Horizontal well cooperative cold production method and device

Abstract

The application provides a horizontal well cooperative cold production method and device, and relates to the technical field of oil exploitation. The method comprises the following steps: obtaining the oil layer thickness and the formation pressure; determining the height difference between the lower horizontal well and the bottom of the oil layer and the height difference between the upper horizontal well and the lower horizontal well according to the oil layer thickness and the formation pressure; determining the horizontal distance between the adjacent upper horizontal well and the adjacent lower horizontal well according to the oil layer thickness and the formation pressure; determining the cold production position of each upper horizontal well and each lower horizontal well according to the height difference between the lower horizontal well and the bottom of the oil layer, the height difference between the upper horizontal well and the lower horizontal well, and the horizontal distance between the adjacent upper horizontal well and the adjacent lower horizontal well; determining the production pressure difference of the upper horizontal well and the lower horizontal well according to the oil layer thickness, the formation pressure and the cold production position of each upper horizontal well and each lower horizontal well; and sending a message instruction for cooperative cold production of the oil layer by each upper horizontal well and each lower horizontal well.

Description

Technical Field

[0001] This invention relates to the field of oil extraction technology, and more particularly to a method and apparatus for horizontal well-assisted cold extraction. Background Technology

[0002] This section is intended to provide background or context for the embodiments of the invention set forth in the claims. The description herein is not an admission that it is prior art simply because it is included in this section.

[0003] Currently, most oilfields in heavy oil belts that are already in production use horizontal well cold production methods. These horizontal well networks are single-layer networks, meaning a single layer of horizontal wells is deployed near the bottom of the oil layer. Because oil layers in heavy oil belts are generally quite thick, this single-layer horizontal well network approach leads to uneven utilization of reserves within the layer. Therefore, it is necessary to deploy two layers of horizontal wells, one above the other, for coordinated cold production. In existing technologies, the same production differential pressure is applied to each horizontal well. However, due to the uneven spatial distribution of formation pressure, applying the same production differential pressure to both layers of horizontal wells causes rapid degassing in the upper layer, making further oil production impossible. Furthermore, the small vertical well spacing between the upper and lower layers of horizontal wells during coordinated cold production results in some overlap in the drainage areas of the two wells, causing interference and affecting production efficiency. Summary of the Invention

[0004] This invention proposes a horizontal well-assisted cold production method to fully exploit oil reservoirs, improve oil production efficiency, and prevent degassing in horizontal wells. The method includes:

[0005] To obtain the oil layer thickness and formation pressure;

[0006] Based on the oil layer thickness and formation pressure, determine the height difference between the lower horizontal well and the bottom of the oil layer, and the height difference between the upper horizontal well and the lower horizontal well; wherein, each lower horizontal well is located on the first horizontal plane, and each upper horizontal well is located on the second horizontal plane;

[0007] Based on the oil layer thickness and formation pressure, determine the horizontal distance between adjacent upper horizontal wells and the horizontal distance between adjacent lower horizontal wells;

[0008] Based on the height difference between the lower horizontal well and the bottom of the oil layer, the height difference between the upper horizontal well and the lower horizontal well, the horizontal distance between adjacent upper horizontal wells, and the horizontal distance between adjacent lower horizontal wells, the cold production location of each upper horizontal well and each lower horizontal well is determined.

[0009] Based on the oil layer thickness, formation pressure, and the cold production location of each upper and lower horizontal well, the production pressure difference between the upper and lower horizontal wells is determined; wherein, the production pressure difference of each upper horizontal well is the same, and the production pressure difference of each lower well is the same.

[0010] After determining the production pressure difference between the upper and lower horizontal wells, a message command is issued to coordinate cold production of the oil layer using each upper and lower horizontal well.

[0011] This invention provides a horizontal well-assisted cold production device for fully exploiting oil reservoirs, improving oil production efficiency, and preventing degassing in horizontal wells. The device includes:

[0012] The first parameter acquisition module is used to obtain the oil layer thickness and formation pressure.

[0013] The height difference determination module is used to determine the height difference between the lower horizontal well and the bottom of the oil layer, and the height difference between the upper horizontal well and the lower horizontal well, based on the oil layer thickness and formation pressure; wherein each lower horizontal well is located on a first horizontal plane, and each upper horizontal well is located on a second horizontal plane;

[0014] The horizontal distance determination module is used to determine the horizontal distance between adjacent upper horizontal wells and adjacent lower horizontal wells based on the oil layer thickness and formation pressure.

[0015] The cold production location determination module is used to determine the cold production location of each upper horizontal well and each lower horizontal well based on the height difference between the lower horizontal well and the bottom of the oil layer, the height difference between the upper horizontal well and the lower horizontal well, the horizontal distance between adjacent upper horizontal wells, and the horizontal distance between adjacent lower horizontal wells.

[0016] The production pressure differential determination module is used to determine the production pressure differential between upper and lower horizontal wells based on the oil layer thickness, formation pressure, and the cold production location of each upper and lower horizontal well; wherein, the production pressure differential of each upper horizontal well is the same, and the production pressure differential of each lower well is the same.

[0017] The collaborative cold production control module is used to issue a message command to conduct collaborative cold production of the oil layer using each upper horizontal well and each lower horizontal well after determining the production pressure difference between the upper and lower horizontal wells.

[0018] An embodiment of the present invention proposes a computer device, including a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, it implements a horizontal well coordinated cold extraction method.

[0019] This invention provides a computer-readable storage medium storing a computer program that, when executed by a processor, implements a horizontal well coordinated cold extraction method.

[0020] This invention provides a computer program product, which includes a computer program that, when executed by a processor, implements a horizontal well collaborative cold extraction method.

