change in the direction of the flow of the fluid in the well (or multiple passages). This design can reduce particulate clogging of filter jacket openings, providing dynamic benefits for both filtration and fluid flow.

A number of other examples can be given. However, today's well designs and completion plans include little, if any, redundancy in the event of problems or failures that result in impaired flow. In many cases, the well's ability to flow at or near the design level is supported by only "one" barrier against the deterioration mechanism (eg, a single filter to control the flow of sand into the well). In many cases, the utility of a well can be reduced as a result of deterioration occurring in a single barrier. As indicated above, the deterioration of the flow can occur as a result of the action of various mechanisms, and various attempts are made to solve the problems of the operation of these mechanisms, which include attempts to create backup barriers to the action of the deterioration mechanisms. However, at this time, it is not possible to create a backup system to prevent two or more deterioration mechanisms. For example, preventing the action of such a deterioration mechanism as the ingress of solid particles and clogging by solid particles. Therefore, in general, the reliability of existing systems today is low. Accordingly, there is a need for downhole completion equipment and methods to provide multiple flow paths within the well with back-up flow paths that operate in the event of solids plugging, solids ingress, or other forms of deterioration

From the stream.

ESSENCE OF THE INVENTION

This invention is aimed at the creation of systems and methods of regulating the flow of fluid in the drilling equipment of oil and gas wells. An example of a well flow control system includes a pipe and a flow control device. The pipe is made with the possibility of placement in the well to form an annular space of the well. The pipe has an external element forming an internal channel, and at least a section of the external element is permeable, ensuring the movement of fluid between the annular space of the well and the channel. The flow control device is made with the possibility of placement in the pipe channel. The flow control device contains at least one structural element that separates the channel and at least one structural element that forms the chamber. At least one structural element that divides the channel is made with the possibility of dividing the channel into at least two flow control channels. At least one structural element forming a chamber is made with the possibility of dividing at least one of at least two flow control channels into at least two flow control chambers. Each flow control chamber has at least one inlet and at least one outlet. Each at least one inlet and at least one outlet is made with the ability to ensure the passage of fluids through it and retain particles with a size exceeding a given size.

Variants of implementation of flow control systems within the scope of this invention may include several variations of the features described above. For example, the fluid flow through the outlet opening of the flow control chamber formed in the first flow control channel can pass into the second flow control channel. Additionally or alternatively, the retention of particles with a size greater than a given outlet can gradually increase the resistance to flow passing through the outlet from the flow control chamber until the flow of fluid through the outlet is at least substantially blocked. In some implementations, at least two flow control chambers can be placed in the pipe channel so that the fluid flow entering through the permeable section of the external element passes into at least one flow control chamber. For example, at least one entrance hole in the flow control chamber is formed by a permeable section of the outer element of the pipe.

In some implementation options, at least one input hole in the flow control chamber can be made with the ability to retain particles of the first predetermined size and at least one outlet hole from the flow control chamber can be made with the ability to retain particles of the second predetermined size. In addition or alternatively, at least one inlet and at least one outlet of the flow control chamber are made with the ability to retain particles with a size at least substantially similar to the given one. For example, the flow control chamber can be made with the possibility of gradually detaining particles with a size larger than a given at least one outlet in the event that at least one inlet is damaged. In some embodiments, at least one inlet and at least one outlet of at least one flow control chamber can be hydraulically offset and connected.

In some embodiments of these flow control systems, the flow in at least one flow control chamber can be at least substantially longitudinal, and at least one structural element forming the chamber can be located at least substantially across the longitudinal direction. Additionally or alternatively, the flow in the at least one flow control chamber may be directed at least substantially circumferentially, and the at least one structural element forming the chamber may be located at least substantially transverse to the circumferential direction. Additionally or alternatively, the flow in at least one flow control chamber may be at least substantially radial, and at least one structural element forming the chamber may be located at least substantially transverse to the radial direction.

Examples of implementation variants of the flow control device may include at least one structural element that separates the channel formed by an inner pipe having permeable sections and impermeable sections. The inner tube forms a first flow control channel in the inner tube and a second flow control channel between the outer element and the inner tube. At least one structural element forming a chamber and at least two flow control chambers are placed in the second flow control channel. In addition or alternatively, at least one structural element that divides the channel can be made with the possibility of dividing the channel into at least three flow control channels. In some implementation options, the structural elements forming the chamber can form flow control chambers in at least two of at least three flow control channels. In such implementation options, at least one of at least three flow control channels can communicate with the fluid medium with the annular space of the well only through one or more flow control chambers. In implementation options having flow control chambers in two or more flow control channels, flow control chambers in adjacent flow control channels can be hydraulically displaced and communicate with the fluid medium.

Variants of implementation of these flow control systems may include at least one structural element separating the channel containing an inner pipe having permeable sections and impermeable sections. The inner tube may form a first flow control channel in the inner tube.

At least one structural element that separates the channel additionally contains turns of spiral plates that pass at least along the section of the inner pipe and are made with the possibility of forming at least one spiral flow control channel between the outer element and the inner pipe. In such implementation options, at least one structural element forming a chamber and at least two flow control chambers can be placed in at least one spiral flow control channel.

In addition or alternatively, one or more at least one of the outlet openings can be made with the possibility of selective opening to regulate the flow of the fluid through the outlet opening. In some implementations, at least one of at least two flow control chambers may include at least two exit openings designed to retain particles of a given size. In such implementation options, each of at least two outlet openings can be made with the possibility of selectively opening the flow of the fluid medium for selective retention of particles differing by a given size depending on which outlet opening is open.

The inlet to at least one flow control chamber can be made in the flow control device and the outlet from at least one flow control chamber can be formed by a permeable section of the external element. In addition or alternatively, the permeable section of the external element may form an inlet to at least one flow control chamber and an outlet from at least one flow control chamber may be made in a flow control device.

The present invention is additionally directed to the formation of a flow control device adapted for insertion into the well pipe channel. The regulating device, which is an example of flow, includes at least one structural element that separates the channel and at least one structural element that forms a chamber. At least one structural element that divides the channel can be made with the possibility of inserting a well pipe into the channel and dividing the channel into at least two flow control channels. At least one structural element forming a chamber can be made with the possibility of dividing at least one of at least two flow control channels into at least two flow control chambers. The flow control device additionally includes at least one permeable zone formed in at least one of the structural elements separating the channel and in at least one of the structural elements forming the chamber. At least one permeable zone is made with the ability to ensure the passage of the fluid and retain particles with a size larger than the specified one. The permeable section is formed such that fluids passing through at least one permeable zone pass from the first flow control channel to the second flow control channel in the channel.

The flow control device within the scope of this invention may include variations of the components described above and/or features in addition to those described above. For example, some embodiments may include intumescent materials placed on at least one structural element separating the channel and configured to be at least substantially sealed against the well pipe to hydraulically isolate the at least two flow control channels from each other such that flow passage between the channels, flow regulation occurs at least essentially only through at least one permeable zone. Additionally or alternatively, at least two permeable zones may be formed to exit at least one flow control chamber. In some implementations, at least two permeable zones can be made with the ability to retain particles of a given size. In addition or alternatively, some implementations of this flow control device may include at least one permeable zone made with the possibility of selective opening to control the size of particles that are filtered from the flow passing through the permeable zone.

Some implementations may include at least one structural element separating a channel formed by an inner pipe having permeable sections and impermeable sections. The inner tube may form a first flow control channel in the inner tube and a second flow control channel outside the inner tube. At least one structural element forming a chamber and at least two flow control chambers can be placed in the second flow control channel.

In addition or alternatively, at least one structural element that divides the channel can be made with the possibility of dividing the channel into at least three flow control channels. In some implementation options having at least three flow control channels, at least one structural element forming a chamber can form flow control chambers in at least two of at least three flow control channels. Additionally or alternatively, in implementations having flow control chambers in two or more flow control channels, the flow control chambers in adjacent flow control channels can be hydraulically offset and fluidized.

Additional or alternative implementation options include at least one structural element separating the channel, which contains an inner pipe having permeable sections and impermeable sections.

The inner pipe forms the first flow control channel in the inner pipe. At least one structural element that separates the channel may additionally contain turns of spiral plates passing at least along the section of the inner pipe and made with the possibility of forming at least one spiral flow control channel outside the inner pipe. In such implementations, at least one structural element forming a chamber and at least two flow control chambers can be placed in at least one spiral flow control channel.

This invention is additionally aimed at creating methods of regulating the flow of solid particles in the equipment of oil and gas wells. The methods include providing a pipe adapted for use on a wellbore. The pipe contains an external element that forms a channel and that has at least a section that is permeable and ensures the passage of fluid flow through the external element. The methods additionally include providing at least one flow control device containing at least one structural element that divides the channel, made with the possibility of placing a pipe in the channel and dividing the channel into at least two flow control channels, and at least one structural element that forms a chamber, made with the possibility of dividing at least one of at least two flow control channels into at least two flow control chambers. The methods additionally include placing pipes in the well, placing at least one flow control device in the well, and connecting at least one flow control device to the pipe. The stages of creation, placement and connection described above can take place in any

in any suitable order so that the assembled pipe and flow control device are placed in the well.

The connected pipe and at least one flow control device together form at least two flow control channels and at least two flow control chambers. Each of at least two flow control chambers has at least one inlet and at least one outlet, each of which is designed to allow the passage of fluids through it and retain particles larger than a given size. The methods further include supplying fluids through at least one flow control device and a pipe.

Similar to the above descriptions of flow control systems and devices, these flow control methods may include numerous variations and/or adaptations depending on the conditions of implementation of the methods.

For example, in some implementation options, the permeable section of the external element may form at least one inlet opening into at least one flow control chamber, and the step of supplying fluids through at least one flow control device and pipe may include supplying fluids obtained through the permeable section of the external element and through the outlet openings of the flow control chambers for extracting hydrocarbons from the well.

In addition or alternatively, the stage of supplying fluids through at least one flow control device and a pipe may include the following stages: supply of fluid to at least one flow control chamber located in the first flow control channel through at least one inlet opening, while the fluid the medium passes through at least one inlet in the first flow direction; redirection of the fluid in the flow control chamber for passage in the second flow direction; redirecting the fluid in the flow control chamber to flow in the third flow direction to flow through the at least one outlet and into the second flow control channel. In some embodiments, the second flow direction may be at least substantially longitudinal. In addition or alternatively, the second flow direction may pass at least substantially circumferentially, at least substantially radially and/or at least substantially spirally.

