Self-adaptive same-well injection-production and water control well completion system and method

Abstract

The invention provides a self-adaptive same-well injection-production and water control well completion system and method.The well completion system comprises oil pipes, a sleeve and an expansion packer, the oil pipes are connected through oil pipe short sections, the well completion system further comprises injection control assemblies and inflow control assemblies, and each well section is at least provided with one injection control assembly and one inflow control assembly; mounting ports are formed in the tubing nipple, and the injection control assembly and the inflow control assembly are mounted in the different mounting ports respectively. A plurality of self-adaptive inflow and injection control assemblies are mounted on each tubing nipple, and water production of a high-permeability section is limited through the inflow control assemblies, so that the yield of a low-permeability section is stabilized, and an inflow profile is balanced; and oil displacement agents or CO2 and other yield increasing fluids are injected into the stratum through the injection control assembly. The method is suitable for both a new well and an old well, edge-bottom water coning of the horizontal well is effectively delayed, same-well throughput production is achieved, the purpose of full-well life cycle yield increase / autonomous profile control production is achieved, and the cumulative yield and the recovery rate are improved to the maximum extent.

Description

TECHNICAL FIELD

[0001] The present application belongs to the technical field of oilfield development, and particularly relates to a self-adaptive injection-production and water control completion system and method for the same well. BACKGROUND

[0002] In the development of horizontal wells, due to the non-uniformity of permeability, the change of water saturation with time, the unstable pressure profile, and the pipe friction, especially when encountering fractured reservoirs, the production profile usually shows strong non-uniformity, and the fluid inflow velocity of some production sections is obviously higher than that of other production sections, which easily causes individual production sections to see water / gas too early, resulting in the increase of water cut and the decrease of oil production of the whole well, and seriously affecting the recovery rate. If the formation is sanding, the fluid velocity will increase due to the throttling effect when passing through the perforation gun or screen pipe, causing erosion and sand particles entering the wellbore to affect normal production. For old wells that have been producing for many years, in addition to water control and balanced production profile, it is also necessary to balance the injection of oil displacement agents or CO2 for huff and puff in each section to improve the recovery rate.

[0003] Research and application at home and abroad show that the use of downhole water control devices can play a certain role in water control, and the use of segmented water control for horizontal wells can balance the production profile, which is an effective means to inhibit the water breakthrough of the wellbore. Downhole water control technology has been developed for many years, and there are many different types of water control devices. Patent CN106246143B discloses a water control method for water-producing oil layers and a water control sand control pipe column, which uses water-swelling rubber to block the water-producing layer, but the water-producing layer needs to be found in advance, and the device does not have the function of self-adaptive water control. Patent CN113803050A discloses a self-adaptive inflow control device, an intelligent completion string and a completion method, and the key water control principle of the self-adaptive inflow control device is to recognize and control the flow of liquid through flow path and channel design, but the adaptability is poorer than that of the floating disc type of the present application when dealing with low-viscosity fluid and gas-liquid mixed flow. SUMMARY

[0004] The present application aims to provide a self-adaptive injection-production and water control completion system to overcome the above technical problems in the prior art.

[0005] Another object of the present application is to provide a self-adaptive injection-production and water control completion method to maximize the cumulative production and recovery rate.

[0006] To this end, the technical solution provided by the present application is as follows:

[0007] An adaptive well injection and production and water control completion system, comprising a tubing, a casing and a plurality of inflatable packers, the tubing is connected by tubing spool, further comprising injection control components and inflow control components, each well section is provided with at least one injection control component and one inflow control component, the tubing spool is provided with installation ports, the injection control components and inflow control components are installed in different installation ports, and the axial directions of the injection control components and inflow control components are perpendicular to the axial direction of the tubing spool.

[0008] The inflow control component comprises a body one and a float plate, the body one is a cavity structure, the body one comprises an upper circular truncated cone one and a lower circular cylinder one, the upper circular truncated cone one is large at the top and small at the bottom, and the larger diameter of the upper circular truncated cone one is larger than the diameter of the lower circular cylinder one;

[0009] The float plate is arranged in the cavity, the upper circular truncated cone one is provided with an inflow port at the top, the lower circular cylinder one is provided with threads, the lower circular cylinder one is provided with support blocks at intervals, the support blocks and the lower circular cylinder one form a flow channel, and the lower circular cylinder one is provided with a flow hole.