[0021] The horizontal well coordinated cold production method and apparatus proposed in this invention can solve the problems of uneven utilization of intra-layer reserves in existing technologies, and the easy occurrence of degassing and low oil production efficiency in horizontal wells. This invention obtains the oil layer thickness and formation pressure; based on the oil layer thickness and formation pressure, it determines the height difference between the lower horizontal well and the bottom of the oil layer, and the height difference between the upper horizontal well and the lower horizontal well; wherein each lower horizontal well is located on a first horizontal plane, and each upper horizontal well is located on a second horizontal plane; based on the oil layer thickness and formation pressure, it determines the horizontal distance between adjacent upper horizontal wells and the horizontal distance between adjacent lower horizontal wells; based on the lower horizontal well and the oil layer... The cold production location of each upper and lower horizontal well is determined by considering the height difference at the bottom of the formation, the height difference between upper and lower horizontal wells, the horizontal distance between adjacent upper and lower horizontal wells, and the horizontal distance between adjacent lower horizontal wells. Based on the oil layer thickness, formation pressure, and the cold production location of each upper and lower horizontal well, the production pressure difference between the upper and lower horizontal wells is determined. The production pressure difference is the same for all upper and lower horizontal wells. After determining the production pressure difference, a message command is issued to coordinate cold production of the oil layer using each upper and lower horizontal well. This embodiment of the invention can determine the cold production location of each upper and lower horizontal well, achieving full exploitation of the oil layer, improving oil production efficiency, and setting separate production pressure differences for upper and lower horizontal wells to prevent degassing of the horizontal wells. Attached Figure Description

[0022] To more clearly illustrate the technical solutions of the embodiments of this application, the drawings used in the description of the embodiments will be briefly introduced below. Obviously, the drawings described below are some embodiments of this application. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0023] Figure 1 This is a schematic flowchart of the horizontal well coordinated cold extraction method in an embodiment of the present invention;

[0024] Figure 2 This is a specific example diagram of the horizontal well coordinated cold extraction method in the embodiments of the present invention;

[0025] Figure 3 This is a specific example diagram of the horizontal well coordinated cold extraction method in the embodiments of the present invention;

[0026] Figure 4This is a specific example diagram of the horizontal well coordinated cold extraction method in the embodiments of the present invention;

[0027] Figure 5 This is a specific example diagram of the horizontal well coordinated cold extraction method in the embodiments of the present invention;

[0028] Figure 6 This is a specific example diagram of the horizontal well coordinated cold extraction method in the embodiments of the present invention;

[0029] Figure 7 This is a specific example diagram of the horizontal well coordinated cold extraction method in the embodiments of the present invention;

[0030] Figure 8 This is a specific example diagram of the horizontal well coordinated cold extraction method in the embodiments of the present invention;

[0031] Figure 9 This is a specific example diagram of the horizontal well coordinated cold extraction method in the embodiments of the present invention;

[0032] Figure 10 This is a specific example diagram of the horizontal well coordinated cold extraction method in the embodiments of the present invention;

[0033] Figure 11 This is a schematic diagram of the horizontal well coordinated cold extraction device in an embodiment of the present invention;

[0034] Figure 12 This is a specific example diagram of the horizontal well coordinated cold extraction device in the embodiments of the present invention;

[0035] Figure 13 This is a schematic diagram of a computer device in an embodiment of the present invention.

[0036] Figure label:

[0037] 1-Outer shell, 2-Inlet, 3-First guide cavity, 4-First guide hole, 5-Second guide cavity, 6-Second guide hole, 7-First base, 8-Second base, 9-Baffle, 10-First connecting rod, 11-First rotating shaft, 12-Second connecting rod, 13-Fixed shaft, 14-Second rotating shaft, 15-Third connecting rod, 16-Conduction plate, 17-Follower float, 18-Iron sheet, 19-Conduction cavity, 20-Density floating cavity, 21-Float, 22-Magnet, 23-Third guide hole, 24-Weak spring, 25-Outlet guide cavity, 26-Outlet, 27-Inlet controller, 28-Flow channel, 29-Sand screen pipe. Detailed Implementation

[0038] To make the objectives, technical solutions, and advantages of the embodiments of the present invention clearer, the embodiments of the present invention will be further described in detail below with reference to the accompanying drawings. Here, the illustrative embodiments of the present invention and their descriptions are used to explain the present invention, but are not intended to limit the present invention.

[0039] In this document, the term "and / or" merely describes a relationship, indicating that three relationships can exist. For example, A and / or B can represent three cases: A alone, A and B simultaneously, and B alone. Furthermore, the term "at least one" in this document means any combination of at least two of any one or more elements. For example, including at least one of A, B, and C can mean including any one or more elements selected from the set consisting of A, B, and C.

[0040] In the description of this specification, the terms "comprising," "including," "having," and "containing" are open-ended terms, meaning that they include but are not limited to. The terms "an embodiment," "a specific embodiment," "some embodiments," and "for example," etc., refer to specific features, structures, or characteristics described in connection with that embodiment or example that are included in at least one embodiment or example of this application. In this specification, the illustrative expressions of the above terms do not necessarily refer to the same embodiment or example. Furthermore, the specific features, structures, or characteristics described can be combined in any suitable manner in one or more embodiments or examples. The order of steps involved in the various embodiments is used to illustrate the implementation of this application, and the order of steps is not limited and can be adjusted appropriately as needed.

[0041] The principles and spirit of the present invention will be explained in detail below with reference to several representative embodiments.

[0042] Figure 1 This is a schematic flowchart of the horizontal well coordinated cold extraction method according to an embodiment of the present invention. Figure 1 As shown, the method includes:

[0043] Step 101: Obtain the oil layer thickness and formation pressure;

[0044] Step 102: Determine the height difference between the lower horizontal well and the bottom of the oil layer, and the height difference between the upper horizontal well and the lower horizontal well, based on the oil layer thickness and formation pressure; wherein each lower horizontal well is located on the first horizontal plane, and each upper horizontal well is located on the second horizontal plane.

[0045] Step 103: Determine the horizontal distance between adjacent upper horizontal wells and adjacent lower horizontal wells based on the oil layer thickness and formation pressure.

[0046] Step 104: Determine the cold production location of each upper horizontal well and each lower horizontal well based on the height difference between the lower horizontal well and the bottom of the oil layer, the height difference between the upper horizontal well and the lower horizontal well, the horizontal distance between adjacent upper horizontal wells, and the horizontal distance between adjacent lower horizontal wells.

[0047] Step 105: Determine the production pressure difference between the upper and lower horizontal wells based on the oil layer thickness, formation pressure, and the cold production location of each upper and lower horizontal well; wherein the production pressure difference is the same for each upper horizontal well and the same for each lower well.