In addition or alternatively, the step of supplying fluids through at least one flow control device and a pipe may include injection of fluids into the well. In addition or alternatively, the supply of fluids through at least one flow control device and the pipe may include injection of the fluids at the end of the well. The supply of fluids through at least one flow control device and a pipe may, in addition or alternatively, contain the injection of the filling composition of the gravel filter into the well.

BRIEF DESCRIPTION DRAWING

The foregoing and other advantages of the present invention are explained in the following detailed description with reference to the accompanying drawings, in which the following is depicted.

In fig. TA-10 schematically shows the usual methods of combating the inflow of sand into the well.

In fig. 2 shows a diagram of a well in which the implementation of this invention is possible.

In fig. C shows a diagram of the sequence of operations of the methods according to the present invention.

In fig. 4 shows a view of a part of a well with cutouts in which this invention is implemented.

In fig. 5A and 58 show cut-away views of a flow control system according to the present invention in a first operating state and a second operating state, respectively.

In fig. бА-6С on the diagrams of the side view shows the working circulation in some variants of the implementation of this invention, on each figure different working states are presented.

In fig. 60-6E are side view diagrams showing the working circulation in some embodiments of the present invention, each figure representing different working states.

In fig. 7A shows a cross-sectional view of a configuration of this invention with branching in three directions.

In fig. 7B shows a cross-sectional view of the coaxial-branched configuration of this invention.

In fig. FIG. 1 shows a cross-sectional side view of the coaxial branch configuration of the present invention.

In fig. 88-80 show cross-sectional views of the implementation variant along the lines in fig. AND.

In fig. 9A shows a cross-sectional side view of a coaxial-branched configuration of the present invention that includes discharge lines.

In fig. 98-90 show cross-sectional views of the implementation variant along the lines in fig. 9A.

In fig. 10A shows a side view of a cutaway part of an eccentric configuration of the present invention.

In fig. 108 shows a cross-sectional view of the configuration of Fig. 10A.

In fig. 11A and 118 show cut-away views of a flow control system according to the present invention in a first operating state and a second operating state, respectively.

DETAILED DESCRIPTION OF THE INVENTION

In the following detailed description of the invention, specific aspects and features of this invention are described for several embodiments. However, although the following description relates to specific embodiments or uses of these inventions, it is for illustrative purposes only and represents only a description of exemplary embodiments. In addition, in the case of describing a particular aspect or feature for a particular embodiment, such aspects and features may be found and/or implemented in other embodiments of the present invention where appropriate. Accordingly, the invention is not limited to these specific implementation options described below, but, on the contrary, the invention includes all alternatives, modifications and equivalents within the scope of the appended claims.

As described above, completion systems and technological processes are implemented in oil and gas wells to control costs through well equipment and support the efficient operation of wells. As a result of the variety of well operating conditions, it is impossible to sufficiently show or outline the numerous ways of implementing this technology. At the same time, it should be understood that the technologies of this invention can be implemented in production and/or injection wells, can be implemented in vertical wells, inclined wells and/or horizontal wells, can be implemented in deep water wells, wells with a large deviation from the vertical, arctic wells and onshore wells, can be implemented in gas wells and in oil wells, and in almost any other type of wells and well operations that can be implemented for the extraction of hydrocarbons. The configurations and implementation options described in this document are only examples of the possible use of the technologies of this invention.

In fig. 2 shows an embodiment of a mining system 100 in accordance with some aspects of the present invention. In an example production system 100, a floating oil production platform 102 is connected to subsea wellhead equipment 104 located on the seabed 106. Through this subsea wellhead equipment 104, the floating oil production platform 102 has access to one or more subsurface formations, such as subsurface formation 107 , which may include multiple mining intervals or zones 108a-108n, where the number "n" is any whole number. Well-defined mining intervals 108a-108p may correspond to well-defined reservoirs and/or well-defined types of reservoirs enclosed in a conventional reservoir.

Production intervals 108a-108p correspond to zones or intervals of the reservoir containing hydrocarbons (ie, oil and/or gas) that are subject to production or other influence (such as the injection of fluids into the interval to move hydrocarbons to the nearest well, in this case, the interval can called the pumping interval). Although in fig. 2 shows a floating oil production platform 102, it should be noted that the production system 100 is shown as an example, and embodiments of these technologies can be applied to the production or injection of fluids from any subsea equipment, platform or land site.

The floating oil production platform 102 can be made with the ability to monitor and extract hydrocarbons from the intervals 108a-108p of the production of the underground formation 107. The floating oil production platform 102 can be a vessel capable of managing the production of fluid media, such as hydrocarbons, from underwater wells. These fluids can be stored on the floating oil production platform 102 and/or supplied to tankers (not shown). To access the mining interval 108a-108p, the floating oil production platform 102 is connected to the underwater equipment 104 of the wellhead and the control valve 110 by a control hose cable 112. Control tubing 112 may include operational tubing for delivering hydrocarbons from subsea wellhead equipment 104 to floating oil production platform 102, control tubing for hydraulic or electrical devices, and/or control tubing for communication with other devices in well 114.

To access the production intervals 108a-108p, the well 114 passes from the seabed 106 to the depth of interaction with the production intervals 108a-108p at different depths (or distances in the case of horizontal or inclined wells) in the well 114. It is clear that the intervals 108a-108p productions, which may be referred to as operational intervals 108, may include different layers or intervals of rock that may or may not contain hydrocarbons and which may be referred to as zones. The subsea wellhead equipment 104 installed above the well 114 on the seabed 106 forms a connection between the devices in the well 114 and the floating oil production platform 102. Accordingly, the subsea wellhead equipment 104 can be connected to the production string 128 of the pump-compressor pipe to form paths fluid flow and control cable (not shown) to create communication lines that can be connected to the control hose cable 112 on the subsea equipment 104 of the wellhead.

In the well 114, the extraction system 100 may also include various equipment for providing access to the extraction intervals 108a-108p. For example, the directional casing 124 may be installed from the seabed 106 to a specific depth from the seabed 106. The directional casing 124 may use an intermediate or production casing 126 that may extend to a depth near the production interval 108a and form the anchorage of the well walls 114 Direction casing 124 and production casing 126 may be cemented in well 114 to further stabilize well 114. Casings 124 and 126 may use pump-compressor tubing production string 128 to form a flow path in well 114 for hydrocarbons and other fluids. The underground safety valve 132 can be used to block the flow of fluids from the production string section 128 of the pump-compressor pipe in the event of a failure or rupture above the underground safety valve 132. Additionally, the packers 134, 135, 136 can be used to isolate specific zones in the annular space of the well one from one Packers 134, 135, 136 can be made in such a way that they form connection paths between the surface and devices 138a-138p to combat the inflow of sand into the well while preventing the passage of the fluid in one or more other zones, such as the annular space of the well.

In addition to the equipment described above, other equipment, such as devices 138a-138p to control the inflow of sand into the well and gravel filters 140a-140p, can be used to regulate the flow of fluids from the well. In particular, the devices 13va-138p for combating the inflow of sand into the well together with the gravel filters 140a-140p can be used to regulate the flow of fluids and/or particles into the operational column 128 of the pump-compressor pipe. Downhole sand control devices 138a-138p may include slotted shanks, stand-alone sand filters, pre-packed filters, wire-wound filters, membrane filters, sliding filters, and/or wire mesh filters, while gravel filters 140a -140p may include gravel or other suitable solid material. Downhole sand control devices 138a-138p may also include flow control mechanisms, such as a flow control device (ie, valves, conduits, nozzles, or any other suitable mechanism), which can increase the pressure loss along the fluid flow path. environment Gravel filters 140a-140p may be solid-fill gravel filters that completely cover the corresponding downhole sand control devices 138a-138p, or may be located on part of the downhole sand control devices 138a-138p. Downhole sand control devices 138a-138p may include different components or configurations for any two or more intervals 108a-108p of the well to accommodate varying conditions along the length of the well.

For example, intervals 108a-1086 may include a cased wellbore completion and a specific configuration of downhole sand control devices 138a-1386, and interval 108p may be an unlined well interval with a distinct configuration of downhole sand control device 138p.

Typically, packers or other flow control mechanisms are placed between adjacent intervals 108 to provide independent control of production in each zone. For example, the inflow of sand in the annular space of interval 10806 should be isolated in interval 10865 by packers 135. In fig. 2 schematically shows a wellbore 114 and specific intervals 108 in the wellbore that are not uniform and reservoirs and reservoirs having different configurations that are difficult to accommodate zone isolation packers.

For example, intervals 108c and 1084 are schematically shown adjacent in fig. 2 and are shown without the packer in between.

Adjacent intervals are one example of a condition where zone isolation by conventional packers is not applicable.

Additional examples include wells that intersect many different formations and/or zones, while the number of packers required makes their use economically untenable; wells intersecting formations in which formation properties change gradually but significantly so that they cannot be separated economically by conventional packers, and various other conditions where the costs and/or operational risks associated with installing a packer make the use of a packer impractical . Another example of downhole conditions where zone isolation using conventional packer technology is impractical is the dynamic conditions in each of the intervals 108 during well operation, and where the operation of one interval that was originally considered to be operated must transition to operation requiring isolation in multiple intervals or zones for independent adjustment. Changing the parameters of the interval, which requires its division into numerous intervals, is common in the operation of wells and is usually performed by methods of risky and capital repair of wells, which is expensive.

The technologies of the present invention are adapted to be placed in a well to create a flow control device associated with the well pipe to create back-up systems that counteract performance degradation. In fig. From this block diagram 200 sequence of operations of the method within the scope of this description and invention. In fig. The sequence of operations of the method begins at stage 210 with the creation of a pipe adapted for use in a well. At stage 212, the operations of the method continue with the creation of the flow control device described below. In fig. It is shown that the methods of this invention can be implemented with a different order or sequence of steps depending on the conditions in the well in which the technologies described below are used in this document. For example, in a new well or in a well from which production tubing was pulled, method 200 may include, at step 214, functionally connecting the flow control device to the pipe, followed by placement of the combined pipe and device at step 216 regulation of flow in the well. Additionally or alternatively, the methods 200 of the present invention may include, at step 218, placing the pipe in the well. The pipe can be placed in the well before the formation of the flow control device, while the flow control device is installed in the existing production pipe. Alternatively, the pipe can be placed in the well before connecting the flow control device to the pipe for other reasons. In fig. C shows at stage 220 a flow control device functionally connected to the pipe already placed in the well.