[0010] The injection control component comprises a body two and a circular baffle, the body two is a circular cavity, and the circular baffle is arranged in the circular cavity;

[0011] The body two comprises an upper circular truncated cone two and a lower circular cylinder two, the upper circular truncated cone two is large at the bottom and small at the top, the smaller diameter of the upper circular truncated cone two is equal to the diameter of the lower circular cylinder two, the lower circular cylinder two is provided with an injection port, the circular baffle and the upper circular truncated cone two are provided with a compression spring, and the diameter of the circular baffle is larger than the diameter of the injection port.

[0012] The tubing spool is detachably connected with a sand prevention metal screen.

[0013] The outer side of the compression spring is provided with a protective rubber.

[0014] The grade of the compression spring is determined according to the injection opening pressure.

[0015] An adaptive well injection and production and water control completion method, which adopts the adaptive well injection and production and water control completion system, during production, fluid flows through the inflow port of the inflow control component, then enters the tubing, and is extracted through the oil pump;

[0016] During the process, because the viscosity of the oil phase is greater than that of the water phase and the gas phase, the flow rate of the oil phase through the float plate is greater than that of the water phase and the gas phase, thereby achieving the purposes of self-control of water and air;

[0017] When the production time is a period of time, the recovery amount decreases, and it is necessary to inject a production increasing fluid, the fluid is injected into the tubing through the water injection pump, the fluid enters the tubing-casing annulus through the injection port of the injection control component, and then is injected into the formation.

[0018] Before production, the following steps are also included:

[0019] Step 1) Collect data: wellbore structure, reservoir and fluid properties, logging interpretation results, perforation and fracturing data, daily production reports;

[0020] Step 2) Determine parameters: Based on the collected data, determine the total length, dimensions, material, and thread type of the completion string;

[0021] Step 3) Determine the isolation section: Quantitative analysis is carried out using numerical simulation methods, and multi-factor comprehensive analysis is conducted in combination with drilling data and logging interpretation results to divide several sections or one section with similar production and pressure into the same isolation section.

[0022] The well logging interpretation results include permeability profiles, water saturation profiles, and fracture interpretation results.

[0023] Step 4) Determine the type and quantity of injection control components for each well section based on production output;

[0024] Step 5) Determine the type and quantity of inflow control components for each well section based on the water injection volume requirements;

[0025] Step 6) Assembly of tubing string: Connect the tubing through tubing stubs, assemble the expandable packer according to the well section, and assemble the corresponding number and type of injection control components and inflow control components on the tubing stubs of each well section to form an adaptive injection and production integrated tubing string.

[0026] Step 7) Running the tubing for production: After running the adaptive injection-production integrated tubing to the predetermined position, set the water-swellable packer and the suspended packer, and start production.

[0027] The type of inflow control component in step 4) is determined by the flow rate at 2 MPa, including flow rates less than 1.1 m³. 3 / d, with a flow rate of 1.1–9.7 m³ / d. 3 / d, with a flow rate of 9.7–26.8 m³ / d. 3 / d has three types.

[0028] The type of injection control component in step 5) is determined by the flow rate at 2 MPa, including flow rates less than 68.7 m³. 3 / d and the overflow rate are 68.7~154.5m 3 / d has two types.

[0029] The beneficial effects of this invention are:

[0030] The adaptive same-well injection and water control completion system provided by this invention utilizes a water-expanding packer for segmented well completion. Several adaptive inflow and injection control components are installed on each water control short section (oil tubing short section). The inflow control components limit water production in high-permeability sections, stabilize production in low-permeability sections, and balance the inflow profile. The injection control components inject oil displacement agents or production-enhancing fluids such as CO2 into the formation.