[0048] Step 106: After determining the production pressure difference between the upper and lower horizontal wells, issue a message command to use each upper and lower horizontal well to perform coordinated cold production of the oil layer.

[0049] Depend on Figure 1 As shown in the flowchart, this embodiment of the invention obtains the oil layer thickness and formation pressure; based on the oil layer thickness and formation pressure, it determines the height difference between the lower horizontal well and the bottom of the oil layer, and the height difference between the upper horizontal well and the lower horizontal well; wherein, each lower horizontal well is located on a first horizontal plane, and each upper horizontal well is located on a second horizontal plane; based on the oil layer thickness and formation pressure, it determines the horizontal distance between adjacent upper horizontal wells and the horizontal distance between adjacent lower horizontal wells; based on the height difference between the lower horizontal well and the bottom of the oil layer, the height difference between the upper horizontal well and the lower horizontal well, and the height difference between adjacent upper horizontal wells... The horizontal distance between upper and lower horizontal wells is used to determine the cold production location of each upper and lower horizontal well. Based on the oil layer thickness, formation pressure, and the cold production location of each upper and lower horizontal well, the production pressure difference between the upper and lower horizontal wells is determined. The production pressure difference is the same for all upper and lower horizontal wells. After determining the production pressure difference, a message command is issued to coordinate cold production of the oil layer using each upper and lower horizontal well. This embodiment of the invention can determine the cold production location of each upper and lower horizontal well, achieving full exploitation of the oil layer, improving oil production efficiency, and setting separate production pressure differences for upper and lower horizontal wells to prevent degassing of the horizontal wells.

[0050] To provide a clearer explanation of the above-mentioned horizontal well coordinated cold production method, each step will be described in detail below.

[0051] In one embodiment of the present invention, determining the height difference between the lower horizontal well and the bottom of the oil layer, and the height difference between the upper horizontal well and the lower horizontal well, based on the oil layer thickness and formation pressure, includes: adjusting the height difference between the lower horizontal well and the bottom of the oil layer, and the height difference between the upper horizontal well and the lower horizontal well, using numerical simulation methods based on the oil layer thickness and formation pressure, to determine the maximum oil production value; and determining the height difference between the lower horizontal well and the bottom of the oil layer, and the height difference between the upper horizontal well and the lower horizontal well, based on the maximum oil production value.

[0052] Figure 2 This is a specific example diagram of the horizontal well coordinated cold extraction method in the embodiments of the present invention.

[0053] In specific implementation, refer to Figure 2 The reservoir numerical simulator inputs the oil layer thickness, formation pressure, height difference between the lower horizontal well and the bottom of the oil layer, and height difference between the upper horizontal well and the lower horizontal well. It then adjusts the height differences between the lower and upper horizontal wells to determine the maximum oil production. When the oil production obtained from the reservoir numerical simulator is at its maximum, the height difference between the lower and upper horizontal wells is defined as h1, and the height difference between the upper and lower horizontal wells as h2. Here, H represents the oil layer thickness. Furthermore, to ensure the accuracy of the oil production results obtained from the reservoir numerical simulator, the viscosity and density parameters of the crude oil can also be input.

[0054] In practice, the height difference between the lower horizontal well and the bottom of the oil layer, and the height difference between the upper horizontal well and the lower horizontal well are determined according to the following formulas:

[0055]

[0056]

[0057] Where h1 is the height difference between the lower horizontal well and the bottom of the oil layer, in meters; h2 is the height difference between the upper horizontal well and the lower horizontal well, in meters; and H is the thickness of the oil layer, in meters.

[0058] In one embodiment of the present invention, determining the horizontal distance between adjacent upper horizontal wells and adjacent lower horizontal wells based on the oil layer thickness and formation pressure includes: adjusting the horizontal distance between adjacent upper horizontal wells and adjacent lower horizontal wells using a numerical simulation method based on the oil layer thickness and formation pressure to determine the maximum oil production value; determining the horizontal distance between adjacent upper horizontal wells and adjacent lower horizontal wells based on the maximum oil production value; wherein the horizontal distance between adjacent upper horizontal wells is the same as the horizontal distance between adjacent lower horizontal wells.

[0059] In practice, the reservoir thickness, formation pressure, and horizontal distances between adjacent upper and lower horizontal wells are input into the reservoir numerical simulator. The horizontal distances between adjacent upper and lower horizontal wells are adjusted within the simulator to determine the maximum oil production. At the point of maximum oil production, the horizontal distances between adjacent upper and lower horizontal wells are then determined. (Reference) Figure 2 The horizontal distance between adjacent upper horizontal wells and the horizontal distance between adjacent lower horizontal wells are the same, both being WS.

[0060] Figure 3 This is a specific example diagram of the horizontal well coordinated cold extraction method in the embodiments of the present invention.

[0061] In one embodiment of the present invention, reference is made to Figure 3 By inputting the oil layer thickness H, formation pressure P, and horizontal distance WS between adjacent horizontal wells into the reservoir numerical simulator, the relationship between the horizontal distance WS between adjacent horizontal wells and the oil layer thickness H can be obtained when the formation pressure P = 9 MPa: WS = 4353.59H (0.79) When the formation pressure P = 8 MPa, the relationship between the horizontal distance WS between adjacent horizontal wells and the oil layer thickness H is WS = 4179.4H. -0.79 When the formation pressure P = 7 MPa, the relationship between the horizontal distance WS between adjacent horizontal wells and the oil layer thickness H is WS = 4005.3H. -0.79 When the formation pressure P = 6 MPa, the relationship between the horizontal distance WS between adjacent horizontal wells and the oil layer thickness H is WS = 3831.2H. -0.79 When the formation pressure P = 5 MPa, the relationship between the horizontal distance WS between adjacent horizontal wells and the oil layer thickness H is WS = 3657.02H. (0.79) .

[0062] In practice, the horizontal distance between adjacent upper horizontal wells and the horizontal distance between adjacent lower horizontal wells are determined according to the following formulas:

[0063] WS = 5422.9e -0.044P H 0.79 ;

[0064] Where WS represents the horizontal distance between adjacent upper horizontal wells and the horizontal distance between adjacent lower horizontal wells; P represents formation pressure; and H represents oil layer thickness.