Steps 210-220 of these methods can be implemented in any suitable order or sequence to result in a flow control device functionally connected to the pipe and placed in the well. For example, a pipe can be installed years before a flow control device is built. Similarly, the pipe can be placed in the well long before the flow control device is created. The diagram of the sequence of stages in fig. C shows only two of the many ways possible to adapt to operating conditions with the presence of a flow control device connected to the pipe and placed in the well, given the methods in the volume.

After placing the flow control device in the well and connecting it to the pipe, method 200 continues at stage 222 by supplying fluids through the flow control device and the pipe. As indicated above, the flow of fluids can be in the direction of extraction (ie, fluids pass through a pipe, then through a flow control device) or in the direction of injection (ie, fluids pass through a flow control device, then through a pipe), all in in these ways.

Finally, at stage 224, hydrocarbons are obtained from the well in which the flow control device is located, or wells associated with it (when the flow control device is used in injection wells).

The description of these systems and methods mainly describes components and features in the context of mining.

For example, flow control channels and chambers are described below with inlets and outlets associated with structural elements whose inlets and outlets may be context dependent. For example, a permeable portion of a structural element may form an outlet in the context of an extraction operation and may form an inlet in the context of an injection operation. Similarly, in a mining-focused review, this document describes features and aspects designed to prevent sand or particles from entering a production pipeline that communicates with the surface.

Likewise, each and every embodiment described herein and/or within the scope of this invention may have subscripts and nomenclature appropriate to injection operations. For example, in an injection operation, the annular space of the well is a pipeline that directly communicates with the target (ie, the formation) in the same way as a production pipeline that directly communicates with the target in the production operation (ie, the surface).

Accordingly, although many of the implementation options described in this document relate to extraction, the present invention is not limited thereto. Adapting these embodiments for use in injection operations usually does not entail anything other than changing the notation used for the component designations. In some implementations, the exact placement of components may change in injection operations. However, the relative arrangement of elements or components must be preserved in the scope of the substance and in the implementation options described in this document. More specifically, the flow control systems in this description, both in operation, used in operations, and in injection operations, operations in the treatment of the near-stem zone or other operations, include a pipe and a device for regulating the flow. The pipe forms the annular space of the well outside the product and includes an external element, forming a channel in the external element. At least a section of the outer element is permeable, forming a fluid connection between the annular space of the well and the channel. The flow control device is placed in the channel and contains at least one structural element separating the channel and at least one structural element forming the chamber. At least one structural element that divides the channel is made with the possibility of dividing the channel into at least two flow control channels.

At least one structural element forming a chamber is made with the possibility of dividing at least one of at least two flow control channels into at least two flow control chambers. Each of at least two flow control chambers has at least one inlet and one outlet, each of which is made with the possibility of ensuring the passage of fluids through it and the retention of particles with a size larger than the specified one.

In fig. 4 shows section 240 of well 242 in formation 244. Section 240 of well is shown as a vertical section of well 242, but is shown here only as an example, as the technology can be used in vertical, horizontal or otherwise oriented wells. As shown in fig. 4, wellbore 242 includes flow control systems 246 located functionally associated with reservoir production zones 244. More specifically, in FIG. 4 shows that these technologies can be implemented in various configurations and/or combinations of technologies to form a flow control system 246 according to various implementation options described and proposed in this document. For example, in fig. 4, the flow control systems 246 are shown to include pipes 248, which may be constructed as a pipe 248a of the first configuration and/or as a pipe 24865 of the second configuration, each of which has a permeable and an impermeable section created in various ways, as further described below and shown in FIG. corresponding figures. The 248 pipes, while different, share some common elements. For example, each pipe 248 includes an external element 250 that forms a channel 252 in the pipe. In addition, each of the external elements 250 includes a permeable section 254, made with the possibility of ensuring the passage of the fluid through the external element into the channel.

In fig. 4 further shows that pipes 248 include a flow control device 256, which may have any of the configurations described herein. Two examples of the flow control device 256 are shown in Fig. 4. The design details of the flow control device and its operation are described in more detail below in this document and are shown in the corresponding figures. Along with the introduction in fig. 4 shows that the fluid flow, shown by arrows 258, from the formation 244 in the pipe 248 follows a tortuous path through at least two flow control mechanisms, here presented as permeable areas associated with the external element 248 and the flow control device 256. In some embodiments of the present invention, it may be preferable to use a common configuration for each of the flow control systems 246 along the length of the well pipe link, along the length of the zone isolated by the packers, and/or along the length of the entire functional section of the well string. In other implementation options, as shown in fig. 4, well, formation and/or reservoir characteristics may dictate the use of different configurations of flow control systems in the same well. For example, as shown schematically in fig. 2, it is possible that two mining intervals, such as zones 108c and 1084, are close enough to each other that zone isolation by conventional packers is impractical. Different zones may include formations with different characteristics that require different terminations for optimal exploitation. The configuration as shown in fig. 4, where flow control systems of different configurations are placed adjacent to each other, can provide different terminations of distinct intervals, and control the flow from them, without requiring the placement of packers between intervals. Similarly, the use of multiple configurations of flow control systems may be suitable in various other common field conditions.

In fig. 5A and 5B show a flow control system 246 in the coaxial configuration 260 also shown in FIG. 4. The coaxial configuration 260 is one example of various implementation options for the flow control system 246 within the scope of this invention. In fig. BA shows the coaxial configuration 260 in the fully open state, and in fig. 5B shows a coaxial configuration with flow control chamber 262 blocked by sand 264 or other particles (referred to below, generally as sand) from reservoir 244. As seen in FIG. 5A, the flow control system 246 in the coaxial configuration 260 includes a pipe 248 that includes an external member 250 that defines a channel 252. The pipes 248 may include solely the external member 250 or may include the external member 250 along with various other devices , such as devices common in well production strings. In embodiments where the tube 248 includes an additional device, it should be understood that the term "external" in the outer element 250 refers to the channel 252 formed by the outer element 250 and not to the tube 248. The tube 248 and the outer element 250 are shown in FIG. BA, as cylindrical elements, common for industry; however, other shapes and configurations can also be used, such as ellipsoidal or polygonal. The shape of the pipe 248 may affect the shape of the channel 252 and/or the configuration of the flow control device 256 placed in the channel 252. Additionally or alternatively, the configuration of the external element 250 may have a greater influence on the configuration of the channel 252 or the flow control device. For example, the outer element 250 may be adapted to form permeable areas 254 and impermeable areas 266 at various locations along the length and/or periphery, which may affect the flow profile and therefore the configuration of the flow control device 256. Accordingly, although in fig. 5A and 58 show an example of a coaxial configuration 260, other coaxial configurations are within the scope of this invention. Similarly, other configurations or implementations described and shown herein are merely examples, and changes in the shapes and sizes of various parts are within the scope of this invention.

The flow control systems 246 of the present invention include the outer tube 250 described above,

and a flow control device 256 placed in the channel 252. The flow control device 256 includes at least one structural element separating the channel 268 and at least one structural element forming a chamber 270. The at least one structural element separating the channel 268 may have any configuration made with the possibility of dividing the channel 252 into at least two flow control channels 272. As shown in fig. 5A, the channel dividing structural member 268 includes a tube 274 disposed in the outer member 250 of the tube 248. In FIG. BA tube 274 and outer element 250 are concentric, leading to the nomenclature of the coaxial configuration; however, it should be understood that the tube 274 may be positioned in any position within the channel 252, including the off-axis tube 248 and/or adjacent the outer member 250. At least one structural member separating the channel 268 , used to separate channel 252 into at least two flow control channels 272 , may comprise a single physical element or may comprise multiple elements such as pipes, walls, reflectors, etc.

The flow control device 256 also includes at least one chamber-forming structural element 270 shown in FIG. 5A. In fig. 5BA structural element forming the chamber 270 is provided with a disk 276 covering the annular space between the pipe 274 and the outer element 250.

Accordingly, the channel 252 formed by the external element 250 is divided into at least two flow control channels 272 and at least two flow control chambers 262. Similarly to the structural member 268, separating the channel, the structural member 270 forming the chamber can be formed in any suitable configuration that can be influenced by the configuration of the external member 250 and/or the configuration of the structural members 268, separating the channel. Similarly, the number of structural elements forming the camera, 270 and the distance between them can be changed in the implementation options within the scope of this invention. In the coaxial configuration 260 in fig. 5A, the structural members 270 forming the chamber may be installed in the conduit 252 at regular intervals and/or may be installed in the conduit based at least in part on measured or predicted formation properties 244 in the region outside the pipe 248 .

Fig. 5A and 58 illustrate the operation of the flow control system 246 described herein. The operation of the system is first described in a general way and then more specifically with reference to the specific elements shown in fig. 5A and 5B. As described above, the flow control system 246 of FIG. 5A and 5B are identical, but in two distinct operating states. In the flow control systems 246 of this invention, at least two flow control channels 272 are created from one flow control channel 252. In addition, at least one of the flow control channels 272 is separated by at least one flow control chamber 262.

At least one flow control chamber 262 includes at least one inlet port 278 and at least one selective outlet port 280. At least one inlet port 278 provides passage of fluid outside the pipe 248, i.e., from the annular space of the well 282 between the formation 244 and the pipe 248 through the outer element 250 in the channel 252 or, more specifically, in the chamber 262 flow control. The inlet 278 is made with the possibility of forming at least one barrier to the deterioration of the flow, such as filtering sand 264 from the flow. Accordingly, the permeable areas 254 may form an inlet 278, which also forms a barrier to flow deterioration (ie, elimination of sand inflow into the well). Inlet 278 may form a flow impairment barrier of any suitable configuration using conventional downhole sand control mechanisms, such as wire wound filters, perforated tubing, pre-packed filters, slotted shanks, mesh screens , metal-ceramic filters, etc.

After the fluid enters the flow control chamber 262, the fluid passes to the outlet 280, shown in Fig. 5A, offset from the inlet 278. The outlet 280 is also designed as a barrier to the deterioration of the flow with the possibility of forming a backup to counteract various well conditions that may impair the flow of the fluid. For example, as shown in fig. 5A, the outlet 280 from the flow control chamber 262 can be made as a permeable section, made with the ability to retain sand 264 or other particles with a size greater than a given one. The outlet configuration may vary depending on the flow deterioration mechanism being counteracted.

Additionally or alternatively, multiple outlets can be formed from the flow control chamber 262 as described below and shown in other figures herein. The coaxial configuration 260 can be made with the possibility of inclusion in the composition of the two exit holes by the formation of perforations, mesh or other forms of permeability in the structural element 270 that forms the chamber. In some embodiments of the present invention, the configuration of the outlet ports and inlet ports can be coordinated to provide redundancy against the same flow degradation mechanism(s). In addition or alternatively, the inlet and/or outlet can be made with the possibility of solving the problems associated with such additional and/or different mechanisms.