[0031] This invention is applicable to both new and old wells. It is a one-time well completion operation that simplifies the tubing structure and operation procedures. It enables uniform single-tube modification and injection-production, as well as long-term autonomous inflow control and autonomous injection control downhole. It effectively delays the conical entry of water at the bottom and side of horizontal wells, balances the inflow profile, and achieves same-well throughput production. It aims to increase production / autonomous profile adjustment throughout the entire well life cycle, maximizing cumulative production and recovery rate. Attached Figure Description

[0032] Figure 1 This is a schematic diagram of one embodiment of the tubing string for the adaptive same-well injection and production and water control completion system of the present invention;

[0033] Figure 2 This is a cross-sectional view of one embodiment of the inflow control component of the present invention;

[0034] Figure 3 This is a cross-sectional view of one embodiment of the injection control component of the present invention;

[0035] Figure 4 This is a schematic diagram of the installation structure of the tubing sub and the inflow / injection control components;

[0036] Figure 5 This is a schematic diagram of a sand-proof metal mesh.

[0037] Figure 6 This is a flowchart of the adaptive same-well injection and production and water control completion method of the present invention;

[0038] Figure 7 The experimental flow-pressure drop curve of the adaptive inflow control component (2 MPa pressure difference, ZGaf2.5);

[0039] Figure 8 The injection control component's experimental flow-pressure drop curve (4 MPa pressure difference, ZGin 6.0);

[0040] Figure 9 The figure shows the production dynamic curve of the adaptive same-well injection and production and water control completion system installed in the production well in the example.

[0041] In the diagram: 1. Oil pump; 2. Screen pipe; 3. Plug; 4. Suspended packer; 5. Oil pipe; 6. Injection control assembly; 7. Inflow control assembly; 8. Expansion packer; 9. Oil pipe sub; 10. Upper truncated cone I; 11. Lower cylinder I; 12. Float; 13. Inlet; 14. Flow channel; 15. Flow hole; 16. Upper truncated cone II; 17. Lower cylinder II; 18. Circular baffle; 19. Compression spring; 20. Protective rubber; 21. Sandproof metal mesh; 22. Injection port. Detailed Implementation

[0042] The following specific embodiments illustrate the implementation of the present invention. Those skilled in the art can easily understand other advantages and effects of the present invention from the content disclosed in this specification.

[0043] Exemplary embodiments of the present invention will now be described with reference to the accompanying drawings. However, the present invention may be embodied in many different forms and is not limited to the embodiments described herein. These embodiments are provided to fully and completely disclose the invention and to fully convey its scope to those skilled in the art. The terminology used in the exemplary embodiments illustrated in the drawings is not intended to limit the invention. In the drawings, the same units / elements are referred to by the same reference numerals.

[0044] Unless otherwise stated, the terms used herein (including technical terms) have their common meaning as understood by one of ordinary skill in the art. Furthermore, it is understood that terms defined in commonly used dictionaries should be understood to have a meaning consistent with the context of their relevant field, and not to be interpreted as having an idealized or overly formal meaning.

[0045] Example 1

[0046] This invention provides an adaptive same-well injection and production and water control completion system, including tubing 5, casing and multiple expansion packers 8. The tubing 5 is connected by tubing stubs 9. It also includes an injection control component 6 and an inflow control component 7. Each well section is equipped with at least one injection control component 6 and one inflow control component 7. The tubing stubs 9 have installation ports. The injection control component 6 and the inflow control component 7 are installed in different installation ports, and their axial directions are perpendicular to the axial direction of the tubing stubs 9.

[0047] like Figure 1 As shown, the sucker tubing 5 is equipped with a screen pipe 2, a plug 3 and a suspended packer 4. The horizontal section of the tubing 5 is divided into multiple well sections by expansion packers 8 for segmented well completion. By installing at least one injection control component 6 and one inflow control component 7 in each well section, the same well injection and production integration is achieved.

[0048] After the adaptive same-well injection and water control completion system is installed, the oil well is in normal production. The produced fluid enters the tubing 5 through the flow control component 7 and is then pumped to the surface by the oil pump 1. When the oil well production decreases and the production efficiency deteriorates, without moving the tubing string, the injection control component 6 can be used to directly inject oil displacement agents or production-enhancing fluids such as CO2 to increase production, thereby improving the degree of recovery and recovery rate.