[0065] In one embodiment of the present invention, the cold production location of each upper horizontal well and each lower horizontal well is determined based on the height difference h1 between the lower horizontal well and the bottom of the oil layer, the height difference h2 between the upper horizontal well and the lower horizontal well, the horizontal distance WS between adjacent upper horizontal wells, and the horizontal distance WS between adjacent lower horizontal wells. The cold production location of each upper horizontal well and each lower horizontal well is referenced. Figure 2 In this case, the horizontal position of each upper horizontal well is located in the middle of the positions of the two lower horizontal wells, that is, one upper horizontal well and two lower horizontal wells form an isosceles triangle.

[0066] Currently, most oilfields in heavy oil belts that are already in production use the foam oil horizontal well cold production method. The horizontal well network is a single-layer horizontal well, meaning that a single layer of horizontal wells is deployed near the bottom of the oil layer within the same development layer. Because oil layers in heavy oil belts are generally quite thick, using a single-layer horizontal well network leads to uneven utilization of reserves within the layer. The dual-horizontal-well three-dimensional network proposed in this invention, which deploys upper and lower layers of horizontal wells at the bottom and upper-middle parts of the oil layer within the same development layer, can effectively increase the degree of reserve utilization. By adjusting the cold production positions of the upper and lower horizontal wells, the cold production development effect is effectively improved.

[0067] In one embodiment of the present invention, determining the production pressure difference between the upper and lower horizontal wells based on the oil layer thickness, formation pressure, and the cold production location of each upper and lower horizontal well includes: adjusting the production pressure difference between the upper and lower horizontal wells using numerical simulation based on the oil layer thickness, formation pressure, and the cold production location of each upper and lower horizontal well to determine the maximum oil production value; and determining the production pressure difference between the upper and lower horizontal wells based on the maximum oil production value.

[0068] In practice, the oil layer thickness, formation pressure, cold production location of each upper and lower horizontal well, and production pressure difference between the upper and lower horizontal wells are input into the reservoir numerical simulator. The production pressure difference between the upper and lower horizontal wells is adjusted to determine the maximum oil production. When the oil production is at its maximum, the production pressure difference between the upper and lower horizontal wells is determined.

[0069] Figures 4-7 This is a specific example diagram of the horizontal well coordinated cold extraction method in the embodiments of the present invention.

[0070] In one embodiment of the present invention, a reservoir numerical simulator is used to obtain the relationship curves between horizontal well production pressure differential and formation pressure under different oil layer thicknesses; when the oil layer thickness is 10m, the curves of the upper horizontal well and the lower horizontal well with formation pressure are referenced. Figure 4 When the oil layer thickness is 15m, the curves showing the variation of formation pressure between the upper and lower horizontal wells are referenced. Figure 5 When the oil layer thickness is 20m, the curves of the upper horizontal well versus formation pressure and the curves of the lower horizontal well versus formation pressure are referenced. Figure 6 When the oil layer thickness is 25m, the curves showing the variation of formation pressure between the upper and lower horizontal wells are referenced. Figure 7 Therefore, it can be seen that the production pressure differential of the upper horizontal well is lower than that of the lower well, and the production pressure differential is adjusted according to the changes in formation pressure during oil production. This can prevent the upper horizontal well from rapidly degassing, which would prevent it from continuing to produce oil and thus reduce oil production.

[0071] In one embodiment of the present invention, the production pressure differential of the upper horizontal well is determined according to the following formula:

[0072] ΔP1=(0.0948lnH+0.4788)e 0.158P ;

[0073] The production pressure differential of the lower horizontal well is determined using the following formula:

[0074] ΔP2=(0.0824lnH+0.4165)e 0.1577P ;

[0075] Wherein, ΔP1 represents the production pressure differential of the upper horizontal well, in MPa; ΔP2 represents the production pressure differential of the lower horizontal well, in MPa; P represents the formation pressure, in MPa; and H represents the oil layer thickness, in meters.

[0076] In practice, the production pressure difference between the upper and lower horizontal wells is determined using the following formula:

[0077]

[0078] Wherein, ΔP i a represents the production pressure differential of the i-th horizontal well, in MPa; i b represents the first correlation coefficient indicating the production pressure differential of the i-th horizontal well; i The second correlation coefficient represents the production pressure differential of the i-th horizontal well; c i The third correlation coefficient represents the production pressure difference of the i-th horizontal well; when i is 1, it represents the calculation of the production pressure difference of the upper horizontal well, and when i is 2, it represents the calculation of the production pressure difference of the lower horizontal well; P represents the formation pressure in MPa; H represents the oil layer thickness in m.

[0079] To address the issue of uneven pressure distribution in horizontal well sections and prevent gas from entering the horizontal well section during oil production, thus avoiding degassing, in one embodiment of the present invention, formation-related parameters are acquired. These parameters include: permeability, porosity, oil saturation, number of interlayers, longitudinal position of the interlayers in the formation, and lateral position of the interlayers in the formation, or any combination thereof. Based on the formation-related parameters, formation pressure, horizontal well length, and the height difference between the horizontal well and the bottom of the oil layer, the location of the first inflow controller, the number of inflow controllers, and the distance between adjacent inflow controllers are determined within the horizontal well. The horizontal well includes an upper horizontal well and a lower horizontal well.

[0080] In one embodiment of the present invention, the location, number, and distance between adjacent inflow controllers of the first inflow controller within the horizontal well are determined based on formation-related parameters, formation pressure, horizontal well length, and the height difference between the horizontal well and the bottom of the oil layer. This includes: receiving multiple preset sets of parameters for the location, number, and distance between adjacent inflow controllers of the first inflow controllers; using numerical simulation to sequentially read the location, number, and distance between adjacent inflow controllers of each set of first inflow controllers based on formation-related parameters, formation pressure, horizontal well length, and the height difference between the horizontal well and the bottom of the oil layer, and determining the maximum oil production value; and determining the location, number, and distance between adjacent inflow controllers of the first inflow controller within the horizontal well based on the maximum oil production value.