In fig. 58 system data redundancy shown 246 flow regulation. The inlet 278 of the flow control chamber 262 is mechanically damaged, causing sand 264 to flow into the flow control chamber 262 as shown through the opening 284 in the permeation area 254. Although the passage of sand through the sand control devices into the wellbore of conventional operating tubing is a significant deterioration of the flow, in fig. 5B shows that the backup control means of the present invention forms an outlet 280 from the chamber 262 with suitable flow control equipment to prevent the flow of particles larger than a given flow control chamber from exiting. Accordingly, sand 264 accumulates in the chamber until it effectively blocks the outlet 280 with sand and blocks, at least substantially, the passage of flow through the chamber. In the embodiment of fig. 5A and 5B, the flow from the outlet passes into another flow control channel, which is not divided into chambers, and the fluids move to the surface. In other implementation options, the flow passing through the outlet 280 from one flow control chamber 262 may pass into another flow control chamber 262 with one or more outlet openings designed to form a barrier against the flow deterioration mechanism. For example, to counter the risks of sand ingress with mining fluid media and/or the risks of unwanted sand blocking of flow paths. As fluid flow passes from one flow control chamber to another flow control chamber, the chambers can be placed in series to create step regulation and/or to address multiple flow degradation mechanisms. For example, the first flow control chamber can be made with the possibility of combating the inflow of larger sand particles, and the second flow control chamber can be made with the possibility of combating the inflow of smaller sand particles, etc.

Preferably, the flow control systems 246 of the present invention provide continued extraction from an interval or zone in which one form of flow impairment has occurred. In fig. 5B shows continued extraction through the flow control chamber 262 even after failure of the outer filter (inlet 278) of the blocked flow control chamber 262, allowing sand to enter channel 252. Also, although the flow through the lower flow control chamber is blocked or at least substantially limited, the inflow from the formation 244 may continue through the annular space 282 of the well with the entrance to the pipe 248 through the inlet 278 connected to the upper, unblocked flow control chamber. The flow path through the annular space 282 of the well forms another form of redundancy created by these flow control systems. Specifically, in the event that the lower flow control chamber is blocked by an accumulation of insoluble sediment at its inlet or other blockage at the outer member and the inlet, the formation flow may continue through the annulus 282 of the well to enter the adjacent flow control chambers.

Flow control systems 246 of the present invention, such as those shown in FIG. 5A and 5B, can be done by displacing the flow control chamber outlet 280 from the flow control chamber inlet 278, in the manner shown in Fig. 5A and 5B. One of the mechanisms of flow deterioration, which the end of the equipment seeks to prevent or solve the problems associated with it, is the arrival of sand 264 when ensuring the passage of fluids into the channel. In conventional methods, filters or other permeable materials are used to prevent the passage of particles while ensuring the passage of fluids. However, permeability inevitably reduces the structural integrity of permeable areas. When the carrier solid particles of the fluid media are exposed to the permeable areas, it is common for these areas to fail and the appearance of through holes in the permeable area, such as hole 284 in Fig. 5B. Such holes nullify the ability of permeable areas to fight against the inflow of sand into the well and form the passage of sand into the operational equipment.

The risk of mechanical failure of permeable areas increases in cased and/or hydraulic fracturing wells, where production fluids enter the annular space 282 of the well from discrete, focused sources.

The offset between the inlet 278 of the flow control chamber and the outlet 280 of the flow control chamber in one or more embodiments of the invention may form an additional barrier against flow deterioration as a result of mechanical failure of the termination equipment. As shown in fig. 5, in an example embodiment, the flow entering the flow control chamber 262 passes through the inlet 278 in the first direction, passes through the flow control chamber in the second direction, and exits through the outlet 280 after passing in the third direction. The flow control device 256 includes impermeable sections 266 designed to form a reinforced structural element around the inlet 278 in the flow control chamber 262. Accordingly, although the inlet 278 may cause the concentration of fluids in a particular flow direction, the flow control device 256 is designed to redirect this energy in a second flow direction, dissipating the energy carried by the particles involved in the flow and forcing the particles to fall out of the flow. This initial rotation may be sufficient to reduce the risk of mechanical damage caused by the impact on the permeable areas of the particles involved in the flow. However, in some implementation options, such as those shown in fig. 5A and 58, other changes in flow direction are applied prior to passage through the outlet 280. The tortuous path taken by particles seeking to pass through the production fluid conduit 248 reduces the energy of the particles and facilitates the performance of the permeable section forming the outlet 280 from the flow control chamber. A tortuous path can be formed in a variety of ways, some of which are shown and described herein, and all of which are within the scope of this invention.

In fig. bA-6E additional variants of implementation and characteristics of flow regulation systems in the scope of this invention are shown and described below. In fig. bA-B6E very schematically present combinations of permeable surfaces and impermeable surfaces that can be used to implement flow control channels and flow control chambers within the scope of this invention. Although the permeable areas represented by dashed lines are visually analogous to conventional wire-wound filters that can be used in the present invention, the permeable areas shown here more broadly and schematically represent any of the various ways in which fluids can be provided to pass through an external element in flow control chamber. For the clarity of the description of the various schemes of fig. bA-6E used reference numbers different from the reference numbers of similar or identical elements or features of fig. 4 and 5. Similarly, other figures in this document may use distinctive reference numbers for clarity of description of these figures. The terms and nomenclature used to refer to common elements and features are consistent with the figures and may refer to consideration of similar features of the various implementation options described in this document.

In fig. 6A-6C schematically show three different operating configurations of the flow control system 300.

The flow control system 300 in FIG. bBA-6C includes an external element 302, which forms an annular space 304 of the well between the reservoir 306 and the external element 302. However, for purposes of consideration and simplification, only half of the longitudinal section is shown. As discussed above, the outer member 302 also forms a channel 308 within the outer member 302. In addition, the flow control system 300 further includes a flow control device 310 that includes channel dividing structural elements 312 configured to divide the channel 308 at least two flow control channels 314, and structural elements forming the chamber, 316, are made with the possibility of dividing at least one flow control channel 314 into at least two flow control chambers 318. As one example of an implementation variant that may represent the circuit in FIG. bA-6C, coaxial configuration in fig. BA and 5B should have the appearance of a longitudinal section, comparable to the appearance of fig. BA-60.

In fig. 6A-6C shows a flow control system 300 with outlets 320 from flow control chambers 318 that can be selectively opened. As can be seen in fig. bA, in comparison with fig. bA-6C outlet openings 320 are both closed in fig. bА, preventing the flow of the fluid through the chambers 318 of the flow control. Accordingly, in fig. bA shows the first operational configuration of flow control systems within the scope of this invention, in which the flow control system effectively acts as a section of non-perforated pipe. As shown by the flow direction arrow 322, the fluid in the annular space 304 of the well effectively remains in the annular space of the well when passing through the flow control system 300. Similarly, as shown by the flow direction arrow 324, the fluid in the flow control channel 314a (which may have entered the flow control channel from the area of the well, closer to the bottom of the face) remains in the flow control channel 314a.

In fig. 68 shows flow patterns when one of the outlet ports 320 is open. As shown in fig. 6C, the structural elements forming the chamber 316 are more than just the disk shown in FIG. 5, |and include both permeable areas and impermeable areas, which together are designed to form a selectively opening outlet 320, shown above. Outlet 320 can be selectively opened using various techniques, including chemical means (dissolution or other modification of areas of the impervious area, including impact-responsive materials), mechanical means (sliding couplings or other elements that move hydraulically, electrically or by the action of other signals and controls) or other means (such as perforating holes or other known downhole tools). It should be understood that a physical embodiment of the selective opening of outlet 320 can be schematically shown here or in any other suitable manner, such as a wire-wound filter with a space filled with soluble or shrinkable material to provide passage between the wound wire.

After opening the outlet 320, the fluid from the annular space 304 of the well passes into the flow control chamber 318a through the outlet 320 and into the flow control channel 314a for additional movement in the well to the surface. In fig. 6B shows that the selective opening of the outlet 320 provides the operator with control over which flow control chambers 318 are operational at any given time, which can be used to control operating flow rates or control the termination type application (eg, preventing the passage of finer or larger particles). . In some implementations, the selective opening of the exit holes 320 allows the operator to set prey from specific mining areas. For example, as shown in fig. 6B, fluids are received through the flow control chamber 318a and the corresponding outlet when the flow through the flow control chamber 3186 is blocked by the closed outlet. Therefore, and as shown in fig. 6C, the passage of the flow through the flow control chamber 318a is blocked by the accumulation of sand 326 by the outlet 320a, designed to retain particles larger than the specified size. When the spoil through the flow control chamber 318a is substantially blocked by the accumulated sand 326, the flow control chamber 3186 and outlet 3200 can be opened to allow continued extraction from the extraction zone, continuing to protect the extraction operation from flow impairments such as sand drift in this example. . With a gradual change in extraction in the extraction zone, the amount of inflow from such an area can be maintained for a longer period of time without major repairs. In some implementations, outlet holes 320r can be made with the possibility of applying different degrees of control of the flow of sand into the well compared to outlet hole 320a. For example, features to control the flow of sand into the outlet hole 3205 may allow passage of larger particles to prevent accumulation of sand 326 at the outlet, blocking flow through the outlet 3200, which may allow continued production with a controlled amount of sand or fines. In addition or alternatively, the spacing between the inlets 328 of the respective flow control chambers may be large enough to effectively limit or prevent the passage of sand from the zone of one formation (eg, the area adjacent to the flow control chamber C318a) to the inlet of the adjacent flow control chamber through annular space 304 well. Accordingly, the configuration of the outlet openings 320a and 32065 in the adjacent flow control chambers may differ for the retention of sand, which is predicted to flow from different zones of the formation. The configuration of outlets that retain particles larger than a given size can be performed on a chamber-to-chamber or wellbore basis. In any case, the formation, well, termination, mode of operation of the well, constructive implementation of the flow control system and various other factors can affect the given size that delays this outlet hole.

In fig. 6C further shows that one or more chambers can be formed with an unsecured opening 332 without features of sand control, such as the exit opening 332 shown in the flow control chamber 318a. Such an outlet can be formed in various conditions where economics or conditions in the well no longer require or foresee the need for these backup flow control systems. For example, data backup control devices for flow control systems can be implemented over a period of time to maximize the life cycle after the end of the well interval and productivity while minimizing sand inflow. However, there may be a time in the life cycle of a well when some amount of sand input is acceptable as opposed to a workover.