[0049] This invention is applicable to water control and production enhancement in oilfield production wells, especially for water control completion of new horizontal wells and water control completion of old wells after high water content.

[0050] Example 2

[0051] Based on Example 1, this example provides an adaptive same-well injection and production and water control completion system, as shown in the figure. The inflow control component 7 includes a body and a floating roof 12. The body is a cavity structure. The body includes an upper frustum 10 and a lower cylinder 11. The upper frustum 10 is smaller at the top and larger at the bottom. The larger diameter of the upper frustum 10 is larger than the diameter of the lower cylinder 11.

[0052] The floating plate 12 is disposed in the cavity. The upper truncated cone 10 has an inlet 13 at its top. The lower cylinder 11 has threads on its exterior. Support blocks are spaced apart on the lower cylinder 11. A flow channel 14 is formed between the support blocks and the lower cylinder 11. A flow hole 15 is opened on the lower cylinder 11.

[0053] During oil well production, according to Bernoulli's equation, the flow velocity above the float 12 varies depending on the fluid flowing through it. Fluids with higher viscosity pass through more easily, while those with lower viscosity pass through more difficultly. Since oil has a higher viscosity than water and gas, this allows for autonomous control of water and gas flow.

[0054] The inflow control component 7 is disc-shaped, with a liquid inlet 13 located in the center of the top of the upper truncated cone 10. The float 12 can float freely, and the opening degree of the float 12 will be different when liquids of different viscosities enter the inlet 13. That is, high-viscosity oil increases the pressure on the upper part of the float 12, pushing the float 12 downward and increasing the oil flow rate; low-viscosity water reduces the pressure on the upper part of the float 12, causing the float 12 to float upward, reducing the flow space and preventing water from flowing through; even lower-viscosity gas further reduces the pressure on the upper part of the float 12, causing the float 12 to float upward, minimizing the flow space, and almost completely preventing airflow.

[0055] The fluid flow path is as follows: inlet 13, floating plate 12, flow channel 14, flow hole 15, and inside the oil pipe 5.

[0056] Example 3

[0057] Based on Example 1, this example provides an adaptive same-well injection and production and water control completion system, such as...Figure 3 As shown, the injection control component 6 includes a body 2 and a circular baffle 18. The body 2 has a circular cavity inside, and the circular baffle 18 is disposed inside the circular cavity.

[0058] The second body includes an upper frustum 16 and a lower cylinder 17. The upper frustum 16 is larger at the top and smaller at the bottom. The smaller diameter of the upper frustum 16 is equal to the diameter of the lower cylinder 17. An injection port 22 is provided on the lower cylinder 17. A compression spring 19 is provided between the circular baffle 18 and the upper frustum 16. The diameter of the circular baffle 18 is larger than the diameter of the injection port 22.

[0059] like Figure 3 As shown, the injection control component 6 is disc-shaped, with a circular baffle 18 and a circular cavity coaxial. A liquid injection port 22 is opened in the middle of the lower cylinder 17, and the upper truncated cone 16 and the circular baffle 18 are connected by a compression spring 19.

[0060] When it is necessary to inject oil displacement agent or CO2 and other production-enhancing fluids for spitting and spitting production, the fluid is injected through the oil pipe 5. The fluid flows through the injection port 22 and pushes the circular baffle 18 under hydraulic action. The compression spring 19 is compressed, and the upper truncated cone 2 16 and the cylinder 2 separate, so that the fluid outlet is opened and the fluid flows into the bottom layer to realize liquid injection for increased production.

[0061] Example 4

[0062] Based on Example 1, this example provides an adaptive same-well injection and production and water control completion system, wherein the tubing section 9 is detachably connected to a sand-proof metal mesh 21.