[0081] In practice, multiple sets of first inflow controller positions, the number of inflow controllers, and the distance parameters between adjacent inflow controllers are preset. Permeability, porosity, oil saturation, number of interlayers, longitudinal position of interlayers in the formation, lateral position of interlayers in the formation, formation pressure, horizontal well length, and height difference between the horizontal well and the bottom of the oil layer are input into the reservoir numerical simulator. Then, the positions, the number of inflow controllers, and the distance between adjacent inflow controllers of each set of first inflow controllers are sequentially input into the reservoir numerical simulator to determine the positions, the number of inflow controllers, and the distance between adjacent inflow controllers of the set of first inflow controllers that will maximize the oil production output of the reservoir numerical simulator. The position of the first inflow controller is determined based on the distance between the first inflow controller and the foot of the horizontal well.

[0082] In another embodiment of the present invention, formation-related parameters, formation pressure, horizontal well length, and height difference between the horizontal well and the bottom of the oil layer are input into the location parameter determination model, and the model outputs the position of the first inflow controller in the horizontal well, the number of inflow controllers, and the distance between adjacent inflow controllers. The location parameter determination model is obtained by training a machine learning model based on historical formation-related parameters, historical formation pressure, historical horizontal well length, historical height difference between the horizontal well and the bottom of the oil layer, and the corresponding historical position of the first inflow controller in the horizontal well, the historical number of inflow controllers, and the historical distance between adjacent inflow controllers.

[0083] In practical implementation, the location parameter determination model is determined by inputting parameters such as permeability, porosity, oil saturation, number of interlayers, longitudinal and lateral positions of the interlayers in the formation, formation pressure, horizontal well length, and the height difference between the horizontal well and the bottom of the oil layer. The output parameters are the position of the first inflow controller within the horizontal well, the number of inflow controllers, and the distance between adjacent inflow controllers. The location parameter determination model is based on historical permeability, historical porosity, historical oil saturation, historical number of interlayers, historical longitudinal and lateral positions of the interlayers in the formation, historical formation pressure, historical horizontal well length, and the height difference between the historical horizontal well and the bottom of the oil layer. The parameters are determined by the model, historical formation pressure, historical horizontal well length, historical height difference between the horizontal well and the bottom of the oil layer, and the corresponding historical first inflow controller position, historical number of inflow controllers, and historical distance between adjacent inflow controllers within the horizontal well. The machine learning model is trained using a fully connected deep neural network model, which has 9 neurons in the input layer and 3 neurons in the output layer. The basic principle of the neural network model is to transmit signals through forward propagation and errors through backward propagation. The weights and biases of each neuron are gradually established based on the training data to obtain the final deep neural network model.

[0084] Figure 8 This is a specific example diagram of the horizontal well coordinated cold extraction method in the embodiments of the present invention.

[0085] In one embodiment of the present invention, reference is made to Figure 8 The inflow controller (ICD) includes:

[0086] 1. Outer shell; 2. Inlet; 3. First guide cavity; 4. First guide hole; 5. Second guide cavity; 6. Second guide hole; 7. First base; 8. Second base; 9. Baffle; 10. First connecting rod; 11. First rotating shaft; 12. Second connecting rod; 13. Fixed shaft; 14. Second rotating shaft; 15. Third connecting rod; 16. Conducting plate; 17. Follower float; 18. Iron sheet; 19. Conducting cavity; 20. Density floating cavity; 21. Float; 22. Magnet; 23. Third guide hole; 24. Weak spring; 25. Outlet guide cavity; 26. Outlet.

[0087] In this structure, inlet 2 and outlet 26 are respectively located on both sides of the outer casing 1. Inlet 2 communicates with the first guide cavity 3. The first guide cavity 3 communicates with the second guide cavity 5 through the first guide hole 4. The first guide cavity 3 communicates with the density floating cavity 20 through the third guide hole 23. Magnet 22 is embedded in float 21, which floats within the density floating cavity 20. Conducting cavity 19 is a sealed cavity adjacent to the density floating cavity 20. Iron sheet 18 is embedded in follower float 17, which moves within the conducting cavity 19 along with float 21. Conducting plate 16 is located below follower float 17 and is connected to the first end of third connecting rod 15. The second end of third connecting rod 15 is connected to the first end of second connecting rod 12 via second rotating shaft 14. Fixed shaft 13 is also present. The second connecting rod 12 is located on the inner shell separating the conduction cavity 19 and the second guide cavity 5. It passes through the inner shell separating the conduction cavity 19 and the second guide cavity 5 via the fixed shaft 13 to change the transmission direction. The second end of the second connecting rod 12 is connected to the first end of the first connecting rod 10 via the first rotating shaft 11. The second end of the first connecting rod 10 is connected to the baffle 9. The first end of the weak spring 24 is fixed on the inner shell of the second guide cavity 5. The second end of the weak spring 24 is connected to the baffle 9. The first base 7 and the second base 8 are located between the second guide cavity 5 and the outlet guide cavity 25. The second guide hole 6 is located between the first base 7 and the second base 8. The second guide cavity 5 communicates with the outlet guide cavity 25 through the second guide hole 6. The outlet guide cavity 25 communicates with the outlet 26.

[0088] Figure 9 This is a specific example diagram of the horizontal well coordinated cold extraction method in the embodiments of the present invention.

[0089] In one embodiment of the present invention, reference is made to Figure 9 Crude oil flows in from inlet 2 and flows out through the first guide cavity 3, the first guide hole 4, the second guide cavity 5, the second guide hole 6, the outlet guide cavity 25, and the outlet 26. When the crude oil contains gas, the gas will enter the density floating cavity 20 through the third guide hole 23, reducing the density of the crude oil. The float 21 moves downward. Since the float 21 has a magnet 22 embedded in it and the follower float 17 has an iron piece 18 embedded in it, the follower float 17 moves downward. The follower float presses down on the transmission plate 16. Through the transmission action of the third connecting rod 15, the second rotating shaft 14, the fixed shaft 13, the second connecting rod 12, the first rotating shaft 11, and the first connecting rod 10, the baffle 9 moves upward, blocking the second guide hole between the first base 7 and the second base 8. This achieves automatic closure of the inflow controller, preventing gas from entering the horizontal well and causing degassing in the horizontal well section, making it impossible to continue oil production.