For example, if the entire flow control system in the completion equipment is blocked and the next step is to pull the production tubing for overhaul, it may be preferable to open the unsecured outlet 332 in one or more flow control chambers to continue production for the time of arrival projected sand or fine material.

Although in fig. b6A-6C show the flow profiles in the flow control system 300 with the staggered use of different flow control chambers 318, the flow profile through the inlet 328, through the flow control chamber 318, and through the outlet 320 is such that it represents the flow profiles of the embodiments described in this invention . Similarly, the schematic representation of the locations and orientation of the flow control chambers, flow control channels, external element, structural elements separating the channel from the structural elements forming the chamber, inlets, outlets, etc., are all presented by way of example only and may be implemented or implemented in any suitable configuration, including those described in more detail herein. As described above, any one or more of these components may have different meanings in the context of injection and in the context of extraction, as described above. For example, outlet 320 can be considered an inlet to the flow control chamber and inlet 328 can be considered an outlet from the flow control chamber.

In fig. 60-6E show additional diagrams of flow control systems 300 within the scope of this invention.

The flow control system 300 in FIG. 60-6E includes many features similar to those described above, made in an excellent variant of implementation. The flow control system 300 includes an external element 302, made with the possibility of forming an inlet opening 328 passing through it, and forming a channel 308 in it. The flow control system 300 is placed in the well so that the outer element 302 forms an annular space 304 of the well between the layer 306 and the outer element. Similarly to the implementation variant described above, the flow control system 300 of Fig. 60-6E includes a flow control device 310 that can be accommodated in an external element 302. The flow control device 310 includes at least one structural element separating the channel 312, which forms at least two flow control channels 314 in the channel 308. In addition, the flow control device 310 includes at least one structural element forming a chamber, 316 made with the possibility of dividing at least one flow control channel 314 into at least two flow control chambers 318. In addition, the flow control device 310 is made with the possibility of forming at least one outlet 320 from the flow control chamber 318.

As shown in fig. 60-6E, the flow control system 300 within the scope of this invention may include two or more outlets 320 to the flow control chamber 318. Following the progress of work in fig. 6O-fig. 6E, it can be seen that the first outlet 320 is open in FIG. 60 to ensure the passage of flow through the flow control chamber 318. The outlet 320 is formed with a permeable area 330 or other features to counteract at least one flow degradation mechanism. For example, the outlet 320 can be provided with a filter or mesh that traps particles larger than a given size. Additionally or alternatively, the outlet 320 may be designed to resist mechanical rupture of the filter or mesh with hydraulic displacement from the inlet 328, as discussed above. As shown in fig. 60, one outlet 320 is open and the other is closed. In some implementations, two or more exit holes can be opened at the same time, depending on the flow parameters required for a specific well, zone and/or chambers of operational equipment.

As shown in fig. 6E, the second outlet 320 is open if the first outlet 320 is effectively and/or substantially closed by an accumulation 326 of sand or other particles. Selective opening of outlet ports 320 provides the operator with flow control through individual flow control chambers. In some implementations, the selective opening of the exit holes is controlled from the surface by any suitable means. Surface control of outlet opening is acceptable because delays in opening the outlet do not introduce increased risks of flow degradation or damage to operational equipment. Additionally or alternatively, control of the various selectively opening exit ports 320 may be accomplished passively or without direct operator intervention or surface action.

For example, the second open outlet 320 in FIG. 6E may be configured to open when the pressure in the flow control chamber 318 exceeds a predetermined rate selected to indicate that the first outlet is sufficiently blocked by particles. Additionally or alternatively, providing a second outlet in the chamber may be sufficient to effectively close it until the first outlet is sufficiently blocked. For example, in fig. 6E flow in the annular space 304 of the well is shown as moving from right to left. The flow should tend to enter the inlet 328 and continue to move from right to left to the first opening 320, which is shown open in FIG. 60 and closed in fig. 6E.

Natural forces should not direct significant flows to the second outlet 320 until there is a significant back pressure on the first outlet.

As described above, in some implementation options, stepwise or selective opening of outlet holes can be implemented in order to maintain production rates for an extended period of time from one section of the formation. In addition or alternatively, staggered or selective opening of the outlets can be implemented to counter different flow degradation mechanisms and/or different levels of flow degradation risks. As one example of such an implementation option, the first outlet hole can be designed to retain particles of a first predetermined size, and the second outlet hole can be designed to retain particles of a second larger predetermined size. Accordingly, the well, or zone of the well, can be operated during a first period of time in which all particles larger than the first smaller predetermined size are retained and accumulated against the outlet. When the second outlet is opened, the flow can resume or continue from the given chamber and must ensure the passage of particles smaller than the second predetermined size through the outlet. Such an implementation option may be suitable when qualitatively different inflows and/or risks are allowed at different stages of the life cycle of the well. In fig. bE shows another additional configuration of the flow control system 300, in which both outlet openings 320, including the permeable sections 330, are blocked. Under such conditions, the flow through chamber 318 must be blocked. However, in some implementations, it may be acceptable to open an unsecured outlet 332 that is not designed to trap particles or otherwise prevent or counteract the flow deterioration mechanism. The flow can then be renewed through the flow control chamber 318. Such an implementation option can be used when the risk of sand inflow must be minimized or when the risks of sand inflow are acceptable when accounting for other conditions associated with the continuation of well operation, such as the cost of major repairs, etc.

In fig. 7A-7C schematically show additional options for implementing flow control systems within the scope of this invention. It is described above and shown in fig. 5A and 58 coaxial configuration of flow control systems, and in fig. bA-6E show flow charts distinguishing various configurations and implementations to be described in this document. In fig. 7A shows an end view of a three-way flow control system 350. Like other implementations described and disclosed in this document, the three-way flow control system 350 includes an external element 302 that forms an internal channel 308. As shown in Fig. 7A, the channel 308 is branched into three directions by the flow control device 310, which includes structural elements 312 that divide the channel in the form of three partitions 352. The partitions 352 divide the channel 308 into three flow control channels 314, any one or more of which can be further divided by structural elements forming a chamber (not shown). The three-way configuration 350 in FIG. 7A presents various ways in which the structural elements that divide the channel can be placed to divide the channel 308 into two or more flow control channels 314 . Partitions 352 can have a configuration of solid panels and/or can be made with the possibility of forming exit holes (not shown in Fig. 7A), such as described herein, to ensure the passage of flow between adjacent flow control channels 314 and/or chambers. Additionally, more detailed examples of three-way and/or multi-branch flow control systems 350 are provided below.

In fig. 7B shows a diagram of the end view of another version of the implementation of the branched flow control system. In fig. 7B schematically shows the flow control system 300 in a coaxial-branched configuration 360. The coaxial-branched configuration 360 is another example of different ways of possible implementation of the flow control device 310 in the external element 302 of the flow control system 300.

As shown, the coaxial branch configuration 360 includes a plurality of structural elements 312 that divide the channel, which include an inner tube 362 and three baffles 364 passing between the outer element 302 and the inner tube 362 that partition or divide the annular space between them on numerous flow control channels 314. In addition, the inner pipe 362 forms another flow control channel 314. Any one or more of these flow control channels 314 can be divided into flow control chambers (not shown) using structural elements forming the chamber (not shown) that can be made conformal or substantially conformal in the dimensions of the channel 314 flow regulation. In example implementations, each of the external flow control channels 314a can be formed into flow control chambers, and the internal flow control channel 31406 can be left open for unobstructed flow of fluids through the pump-compressor pipe column. Similarly to the scheme of fig. 7A, the structural elements 312 separating the channel in FIG. 7B, including the inner tube 362 and the baffles 364, can be made as continuous panels and/or can be made to form exit openings (not shown in FIG. 7B), such as the exit openings described herein, that provide flow passage between adjacent flow control channels and/or cameras.

In fig. vBA-80 shows another example of a variant of the implementation of the coaxial-branched configuration 360.

In this embodiment, the flow control device 310 may include multiple structural elements 312 separating the channel, placed and designed in any suitable manner to form at least two flow control channels 314 from the channel 308 formed by the external element 302. As shown in Fig.

ZA, the coaxial-branched configuration 360 effectively forms a plurality of concentric flow control channels 314a, 31460, 314c using multiple internal tubes 362. The external element includes at least one inlet 328 into the flow control channel 308, and a specific flow control channel 314a.

As also shown in fig. 8A, after the fluid enters the channel 308, it has the opportunity to pass into the flow control chamber 318a formed by the structural elements 312 that divide the channel, the structural elements 316 that form the chamber, and the external element 302. The fluid in the external flow control channel 314a or the external flow control chamber 318a may then exit the flow control chamber through outlet openings 320 formed in the channel dividing member 312, which may be of any suitable shape for the outlet openings forming fluid communication between the external flow control channel 314a and an intermediate channel 314r for flow control. The configuration of the outlet 320 may vary depending on the flow degradation mechanism for which the flow control system 300 is adapted. The exit holes, which are an example, can form a permeable area, such as the one described above, made with the possibility of retaining particles of material with a size greater than a given one.

As shown in the configuration of the outer element 302, the inlet 328, which forms a connection between the annular space 304 of the well and the channel 308, can be made with the possibility of counteracting the deterioration of the flow, as described in this document. For example, inlet 328 may be a wire wound filter, mesh, or configuration adapted to control the inflow of sand into the wellbore.

Examples of configurations of the external element 302 may include an inlet 328 formed by a wire-wound filter having gaps between adjacent wires sufficient to retain reservoir sand entering the wellbore larger than a predetermined size. Other portions of the outer element 302 may be formed in any suitable manner, such as non-perforated pipe, impermeable material wound externally on permeable material, or a wire-wound filter with no gaps between adjacent wires. Wire-wound filter fabrication is well known in the art and involves winding the wire at a predetermined pitch to provide some gap between adjacent wires. In some embodiments, suitable external elements can be manufactured with a step change that is used to manufacture conventional wire-wound filters. For example, one section of the outer element can be prepared by winding a wire-wound filter with a required pitch that should retain formation sand of a size larger than a given size and winding the next section at zero or near zero pitch (no gap) to form an essentially impermeable section material. Other sections of the outer member 302 can be wound at varying pitches to form sections of varying permeability or impermeable sections.