[0063] like Figure 5 As shown, the injection control component 6 and the inflow control component 7 are located inside the sand-control metal mesh 21 to ensure that sand particles do not enter and block the inflow channel. The connection between the sand-control metal mesh 21 and the short section is detachable and can be selected according to whether the formation produces sand. The internal structure of the sand-control metal mesh 21 is shown in [details omitted]. Figure 6 .

[0064] Example 5

[0065] Based on Example 3, this example provides an adaptive same-well injection and production and water control completion system, wherein the compression spring 19 is provided with a protective rubber 20 on the outside.

[0066] like Figure 3 As shown, the outer side of the spring is fitted with a protective rubber 20 that can withstand temperatures up to 270°C, which can prevent sand and other factors from affecting the performance of the spring and extend the service life of the injection device.

[0067] The compression spring grade 19 is determined based on the injection opening pressure.

[0068] The 19th grade of the cylindrical helical compression spring is determined by activating the injection control component 6 for different injection pressures.

[0069] Example 6

[0070] This embodiment provides an adaptive same-well injection and production and water control completion method. During production, the fluid flows through the inlet 13 of the inflow control component 7, passes through the floating roof 12, and then enters the tubing 5, and is extracted by the pumping pump 1.

[0071] During this process, because the viscosity of the oil phase is greater than that of the water phase and the gas phase, the flow velocity of the oil phase through the floating plate 12 is greater than that of the water phase and the gas phase, thereby achieving the purpose of autonomous water and air control;

[0072] When production has been ongoing for a period of time and the recovery rate decreases, requiring the injection of production-enhancing fluid, the fluid is injected into the tubing 5 via a water injection pump. The fluid then enters the annulus through the injection port 22 of the injection control component 6 and is subsequently injected into the formation.

[0073] Before production, such as Figure 6 As shown, it also includes the following steps:

[0074] Step 1) Collect data: wellbore structure, reservoir and fluid properties, logging interpretation results, perforation and fracturing data, daily production reports;

[0075] Step 2) Determine parameters: Based on the collected data, determine the total length, dimensions, material, and thread type of the completion string;

[0076] Step 3) Determine the isolation section: Quantitative analysis is carried out using numerical simulation methods, and multi-factor comprehensive analysis is conducted in combination with drilling data and logging interpretation results to divide several sections or one section with similar production and pressure into the same isolation section.

[0077] The well logging interpretation results include permeability profiles, water saturation profiles, and fracture interpretation results.

[0078] Step 4) Determine the type and quantity of injection control components 6 for each well section based on production output to ensure the desired production output and minimal erosion.

[0079] Step 5) Determine the type and quantity of the inflow control components 7 for each well section according to the water injection requirements; to ensure the desired injection and minimal erosion.

[0080] Step 6) Assembly of tubing string: Clean the production casing wellbore, connect the tubing 5 through the tubing short section 9, assemble the expansion packer 8 according to the isolation well section, and assemble the corresponding number and type of injection control components 6 and inflow control components 7 on the tubing short section 9 of each well section to assemble an adaptive injection and production integrated tubing string.

[0081] Step 7) Running the tubing for production: After running the adaptive injection-production integrated tubing to the predetermined position, set the water-swellable packer 8 and the suspended packer 4, and start production.

[0082] Steps 2) and 3) are existing technologies and will not be described in detail here.

[0083] The type of the inflow control component 7 in step 4) is determined by the flow rate at 2 MPa, including flow rates less than 1.1 m³. 3 / d (corresponding model ZGaf0.5), flow rate is 1.1~9.7m 3 / d (corresponding model ZGaf1.5), flow rate is 9.7~26.8m 3 There are three types: / d (corresponding to model ZGaf2.5).

[0084] The quantity is the total fluid volume within this isolation section / the theoretical fluid throughput of a single inflow control device of a certain type, or the fluid volume is matched according to the combination of different types based on the total fluid volume within this isolation section.

[0085] The type of the injection control component 6 in step 5) is determined by the flow rate at 2 MPa, including flow rates less than 68.7 m³. 3 / d (corresponding model ZGin4.0) and flow rate of 68.7~154.5m 3 There are two types: / d (corresponding model ZGin6.0).