[0090] Figure 10 This is a specific example diagram of the horizontal well coordinated cold extraction method in the embodiments of the present invention.

[0091] In one embodiment of the present invention, the inflow controller 27 and the sand screen tube 29 are installed as follows: Figure 10 Crude oil enters the horizontal well's flow channel 28 from the oil layer through the sand screen 29, and then enters the horizontal well through the inflow controller 27 for oil production and transportation. The sand screen 29 is used to prevent sand in the crude oil from entering the horizontal well, and the inflow controller 27 is used to prevent gas from entering the horizontal well.

[0092] It should be noted that although the operation of the method of the present invention has been described in a specific order in the above embodiments and figures, this does not require or imply that the operations must be performed in that specific order, or that all the operations shown must be performed to achieve the desired result. Additionally or alternatively, certain steps may be omitted, multiple steps may be combined into one step, and / or one step may be broken down into multiple steps.

[0093] The implementation of the horizontal well coordinated cold production device can refer to the implementation of the above method, and the repeated parts will not be described again. The term "module" or "unit" used below can be a combination of software and / or hardware to achieve a predetermined function. Although the device described in the following embodiments is preferably implemented in software, hardware implementation, or a combination of software and hardware, is also possible and contemplated.

[0094] Based on the same inventive concept, this invention also proposes a horizontal well coordinated cold extraction device, such as... Figure 11 As shown, the device includes:

[0095] The first parameter acquisition module 1101 is used to acquire the oil layer thickness and formation pressure.

[0096] The height difference determination module 1102 is used to determine the height difference between the lower horizontal well and the bottom of the oil layer, and the height difference between the upper horizontal well and the lower horizontal well, based on the oil layer thickness and formation pressure; wherein each lower horizontal well is located on a first horizontal plane, and each upper horizontal well is located on a second horizontal plane;

[0097] The horizontal distance determination module 1103 is used to determine the horizontal distance between adjacent upper horizontal wells and adjacent lower horizontal wells based on the oil layer thickness and formation pressure.

[0098] The cold production location determination module 1104 is used to determine the cold production location of each upper horizontal well and each lower horizontal well based on the height difference between the lower horizontal well and the bottom of the oil layer, the height difference between the upper horizontal well and the lower horizontal well, the horizontal distance between adjacent upper horizontal wells, and the horizontal distance between adjacent lower horizontal wells.

[0099] The production pressure differential determination module 1105 is used to determine the production pressure differential between the upper and lower horizontal wells based on the oil layer thickness, formation pressure, and the cold production location of each upper and lower horizontal well; wherein the production pressure differential of each upper horizontal well is the same, and the production pressure differential of each lower well is the same.

[0100] The collaborative cold production control module 1106 is used to issue a message command to conduct collaborative cold production of the oil layer using each upper horizontal well and each lower horizontal well after determining the production pressure difference between the upper and lower horizontal wells.

[0101] In one embodiment of the present invention, the height difference determination module 1102 is specifically used for:

[0102] Based on the oil layer thickness and formation pressure, numerical simulation is used to adjust the height difference between the lower horizontal well and the bottom of the oil layer, and the height difference between the upper horizontal well and the lower horizontal well, to determine the maximum oil production. Based on the maximum oil production, the height difference between the lower horizontal well and the bottom of the oil layer, and the height difference between the upper horizontal well and the lower horizontal well are determined.

[0103] In one embodiment of the present invention, the height difference determination module 1102 is specifically used for:

[0104] The height difference between the lower horizontal well and the bottom of the oil layer, and the height difference between the upper horizontal well and the lower horizontal well are determined using the following formulas:

[0105]

[0106]

[0107] Where h1 is the height difference between the lower horizontal well and the bottom of the oil layer, in meters; h2 is the height difference between the upper horizontal well and the lower horizontal well, in meters; and H is the thickness of the oil layer, in meters.

[0108] In one embodiment of the present invention, the horizontal distance determination module 1103 is specifically used for:

[0109] Based on the oil layer thickness and formation pressure, the horizontal distance between adjacent upper horizontal wells and adjacent lower horizontal wells is adjusted using numerical simulation to determine the maximum oil production. Based on the maximum oil production, the horizontal distance between adjacent upper horizontal wells and adjacent lower horizontal wells is determined. The horizontal distance between adjacent upper horizontal wells is the same as the horizontal distance between adjacent lower horizontal wells.

[0110] In one embodiment of the present invention, the horizontal distance determination module 1103 is specifically used for:

[0111] The horizontal distance between adjacent upper horizontal wells and the horizontal distance between adjacent lower horizontal wells are determined using the following formulas:

[0112] WS = 5422.9e -0.044P H 0.79 ;

[0113] Where WS represents the horizontal distance between adjacent upper horizontal wells and the horizontal distance between adjacent lower horizontal wells; P represents formation pressure; and H represents oil layer thickness.

[0114] In one embodiment of the present invention, the production pressure differential determination module 1105 is specifically used for:

[0115] Based on the oil layer thickness, formation pressure, and the cold production location of each upper and lower horizontal well, numerical simulation is used to adjust the production pressure difference between the upper and lower horizontal wells to determine the maximum oil production; and based on the maximum oil production, the production pressure difference between the upper and lower horizontal wells is determined.

[0116] In one embodiment of the present invention, the production pressure differential determination module 1105 is specifically used for:

[0117] The production pressure difference between the upper and lower horizontal wells is determined using the following formula:

[0118]

[0119] Where, ΔP i a represents the production pressure differential of the i-th horizontal well; i b represents the first correlation coefficient indicating the production pressure differential of the i-th horizontal well; i The second correlation coefficient represents the production pressure differential of the i-th horizontal well; c i The third correlation coefficient represents the production pressure difference of the i-th horizontal well; when i is 1, it represents the calculation of the production pressure difference of the upper horizontal well, and when i is 2, it represents the calculation of the production pressure difference of the lower horizontal well; P represents the formation pressure; H represents the oil layer thickness.