The inner pipe 362 can be formed in a manner similar to that described for the outer element 302, using wire-wound filter techniques. Using various known wire configurations and different pitches, it is possible to form the outlet openings 320 in the permeable areas in numerous configurations suitable for trapping particles of any given size. In addition or alternatively, the permeable areas on the flow control device 310 compared to the permeable inlet on the outer element 302 can be formed by other suitable methods that provide the necessary functionality, such as the selective opening of the outlet openings 320 described above and shown in FIG. 6. In embodiments where the outlet 320 from the flow control chamber 318 is hydraulically offset from the inlet 328 to the flow control chamber, more flexibility in the configuration of the outlet can be provided. As discussed above, the hydraulically offset inlet 328 and outlet ports 320 form an impermeable and therefore stronger structural element separating the channel 312 in the area in the path of the fluid from the annular space 304 of the well through the inlet 328 to resist mechanical damage to the structural element 312 , forming a chamber, by the force of fluid media and/or incoming particles.

In the configuration shown in fig. 8A-80, the channel 308 is divided into two annular flow control channels 314 by an inner pipe 362, which are further divided into longitudinal flow control channels by baffles 364 passing through the annular channels (see Fig. 88-80). Flow, flow control inlet 314 through inlet 328, meets an impermeable member of the channel divider 312, as indicated by flow direction arrows 366 in FIG. 8A. The flow is then deflected dissipating the energy carried by the fluids and particles in the flow longitudinally in the longitudinal flow control channels 314 formed and formed by the flow control device and the structural element 312 dividing the channel, as seen by the flow direction arrows 368. The flow is then isolated by the longitudinal structural elements 316 forming the chamber. Outlets 320, which can be outlets of selective opening, form a fluid connection between the external longitudinal flow control channel 314a and the intermediate longitudinal flow control channel 3145. As discussed above, and similarly to the inlet 328, the outlet openings 320 can be formed with a permeable area or in another suitable configuration to trap particles with a size greater than a given one. The flow in the intermediate flow control channel 3146 can then pass through the outlet 320 into the internal flow control channel 314c, as shown by flow direction arrows 370, or can pass longitudinally through the flow control intermediate channel 314p, as shown by flow direction arrows 372. For example, in the event that one of the outlets 320 from the intermediate flow control channel 3146 becomes blocked by an accumulation of particles, the fluids may pass longitudinally to the other outlet 320 to support extraction from the corresponding section of the production pipe. Additionally or alternatively, the outlets from the intermediate flow control channel 3146 may be hydraulically offset (not shown) from the outlets from the outer flow control channel 314c. After the passage of fluids through the outlet 320 from the intermediate flow control channel 3146 to the internal flow control channel 314c, the fluids are hydraulically connected to the surface and are part of the extraction flow shown by arrows 374 in the direction of flow.

In some implementations, the external flow control channel 314a and the corresponding outlet can be made with the possibility of creating an outlet filter to retain larger particles, which allows smaller particles to pass through it, and the intermediate flow control channel 31465 and the corresponding outlet can be made with the possibility of forming final filter to remove smaller particles. Additionally or alternatively, the external and intermediate flow control channels and corresponding outlets may be essentially similar and form redundancy with a similar level of filtration, rather than with different degrees of filtration. In any case, if the inlet 328 fails and allows particles to enter the channel 308, the external flow control channel 314a and the corresponding outlet form the first barrier in the way of infiltration of sand into the stream 374 extraction. In addition, in the event that the outlet 320 from the external channel 314a of the flow control is made with the possibility of ensuring the passage of some particles through it or in the case of mechanical failure of the outlet, the intermediate channel 3146 of the flow control and the corresponding outlet form a second barrier on the path of sand infiltration into the mining stream. In conjunction with the energy dissipation of the hydraulically offset inlets and outlets, the flow control system 300 of the present invention provides improved ability to prevent flow degradation resulting from the formation of multiple backup flow paths in the outer member 302 and channel 308. In the event that each of the outlets from this flow control chamber 318 is blocked or essentially blocked as a result of particle accumulation (or as a result of a possible configuration of selective opening), produced fluids from the adjacent formation can enter the annular space 304 of the well and move to the adjacent section of the production string of pumping and compression pipes , which is not yet blocked. Accordingly, back-up flow paths and back-up systems ensure the continuation of mining operations by preventing sand infiltration and counteracting other forms of flow impairment.

In fig. 88, 8C and 80 show cross-sections of fig. ZA along the lines indicated in fig. FOR, while the same elements are indicated by the same positions. These figures show the transition from permeable walls (dashed lines) to impermeable walls (solid lines) based on location in the wellbore. In addition to what is not shown in fig. ZBA-80, any one of the structural elements 312 forming the chamber, such as the baffles 364, can be formed with permeable sections, forming outlets from one longitudinal flow control channel to an adjacent flow control channel. The fluid connection between the longitudinal flow control channels shown in fig. 8A-8O0, can form an additional reservation of the flow paths for passing the flow of the fluid medium with countering the mechanisms of flow deterioration. The configuration and placement of the outlet openings in the baffles 364 may utilize the principles of hydraulic displacement described above, such as being positioned longitudinally offset from the inlet opening 328. Additionally or alternatively, the outlet openings in the baffles may be positioned longitudinally aligned with the inlet opening 328, with thereby retaining the benefits of hydraulic displacement generation described above. As described above, hydraulic displacement between the inlets and outlets can be implemented to dissipate energy in the inlet flows that act against the solid surface with greater stability of the structural element separating the channel rather than the outlet. The displacement causes a change in the directions of the incoming flow after entering the flow control channel (for example, from the radial direction of the flow through the inlet to the longitudinal direction of the flow in Fig. BA). Longitudinally shifted outlet holes shown in fig. ZA, cause a different change in flow direction when the flow passes through the outlet (for example, from a longitudinal direction of flow in the pipeline to a radial direction of flow through the outlet). In implementation options with one or more exit holes in the partitions 364, similar changes in the flow direction are formed. For example, radial flow through the inlet is changed to circumferential flow as a result of the connection between the solid inner tube and the outlet in the baffle.

In fig. 9A-90 shows an example of a flow control system 300 further adapted for use in operations requiring flow in the reverse direction or the direction of injection, such as operations in the treatment of the stem zone and/or operations in the installation of gravel filters.

Configurations in fig. 9A-90 are analogous in many respects to the coaxial branch configuration 360 of FIG. 8A-80, and like items relate to like elements without specific reference to Figs. 9A-90. As shown in fig. 9A-90, one or more of the flow control channels 314 can be implemented as a discharge pipe 376. The example configuration shown includes a bypass pipe 378 located in the discharge pipe 376 and nozzles 380 extending from the bypass pipe through the outer element 302. When the bypass pipe 378 is used, the discharge pipe 376 may have enough space left over to ensure that the flow control channel is also used for extraction purposes. Alternatively, the flow control channel in which the shunt pipe is placed can be adapted for exclusive use as a conduit for the shunt pipe. Additionally or alternatively, one or more of the flow control channels 314 may be adapted for injection operations without the use of bypass pipes 378. For example, the use of solid, impermeable structural members separating the channel and appropriate inlets and outlets may enable the use of a single flow control channel for injection operations, while the adjacent flow control channel is adapted for extraction operations. Incorporation of shunt pipes 378 and/or discharge lines 376 can provide the use of these flow control systems in gravel filter filling operations as described in US Patent Nos. 4,945,991, 5,082,052, and 5,113,935.

In fig. 10A and 108 show a cut-away side view and a cross-sectional view, respectively, of another embodiment of flow control systems 400 within the scope of this invention. Although eccentric configuration 402 is shown and described separately from the embodiments and configurations described above, features and aspects of this embodiment are interchangeable with other embodiments and configurations described herein. For example, the outlet and inlet configurations described above for the coaxial, branched, and/or coaxial-branched implementation may be used in the eccentric configuration 402 without specifically repeating such features or configurations for the eccentric configuration. Similar to the implementation options described above, the eccentric configuration 402 provides flow path redundancy and backup countermeasures against flow degradation to improve the durability and functionality of the downhole equipment. The eccentric configuration 402 in FIG. 10A and 108 is shown in the context of counteracting the mechanism of flow deterioration with sand infiltration, but is also effective in counteracting insoluble deposit build-up at the inlets of operational equipment. In addition, since an increase in sand input is often associated with a corresponding increase in irrigation, these flow control systems can effectively work against the mechanism of deterioration of irrigation flow.

As shown in fig. 10A and 108, the eccentric configuration 402 includes a pipe 404 with an external element 406 forming a channel 408. A flow control device 410 is placed in the channel 408 with structural elements 412 that divide the channel, made with the possibility of dividing the channel 408 into at least two channels 414 flow regulation, and which has structural elements forming a chamber, 416, made with the possibility of dividing at least one of the flow regulation channels 414 into at least two flow regulation chambers 418. The outer element 406 is also provided with an inlet 420, represented by perforation holes 422. Perforation holes 422 or other means of inlet holes, which forms a fluid connection between the annular space 424 of the well and the flow control channel 414, can be made with the ability to retain particles with a larger size given or can be otherwise performed with the possibility of counteracting the flow deterioration mechanism.

The flow control device 410 also includes an outlet 426 designed to form a fluid connection between the flow control external channel 414a and the flow control internal channel 414p. The outlet 426 is represented or shown as perforations 428, and may be formed in any suitable manner to counteract one or more flow degradation mechanisms as described herein. As shown in fig. 10A and 108, the outer element 406 and components of the flow control devices 410 can be formed from conventional pipes provided with perforation holes that create the appropriate inlets and outlets. Although the perforations themselves may be designed to retain particles larger than a predetermined size (or provide some other countermeasure against flow impairment), the outer element 406 and/or flow control device 410 may include sand filters 434 that may extend the length of the element. , as shown, or only on top of the perforated length segments.

In fig. 108 shows that the eccentric configuration 402 is made of two types of channel dividing structural members 412, which include an inner tube 430 placed eccentrically in the outer member 406 and which divides the channel 408 into an inner flow control channel 4145 and an outer flow control channel, additionally divided by a partition 432 into the first external flow control channel 414a and the second external flow control channel 414c. The amount of eccentricity and the relative sizes of the various flow control channels, shown only as an example, can be changed depending on the implementation option.

In fig. 10A and 108 show ways in which backup flow paths can extend the life cycle of the completion equipment despite reservoir phenomena that impair operation, such as sand ingress. In the embodiment of fig. 10A shows the flow control chamber 418a with a failed filter at the inlet 420 that created sand entry 436 into the flow control inlet chamber 418.