[0086] The flow rates of the inflow control component 7 and the injection control component 6 are estimated flow rates under the theoretical pressure of 2MPa. Therefore, when the critical value is near, it is preferable to select the larger component.

[0087] Example 7

[0088] To further illustrate the effects of the present invention, this embodiment takes a horizontal well in an oil field as an example and uses the present invention for on-site construction.

[0089] The horizontal well has an oil reservoir at a depth of 2400m, a horizontal section length of 1000m, and a formation crude oil viscosity of 3.0mPa.s. There are a total of 4 water injection wells in the surrounding area.

[0090] In April 2020, coiled tubing fracturing was used to fracture 10 sections. The initial daily fluid production was 28.9 m³. 3 The oil yield is 15.3 tons, with a water content of 47.2%. After five years of production, the daily liquid production is projected to reach 27.3 cubic meters by the end of February 2025. 3 The oil volume is 1.5t, with a water content of 94.7%. The current production pressure difference is about 2 MPa. The high water content is attributed to the influence of four surrounding water injection wells.

[0091] By collecting data from individual wells and reservoir and fluid properties, a geological model of the well area was established. Using numerical simulation methods, and combining reservoir properties, fracture development, and actual drilling data, the well was comprehensively analyzed and divided into six isolation sections. For example... Figure 1 As shown.

[0092] Based on five years of production, a comprehensive analysis shows that the heel sections (fifth and sixth packer sections) contributed significantly in the early stages but currently have limited potential. Therefore, they require smaller inflow control units (ZGaf0.5) and smaller injection control units (ZGin4.0). The toe section (first packer section), potentially affected by surrounding injection wells, is the main source of water production. Currently, water control is needed, and later, huff and puff operations will be implemented to release its potential. Therefore, larger inflow control units (ZGaf2.5) and relatively larger injection control units (ZGin4.0 / ZGin6.0) are required. The second, third, and fourth packer sections, unaffected by injection wells and possessing good reservoir oil content and physical properties, have considerable production potential. They require medium-sized inflow control units (ZGaf1.5) and larger injection control units (ZGin6.0).

[0093] in accordance with Figure 7 The experimental flow-pressure drop curve of the adaptive inflow control device shows that, with a production pressure differential of 2 MPa and a white oil flow rate of 15.0 mPa·s, the water-to-oil ratio is approximately 1:1.5, indicating that the device has an "oil-to-water blocking" function. Based on... Figure 8 Based on the experimental flow-pressure drop curve calculation of the injection control device, the ZGin6.0 model can inject approximately 6.2 cubic meters of clean water per hour (148.8 cubic meters / day) for the second, third, and fourth isolation sections with high injection volume requirements, while the ZGin4.0 model can inject approximately 2.5 cubic meters of clean water per hour (60.0 cubic meters / day) for the same injection pressure difference.

[0094] The final configuration of the inflow control components and injection control components for each packer section is shown in the table below:

[0095]

[0096]

[0097] The horizontal well was started in March 2025. After the adaptive same-well injection-production and water-controlled completion string (6 inflow control components 7 and 10 injection control components 6) was installed, the daily fluid production was 25.0 m³. 3 The oil content was 6.6 tons, with a water content of 73.8%, demonstrating a significant effect in controlling water and increasing oil content. For example... Figure 9 As shown.

[0098] The above examples are merely illustrative of the present invention and do not constitute a limitation on the scope of protection of the present invention. All designs that are the same as or similar to the present invention are within the scope of protection of the present invention.

Claims

1. An adaptive same-well injection-production and water control completion system, comprising tubing, casing, and multiple expansion packers, wherein the tubing is connected by tubing stubs, characterized in that: It also includes an injection control component and an inflow control component. Each well section is equipped with at least one injection control component and one inflow control component. The tubing sub section has an installation port. The injection control component and the inflow control component are installed in different installation ports, and their axes are perpendicular to the axis of the tubing sub section.