[0120] Figure 12 This is a specific example diagram of the horizontal well coordinated cold extraction device in an embodiment of the present invention. For example... Figure 12 As shown, in one embodiment of the present invention, Figure 11 The horizontal well coordinated cold production device shown also includes:

[0121] The second parameter acquisition module 1201 is used to acquire formation-related parameters; wherein, formation-related parameters include: permeability, porosity, oil saturation, number of interlayers, vertical position of interlayers in the formation, and lateral position of interlayers in the formation, or any combination thereof;

[0122] The location parameter determination module 1202 is used to determine the location of the first inflow controller, the number of inflow controllers, and the distance between adjacent inflow controllers in the horizontal well based on formation-related parameters, formation pressure, horizontal well length, and the height difference between the horizontal well and the bottom of the oil layer; wherein, the horizontal well includes an upper horizontal well and a lower horizontal well.

[0123] In one embodiment of the present invention, the inflow controller includes:

[0124] 1. Outer shell; 2. Inlet; 3. First guide cavity; 4. First guide hole; 5. Second guide cavity; 6. Second guide hole; 7. First base; 8. Second base; 9. Baffle; 10. First connecting rod; 11. First rotating shaft; 12. Second connecting rod; 13. Fixed shaft; 14. Second rotating shaft; 15. Third connecting rod; 16. Conducting plate; 17. Follower float; 18. Iron sheet; 19. Conducting cavity; 20. Density floating cavity; 21. Float; 22. Magnet; 23. Third guide hole; 24. Weak spring; 25. Outlet guide cavity; 26. Outlet.

[0125] In this structure, inlet 2 and outlet 26 are respectively located on both sides of the outer casing 1. Inlet 2 communicates with the first guide cavity 3. The first guide cavity 3 communicates with the second guide cavity 5 through the first guide hole 4. The first guide cavity 3 communicates with the density floating cavity 20 through the third guide hole 23. Magnet 22 is embedded in float 21, which floats within the density floating cavity 20. Conducting cavity 19 is a sealed cavity adjacent to the density floating cavity 20. Iron sheet 18 is embedded in follower float 17, which moves within the conducting cavity 19 along with float 21. Conducting plate 16 is located below follower float 17 and is connected to the first end of third connecting rod 15. The second end of third connecting rod 15 is connected to the first end of second connecting rod 12 via second rotating shaft 14. Fixed shaft 13 is also present. The second connecting rod 12 is located on the inner shell separating the conduction cavity 19 and the second guide cavity 5. It passes through the inner shell separating the conduction cavity 19 and the second guide cavity 5 via the fixed shaft 13 to change the transmission direction. The second end of the second connecting rod 12 is connected to the first end of the first connecting rod 10 via the first rotating shaft 11. The second end of the first connecting rod 10 is connected to the baffle 9. The first end of the weak spring 24 is fixed on the inner shell of the second guide cavity 5. The second end of the weak spring 24 is connected to the baffle 9. The first base 7 and the second base 8 are located between the second guide cavity 5 and the outlet guide cavity 25. The second guide hole 6 is located between the first base 7 and the second base 8. The second guide cavity 5 communicates with the outlet guide cavity 25 through the second guide hole 6. The outlet guide cavity 25 communicates with the outlet 26.

[0126] In one embodiment of the present invention, the position parameter determination module 1201 is specifically used for:

[0127] The system receives preset parameters such as the location, number, and distance between adjacent inflow controllers of multiple sets of first inflow controllers; based on formation parameters, formation pressure, horizontal well length, and height difference between the horizontal well and the bottom of the oil layer, it uses numerical simulation to sequentially read the location, number, and distance between adjacent inflow controllers of each set of first inflow controllers to determine the maximum oil production; based on the maximum oil production, it determines the location, number, and distance between adjacent inflow controllers of the first inflow controllers to be set in the horizontal well.

[0128] In one embodiment of the present invention, the position parameter determination module 1202 is specifically used for:

[0129] The location parameter determination model is obtained by inputting formation-related parameters, formation pressure, horizontal well length, and height difference between the horizontal well and the bottom of the oil layer into the location parameter determination model, and outputting the location of the first inflow controller in the horizontal well, the number of inflow controllers, and the distance between adjacent inflow controllers. The location parameter determination model is obtained by training a machine learning model based on historical formation-related parameters, historical formation pressure, historical horizontal well length, historical height difference between the horizontal well and the bottom of the oil layer, and the corresponding historical location of the first inflow controller in the horizontal well, the historical number of inflow controllers, and the historical distance between adjacent inflow controllers.

[0130] It should be noted that although several modules of the horizontal well coordinated cold production device have been mentioned in the detailed description above, this division is merely exemplary and not mandatory. In fact, according to embodiments of the present invention, the features and functions of two or more modules described above can be embodied in one module. Conversely, the features and functions of one module described above can be further divided and embodied by multiple modules.

[0131] Based on the aforementioned inventive concept, such as Figure 13 As shown, the present invention also proposes a computer device 1300, including a memory 1301, a processor 1302, and a computer program 1303 stored in the memory 1301 and executable on the processor 1302. When the processor 1302 executes the computer program 1303, it implements the aforementioned horizontal well collaborative cold extraction method.

[0132] Based on the aforementioned inventive concept, this invention proposes a computer-readable storage medium storing a computer program that, when executed by a processor, implements the aforementioned horizontal well coordinated cold extraction method.

[0133] Based on the aforementioned inventive concept, the present invention proposes a computer program product, which includes a computer program that, when executed by a processor, implements a horizontal well collaborative cold extraction method.