As sand accumulates in the flow control chamber 418a, the flow resistance increases and less fluid passes through the outlet 426 from the flow control chamber 418a. Accordingly, less fluid enters the flow control chamber 418a, as shown by dashed flow lines 438. The structural element forming the chamber 416 and the outlet 426 are blocked or substantially blocked by the infiltrated sand, which creates an effective isolation of the level to ensure continued production of fluids adjacent to the isolated level through the annular space 424 of the well and the chamber 4186 adjustment costs, following a bypass shown by bypass flow line 440.

In fig. 10A shows two predominant scenarios possible when operating a well with a flow control system of this invention. As described above, the infiltrating flow control chamber 418a is filled with sand 436. Although the accumulated sand may completely block the outlet 426, it is also possible for the outlet 426 to function as a conventional sand-filled gravel filter and for the infiltrated sand 436 to function as natural sand filling of the filter in an isolated chamber 418a flow regulation. The possibility of natural filling of the filter with infiltrated sand may depend on the nature of the reservoir in which the flow control system 400 is placed. In addition, the configuration of the flow control chamber 418a and the outlet 426 may facilitate or hinder the formation of a natural fill with infiltrated sand. In some implementations, end-of-line engineers and equipment manufacturers can adapt the flow control device 410 to facilitate the formation of a natural filter fill with infiltrated sand in the flow control chambers. Natural filling with infiltrated sand in the flow control chamber 418a can provide continued extraction of hydrocarbons through the flow control chamber, preventing the entry of sand into the internal flow control channel 41406, and additional protection of the outlet hole 420 from mechanical damage.

In addition or alternatively, the backup flow bypass 440 created in the flow control system 400 dissipates the energy of the sand involved in the flow entering the annular space of the well adjacent to the infiltration flow control chamber 418a. As shown in fig. 10A, the sand fluid enters the borehole annulus 424 and is forced through the outer member 406 to travel longitudinally through the annulus to meet another inlet 420. As described above, changes in direction caused by hydraulic displacements dissipate energy that can be stored concentrated sand. In fig. 10A shows that the hydraulic displacement can be set in the annular space of the well as well as in the flow control channels in the data channels of the flow control systems.

In fig. 1088 shows another method of creating backup flow paths and backup protection against flow degradation in the eccentric configuration 402. As shown in FIG. 108, the infiltrated sand 436 may enter only one of the external flow control channels, such as the first external flow control channel 414a. Under such conditions, the extracted fluids can pass circumferentially around the outer element 406 to enter the second outer flow control channel 414c, in which there is no infiltration as shown in FIG. 108. Similar to the conditions shown in fig. 10A, the infiltration flow control chamber 418a may form a natural sand fill gravel filter in some embodiments, which allows the extraction fluids to continue to flow through the infiltration flow control chamber 418a at reduced velocities. Additionally or alternatively, the conditions of FIG. 108 show that flow bypasses 440 may be circumferentially similar or alternatively to the longitudinal flow shown in FIG. 10A.

As described above for other configurations of the present invention, various structural elements of the flow control device 410 can be implemented with the ability to create permeable areas suitable for backup flow paths and backup particle retention systems described herein. For example, the partition 432 and/or structural elements that form the chamber, 416 can be formed with perforations, mesh, wire winding, or other means that creates fluid communication between the flow control channels and/or flow control chambers.

In fig. 11A and 118 show an enlarged view of another flow control system from FIG. 4. Similarly to the consideration of fig. 5A and 5B, the operation of this flow control system configuration is described in detail below. In fig. 11A and 118 show a partial cutaway view of the flow control system 500 in a stepped configuration 502. As in the previous drawings, the flow control system 500 is located in a wellbore 504 in a formation 506, with the formation of an annular space 508 of the well between the flow control system and the formation. Although the flow control system 500, as well as other implementations described herein, is shown by way of example in an uncased wellbore, the systems and methods of this invention are also applicable in cased wellbores.

The stepped configuration 502 of the flow control system 500 includes a pipe 510 that includes an outer element 512. The pipe 510 includes a perforated main pipe and a wire wound filter. In this embodiment, the perforated main pipe forms an outer member 512 that forms a channel 514 and that forms an inlet 516 to the channel that provides fluid communication between the channel and the annular space of the well 508. Perforations 518 are one example of inlets to the channel 514 .Similarly, a perforated main pipe is just one example of various ways of creating an outer member with an inlet opening and forming a channel. Other suitable means are known to those skilled in the art and are included within the scope of this invention. It should be noted that the pipe connected to the flow control channel 526c is not provided with perforation holes or other means that form an inlet to the channel. Accordingly, the only way for fluid to enter the flow control channel 526c (described further below) is through the flow control chamber. Flow control channels that have only fluid communication with the formation or annular space of the well through the flow control chamber can be considered operational flow control channels that can communicate with the surface.

As also shown in fig. 11A and 118, the stepped configuration 502 of the flow control system 500 includes a flow control device 520 located in the channel 514. Similar to the embodiments described herein, the flow control device 520 includes structural elements 522 that separate the channel and structural elements elements forming a chamber, 524. Structural elements 522 THAT divide the channel, are made with the possibility of dividing the channel 514 into at least two flow control channels 526. In the shown embodiment of the stepped configuration, the structural elements 522 separating the channel are formed by a plurality of partitions 528 designed to divide the channel into three branches. Additionally or alternatively, additional channel partitioning structures may be formed to further partition the channel 514. The baffles 528 of the channel partitioning structures 522 include both permeable sections 530 and impermeable sections 532. The permeable sections 530 are made of the ability to provide communication between adjacent channels 526 with the flow control with the retention of particles with a size larger than the specified one. Accordingly, the permeable sections 530 are one way of forming the outlet 534 from the chambers 536 of flow regulation by the structural elements forming the chamber.

Impermeable sections 532 are designed to prevent the flow of fluid through them. As shown in fig. 11A, the impermeable sections 532 are positioned operably associated with the perforations 518. The impermeable sections of the flow control device may be designed to allow or be adapted for direct fluid communication with the inlet 516 to absorb and/or deflect the energy of the incoming fluids and particles. Additionally or alternatively, the impermeable sections 532 can be placed to create a hydraulic displacement of the outlet openings 534 from the flow control chamber 536 away from the inlet openings 516. Although in the illustrated embodiment, the impermeable sections 532 are formed only on one partition that forms the flow control channel 526r, in the other implementation options can form alternative configurations that include impermeable sections on both partitions and/or with different interconnections.

In the stepped configuration 502 of FIG. 11A and 118, three flow control channels 526a-526c are created with two flow control channels divided into a plurality of flow control chambers 536. As shown, the flow control chambers 536 in each flow control channel are stacked longitudinally in the channel, and the flow control chambers in adjacent flow control channels 526 are offset relative to each other. In addition, as shown in fig. 11A and 118, the partition 528a includes permeable sections that ensure the passage of fluid flow between flow control chambers in adjacent flow control channels. Accordingly, in this embodiment, the partition creates at least one outlet from the flow control chamber 536. In addition, as shown in fig. 11A and 118, partitions 5286 and 528c include permeable sections 530 designed to allow flow from the flow control chamber 536 into the flow control channel 526c, which is not divided into flow control chambers.

The stepped configuration 502 operates in a manner similar to the configurations described herein.

For example, the flow control device 520 divides the channel into a plurality of flow control channels and flow control cameras. The flow control channels and flow control chambers form back-up flow paths through the pipe and form back-up measures against flow impairment, specifically, flow impairment as a result of sand and/or particle accumulation or insoluble deposit formation.

Flow direction arrows 538 in fig. 11A show multiple redundancy options built into the staggered configuration 502. Depending on the configuration of the impermeable sections and the permeable sections of the structural elements separating the channel, the incoming radial fluid flow can be redirected longitudinally and/or circumferentially before exiting the flow control chamber. The presence of multiple outlets and flow paths from each chamber may also provide a more dense filling of each flow control chamber with infiltrated sand.

The combination of fig. 711A and 118 shows what happens in a step configuration flow control system when the channel inlet is damaged and begins to allow sand to enter the channel. As shown in fig. 118, the inlet 516 of the flow control chamber 536ba is damaged by erosion or other mechanical wear, and the hole 540 in the wire wound filter is open for sand 542 to enter the flow control chamber 536ba. Sand 542 may begin to accumulate against any of the permeable sections 530 forming the outlet 534. As a result of the increased number of outlets and the ability to pass flow through one outlet as sand accumulates against the other outlet, extraction through chamber 536b and flow control can continue with greater productivity and for a longer time. In addition, as described herein, the staggered configuration and creation of multiple outlets and flow paths can facilitate the formation of an internal gravel filter of natural fill with infiltrated sand, which can provide continued production of fluids through the flow control chamber 53ba while reducing the risk of sand infiltration into the channel 526c regulation of extraction costs. In addition, the stepped configuration 502 can maintain flow rates longer and longer extraction periods between overhauls as a result of the proximity of adjacent flow control chambers.

As can be seen in fig. 118, when flow control chamber 536ba is blocked or filled with sand, reservoir fluids that would otherwise enter chamber 53ba can be diverted, with appropriate energy dissipation, to the inlet of an adjacent flow control chamber by circumferential movement around the outer element or longitudinally along the outer element.

The above description provides numerous illustrations of flow control systems within the scope of the present invention.

Each of the systems represents a nomenclature of systems that can be developed in volume, according to the essence and formula of this invention. In addition, you need to understand that each of the features of different implementation options can be interchangeable in different implementation options. For example, the selectively opening outlets described for FIG. 6A-6E, can be included in any other implementation options. The inlets and outlets of the flow control chambers of various implementations can be selectively opened in various ways, including selective perforation, rupture discs, pressure-responsive valves, sliding bushings, flow control devices with radio frequency identification, etc. In addition, or alternatively, as described for several embodiments, the inlets and/or outlets may be designed to provide fluid communication to prevent sand infiltration by a variety of suitable means, including wire-wound filters, perforations, meshes, filters with variable wire pitch winding, etc., and can be formed in any combination of filtration measures, including filtration of particles of different sizes, filtration of particles of the same size, or both.

In addition, as described for fig. 3, flow control systems within the scope of this invention can be assembled or constructed in a variety of ways, including construction or assembly prior to lowering the well and assembling after the components are lowered into the well. For example, the flow control system can be made as an autonomous termination equipment, ready to be connected to other links of the operating or injection pump-compressor pipe. In addition or alternatively, flow control systems may include a flow control device designed to be lowered through the operational pump-compressor pipe already placed in the well. Lowering the flow control device into the pipe already in the well can be performed using various well-known equipment and rig systems. Depending on the condition of the well pipe and the configuration of the flow control device, the clearance between the flow control device and the internal diameter of the pipe may vary. In some embodiments, the intumescent material can be placed in a suitable manner on the flow control device to close the gaps required when the flow control device is lowered into place. The swellable material can be activated or swelled by any suitable method used in other industrial uses. In addition or alternatively, the gap between the flow control device and the inner diameter of the pipe may be small enough to not require sealing with an intumescent material between the pipe and the flow control device. In some implementation options, the flow control device may not be designed to create a high-quality seal between the device and the pipe. For example, the configuration of the flow control device, flow control channels, and flow control chambers may allow a pressure loss between the device and the pipe that is small enough for a negligibly small fluid flow.