2. The adaptive same-well injection and production and water control completion system according to claim 1, characterized in that: The inflow control component includes a body and a floating plate. The body has a cavity structure and includes an upper frustum and a lower cylinder. The upper frustum is smaller at the top and larger at the bottom, and the larger diameter of the upper frustum is larger than the diameter of the lower cylinder. The floating plate is located inside the cavity. The top of the upper truncated cone has an inlet. The lower cylinder has threads on its exterior. Support blocks are spaced apart on the lower cylinder. A flow channel is formed between the support blocks and the lower cylinder. Flow holes are opened on the lower cylinder.

3. The adaptive same-well injection and production and water control completion system according to claim 1, characterized in that: The injection control component includes a second body and a circular baffle. The second body has a circular cavity inside, and the circular baffle is disposed inside the circular cavity. The second body includes an upper truncated cone and a lower cylinder. The upper truncated cone is larger at the top and smaller at the bottom. The smaller diameter of the upper truncated cone is equal to the diameter of the lower cylinder. An injection port is provided on the lower cylinder. A compression spring is provided between the circular baffle and the upper truncated cone. The diameter of the circular baffle is larger than the diameter of the injection port.

4. The adaptive same-well injection and production and water control completion system according to claim 1, characterized in that: The oil pipe section is detachably connected to a sand-proof metal mesh.

5. The adaptive same-well injection and production and water control completion system according to claim 3, characterized in that: The compression spring is provided with protective rubber on the outside.

6. The adaptive same-well injection and production and water control completion system according to claim 3, characterized in that: The compression spring grade is determined based on the injection opening pressure.

7. An adaptive method for simultaneous injection and production and water control completion, characterized in that: When using the adaptive same-well injection and production and water control completion system according to any one of claims 1-6, during production, the fluid flows through the inlet of the control component, passes through the floating roof, enters the tubing, and is extracted by the pump. During this process, because the viscosity of the oil phase is greater than that of the water and gas phases, the flow velocity of the oil phase through the floating plate is greater than that of the water and gas phases, thereby achieving the purpose of autonomous water and air control; When production has been ongoing for a period of time and the recovery rate decreases, requiring the injection of production-enhancing fluids, the fluids are injected into the tubing via a water injection pump. The fluids then enter the annulus through the injection port of the injection control component and are subsequently injected into the formation.

8. The adaptive same-well injection and production and water control completion method according to claim 7, characterized in that: Before production, the following steps are also included: Step 1) Collect data: wellbore structure, reservoir and fluid properties, logging interpretation results, perforation and fracturing data, daily production reports; Step 2) Determine parameters: Based on the collected data, determine the total length, dimensions, material, and thread type of the completion string; Step 3) Determine the isolation section: Quantitative analysis is carried out using numerical simulation methods, and multi-factor comprehensive analysis is conducted in combination with drilling data and logging interpretation results to divide several sections or one section with similar production and pressure into the same isolation section. The well logging interpretation results include permeability profiles, water saturation profiles, and fracture interpretation results. Step 4) Determine the type and quantity of injection control components for each well section based on production output; Step 5) Determine the type and quantity of inflow control components for each well section based on the water injection volume requirements; Step 6) Assembly of tubing string: Connect the tubing through tubing stubs, assemble the expandable packer according to the well section, and assemble the corresponding number and type of injection control components and inflow control components on the tubing stubs of each well section to form an adaptive injection and production integrated tubing string. Step 7) Running the tubing for production: After running the adaptive injection-production integrated tubing to the predetermined position, set the water-swellable packer and the suspended packer, and start production.

9. The adaptive same-well injection and production and water control completion method according to claim 7, characterized in that: The type of inflow control component in step 4) is determined by the flow rate at 2 MPa, including flow rates less than 1.1 m³. 3 / d, with a flow rate of 1.1–9.7 m³ / d. 3 / d, with a flow rate of 9.7–26.8 m³ / d. 3 / d has three types.

10. The adaptive same-well injection and production and water control completion method according to claim 7, characterized in that: The type of injection control component in step 5) is determined by the flow rate at 2 MPa, including flow rates less than 68.7 m³. 3 / d and the overflow rate are 68.7~154.5m 3 / d has two types.

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