The flow control systems of the present invention provide improved protection or countermeasures against various flow degradation mechanisms to provide longer-lasting operation.

Backup flow paths are designed to allow continued operation even when the well section is damaged, such as by excessive sand inflow, insoluble sediment formation, or blocked inlets. Similarly, back-up sand filters that prevent sand infiltration ensure longer operation of the well section when formation sand is inflow. When both backup flow paths and backup sand filters are included in the composition, numerous mechanisms of flow deterioration are counteracted by a single system, which in any version of implementation can be placed in the well and provide an autonomous response without operator intervention.

In some implementation options, the flow control channels are made with the possibility of the direction of the incoming fluids in the longitudinal direction before meeting with a structural element forming a chamber that changes the direction of movement of the fluid to pass through the outlet.

For example, the coaxial configuration in fig. 5A and 5B creates a longitudinal flow in the outer flow control channel before redirecting the flow radially to pass into the inner flow control channel. In other implementation options, flow control channels are made with the possibility of a radial flow direction followed by one or more changes in direction, either longitudinally or circumferentially before entering the extraction flow. In addition, in some implementations, the flow entering through the inlet opening can be directed circumferentially and/or spirally (circumferentially and longitudinally) through one or more flow control channels before meeting a structural element that forms a chamber that changes the flow direction, causing passage of the fluid through the outlet holes and into the extraction speed control channel. For example, the multiple exit holes of the stepped configuration described in this document ensure the passage of fluid both longitudinally in the flow control chamber and circumferentially between the flow control chambers before passing through the exit hole into the extraction rate control channel. Other implementation options may include structural elements separating the channel and/or structural elements forming the chamber in any suitable configuration. As one of various examples, the structural elements separating the channel can be placed spirally around the inner tube. The spirally wound structural members separating the channel can direct the flow spirally around the inner tube to meet the structural member forming a chamber, preventing the spiral flow and directing the flow through the outlet opening into the operational flow control channel created by the inner tube. In some implementation options, the structural elements forming the chamber can be placed across the flow direction of the fluid, established or caused by flow control channels.

Each of the implementation options of this invention can be made suitable for a specific well or well section. For example, the number of flow control channels and flow control chambers can be changed as well as the length, width, depth, direction, etc. of pipelines and chambers. Although the permutations of the channel-separating structural elements and of the chamber-forming structural elements can be endless, engineers and operators can identify a few that are most suitable for use based on one or more of the following characteristics: ease of manufacture, ease of operation, effectiveness in preventing entry of sand into the well, efficiency in maintaining extraction rates, the possibility of changing the configuration according to the customer's specifications, etc. Each such change is within the scope of this invention.

EXAMPLE

The flow control systems of this invention were demonstrated in a laboratory model of wellbore flows. The laboratory wellbore model for the flow control system was a 25 cm (10 in) outside diameter, 7.6 m (25 ft) long acrylic plastic pipe to simulate an uncased wellbore or casing string. The device for testing the end equipment was installed inside a pipe made of acrylic plastic and included a group of three pump-compressor pipe sections. Three sections of the pump-compressor pipe consisting of a flow control system having a mechanically damaged inlet zone of the outer element, a flow control system having a mechanically undamaged inlet zone of the outer element, and a conventional filter represented by a mechanically damaged sand filter. Each section of pump-compressor pipe was 15 cm (6 in) in diameter and 1.8 m (6 ft) long. The flow control systems included a 91 cm (3 ft) slotted shank and a 91 cm (3 ft) unperforated pipe as a pipe or external element. The flow control device placed in the ducts consisted of an inner tube (structural element that divides the duct) with an OD of 7.5 cm (3 in.) consisting of a 1.2 m (4 ft) length of unperforated pipe and a filter with 61 cm (2 ft.) long coil of wire. The outer element and inner tube in the flow control systems being modeled were concentric, corresponding to the coaxial configuration example described above. During the test, water containing gravel sand was pumped into the annular space between the tubing assembly (the termination system) and the acrylic pipe (the unlined casing or casing).

The suspension (water and sand) initially passed through the annular space and into the damaged flow control system. Sand entering the damaged flow control system was retained and filled the flow control chamber formed between the inner pipe and the outer element. The growing sand filter increased flow resistance and slowed the movement of sand entering the damaged flow control system. As the sand inflow into the damaged flow control system decreased, the suspension (water and sand) was diverted further downstream into the adjacent undamaged flow control system. Gravel sand filled the annular space between the intact flow control system and the acrylic plastic pipe. Since this flow control system was intact, the sand was trapped by the inlet in the outer element. With the plugging of the externally undamaged flow control system, the suspension was diverted to the next damaged conventional filter. The sand passed around and then into the damaged conventional filter. Because the conventional filter was not equipped with an auxiliary or back-up means of controlling sand infiltration, sand continuously entered the eroded filter and the process could not be controlled.

The experiment illustrated the concepts of flow control systems in the gravel filter filling part of well completion operations. If a portion of the sand filter material is damaged during filter installation or eroded during gravel filter filling operations, the flow control system described herein is capable of retaining gravel as an auxiliary or back-up means to counteract sand infiltration or other flow impairment while allowing normal flow to continue. gravel filter filling operations. However, a conventional filter could not control the loss of gravel and should potentially result in an incompletely filled gravel filter. An incompletely filled gravel filter with a conventional filter later determines the inflow of formation sand during the operation of the well. Excessive inflow of sand reduces the productivity of the well, damages the well equipment and poses a threat to the safe conduct of work on the surface.

This experiment also illustrated the concepts underlying the flow control systems of this invention during the operation of wells completed with gravel filters or self-contained anti-sand completion equipment. If a portion of the filter material designed to prevent sand infiltration is damaged or eroded during well operation, the flow control system described herein may trap gravel or natural sand (ie, formation sand) in the flow control chambers of the flow control systems, maintaining integrity ring gravel filter or natural sand filter, divert flow to other undamaged filters and continue mining free of sand. In contrast, damage to a conventional filter should cause a continuous loss of sand to fill a gravel filter or a natural fill sand filter, followed by a continuous supply of formation sand.

Variants of this invention may have different modifications and alternative forms in comparison with the implementation options discussed above. It should be understood that the invention is not limited to the specific embodiments described herein. In fact, the true methods of the invention should cover all modifications, equivalents and alternatives corresponding to the essence and scope of the invention defined by the appended claims.

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Claims (17)

1. Well flow control system, which includes a pipe, which is designed to be placed in the well to form an annular space of the well and which has an external element that forms an internal channel and which has at least a permeable section to ensure the movement of fluid between the annular space of the well and the internal a channel, and a flow control device made with the possibility of placing a pipe in the channel and which contains at least one structural element that divides the channel, which divides the inner channel in the essentially longitudinal direction into at least two, first and second flow control channels, and at least one structural element a chamber-forming element that divides at least two flow control channels in a substantially transverse direction into at least two flow control chambers, each flow control chamber having at least one inlet opening 1 at least one outlet opening, each of which is intended for the passage of flowing sulfur flow through it and retain particles with a size greater than a given size, while at least one of the two flow control channels is connected to the annular space of the well only through at least one flow control chamber, while each outlet of the flow control chamber is able to be selectively opened for flow control fluid through it. 2. The system according to item I, which differs in that the flow control chambers in adjacent flow control channels are connected. 3. The system according to claim 1, which is characterized by the fact that the outlet opening of the flow control chamber formed in the first flow control channel is adapted to pass the fluid flow to the second flow control channel. 4. The system according to claim 1, which is characterized by the fact that at least two flow control chambers are placed in the inner channel of the pipe so that the flow of the fluid that enters through the permeable section of the external element passes into at least one flow control chamber. 5. The system according to claim 3, which is characterized by the fact that at least one inlet hole in the flow control chamber is formed by a permeable section of the outer element of the pipe. b. The system according to claim 1, which is characterized by the fact that at least one inlet hole in the flow control chamber is able to retain particles of the first predetermined size, 1 at least one outlet hole from the flow control chamber is capable of retaining particles of the second predetermined size. 7. The system according to claim 1, characterized in that at least one inlet and at least one outlet of the flow control chamber are capable of retaining particles with sizes at least substantially similar to a given size, while the flow control chamber is capable of gradually retaining particles of size, exceeding the given size, by at least one outlet hole when at least one inlet hole is damaged. 8. The system according to claim 1, which is characterized by the fact that at least one inlet and at least one outlet of at least one flow control chamber are connected. 9. The system according to claim 1, which is characterized by the fact that the flow in at least one flow control chamber passes in at least essentially a longitudinal direction, while at least one structural element forming the chamber is placed at least essentially across the longitudinal direction. 10. The system according to item I, which is characterized by the fact that the flow in at least one flow control chamber is at least substantially circumferential, while at least one structural element forming the chamber is located at least substantially transverse to the circumferential direction. 11. The system according to claim 1, characterized in that at least one of the at least two flow control chambers includes at least two outlet openings, each of which is capable of retaining particles of different predetermined sizes and selectively opening to the flow of a fluid medium to selectively retain particles of different predetermined sizes sizes depending on which outlet is open. 12. The system according to claim 1, which is characterized by the fact that the inlet of at least one flow control chamber is made in the flow control device and the outlet of at least one flow control chamber is formed by a permeable section of the external element. 13. The system according to claim 1, which is characterized by the fact that the permeable part of the external element forms an inlet to at least one flow control chamber, while the output hole of at least one flow control chamber is made in a flow control device. 14. The system according to claim 1, which is characterized by the fact that the flow control device is adapted to be lowered into a pipe placed in a well. 15. The system according to claim 1, which is characterized in that at least one structural element forming the channel is adapted to form at least one impermeable deflecting surface of at least one flow control chamber, placed directly in the path of the fluid medium of the inlet opening into the flow control chamber for deflecting the incoming fluid medium. 16. The system of claim 15, wherein each flow control chamber includes at least two exit openings. 17. The system according to claim 16, which is characterized by the fact that each of the at least two outlets provides communication with different flow control channels.