[0134] The horizontal well coordinated cold production method and apparatus proposed in this invention can solve the problems of uneven utilization of intra-layer reserves in existing technologies, and the easy occurrence of degassing and low oil production efficiency in horizontal wells. This invention obtains the oil layer thickness and formation pressure; based on the oil layer thickness and formation pressure, it determines the height difference between the lower horizontal well and the bottom of the oil layer, and the height difference between the upper horizontal well and the lower horizontal well; wherein each lower horizontal well is located on a first horizontal plane, and each upper horizontal well is located on a second horizontal plane; based on the oil layer thickness and formation pressure, it determines the horizontal distance between adjacent upper horizontal wells and the horizontal distance between adjacent lower horizontal wells; based on the lower horizontal well and the oil layer... The cold production location of each upper and lower horizontal well is determined by considering the height difference at the bottom of the formation, the height difference between upper and lower horizontal wells, the horizontal distance between adjacent upper and lower horizontal wells, and the horizontal distance between adjacent lower horizontal wells. Based on the oil layer thickness, formation pressure, and the cold production location of each upper and lower horizontal well, the production pressure difference between the upper and lower horizontal wells is determined. The production pressure difference is the same for all upper and lower horizontal wells. After determining the production pressure difference, a message command is issued to coordinate cold production of the oil layer using each upper and lower horizontal well. This embodiment of the invention can determine the cold production location of each upper and lower horizontal well, achieving full exploitation of the oil layer, improving oil production efficiency, and setting separate production pressure differences for upper and lower horizontal wells to prevent degassing of the horizontal wells.

[0135] Those skilled in the art will understand that embodiments of the present invention can be provided as methods, systems, or computer program products. Therefore, the present invention can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, the present invention can take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0136] This invention is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of the invention. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, generate instructions for implementing the flowchart illustrations and / or block diagrams. Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0137] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0138] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.

[0139] The specific embodiments described above further illustrate the purpose, technical solution, and beneficial effects of the present invention. It should be understood that the above descriptions are merely specific embodiments of the present invention and are not intended to limit the scope of protection of the present invention. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of the present invention should be included within the scope of protection of the present invention.

Claims

1. A method for coordinated cold extraction of horizontal wells, characterized in that, include: To obtain the oil layer thickness and formation pressure; Based on the oil layer thickness and formation pressure, determine the height difference between the lower horizontal well and the bottom of the oil layer, and the height difference between the upper horizontal well and the lower horizontal well; wherein, each lower horizontal well is located on the first horizontal plane, and each upper horizontal well is located on the second horizontal plane; Based on the oil layer thickness and formation pressure, determine the horizontal distance between adjacent upper horizontal wells and the horizontal distance between adjacent lower horizontal wells; Based on the height difference between the lower horizontal well and the bottom of the oil layer, the height difference between the upper horizontal well and the lower horizontal well, the horizontal distance between adjacent upper horizontal wells, and the horizontal distance between adjacent lower horizontal wells, the cold production location of each upper horizontal well and each lower horizontal well is determined. Based on the oil layer thickness, formation pressure, and the cold production location of each upper and lower horizontal well, the production pressure difference between the upper and lower horizontal wells is determined; wherein, the production pressure difference of each upper horizontal well is the same, and the production pressure difference of each lower horizontal well is the same. After determining the production pressure difference between the upper and lower horizontal wells, a message command is issued to coordinate cold production of the oil layer using each upper and lower horizontal well.

2. The method according to claim 1, characterized in that, Based on the oil layer thickness and formation pressure, determine the height difference between the lower horizontal well and the bottom of the oil layer, and the height difference between the upper horizontal well and the lower horizontal well, including: Based on the oil layer thickness and formation pressure, numerical simulation is used to adjust the height difference between the lower horizontal well and the bottom of the oil layer, and the height difference between the upper horizontal well and the lower horizontal well, to determine the maximum oil production. Based on the maximum oil production, determine the height difference between the lower horizontal well and the bottom of the oil layer, and the height difference between the upper horizontal well and the lower horizontal well.

3. The method according to claim 2, characterized in that, The height difference between the lower horizontal well and the bottom of the oil layer, and the height difference between the upper horizontal well and the lower horizontal well are determined using the following formulas: ； ； in, This represents the height difference between the lower horizontal well and the bottom of the oil layer, in meters. H represents the height difference between the upper and lower horizontal wells, in meters; H represents the oil layer thickness, in meters.

4. The method according to claim 1, characterized in that, Based on the oil layer thickness and formation pressure, determine the horizontal distance between adjacent upper horizontal wells and the horizontal distance between adjacent lower horizontal wells, including: Based on the oil layer thickness and formation pressure, the horizontal distance between adjacent upper horizontal wells and adjacent lower horizontal wells is adjusted using numerical simulation to determine the maximum oil production. Based on the maximum oil production, determine the horizontal distance between adjacent upper horizontal wells and the horizontal distance between adjacent lower horizontal wells; wherein the horizontal distance between adjacent upper horizontal wells is the same as the horizontal distance between adjacent lower horizontal wells.

5. The method according to claim 4, characterized in that, The horizontal distance between adjacent upper horizontal wells and the horizontal distance between adjacent lower horizontal wells are determined using the following formulas: ； Wherein, WS represents the horizontal distance between adjacent upper horizontal wells and the horizontal distance between adjacent lower horizontal wells; P Indicates formation pressure; H Indicates the thickness of the oil layer.

6. The method according to claim 1, characterized in that, Based on the reservoir thickness, formation pressure, and the cold production location of each upper and lower horizontal well, the production pressure differential between the upper and lower horizontal wells is determined, including: Based on the oil layer thickness, formation pressure, and the cold production location of each upper and lower horizontal well, the production pressure difference between the upper and lower horizontal wells is adjusted using numerical simulation to determine the maximum oil production. The production pressure difference between the upper and lower horizontal wells is determined based on the maximum oil production.

7. The method according to claim 6, characterized in that, The production pressure difference between the upper and lower horizontal wells is determined using the following formula: in, Indicates the first i Production pressure differential of horizontal wells; Indicates the first i The first correlation coefficient of the production pressure differential of a horizontal well; Indicates the first i The second correlation coefficient of the production pressure differential of a horizontal well; Indicates the first i The third correlation coefficient of the production pressure differential of a horizontal well; i A value of 1 indicates that the production pressure differential of the upper horizontal well is calculated. i A value of 2 indicates the calculation of the production pressure differential of the lower horizontal well; P Indicates formation pressure; H Indicates the thickness of the oil layer.

8. The method according to claim 1, characterized in that, Also includes: Obtain formation-related parameters; among which, formation-related parameters include: permeability, porosity, oil saturation, number of interlayers, vertical position of interlayers in the formation, and lateral position of interlayers in the formation, or any combination thereof; Based on formation parameters, formation pressure, horizontal well length, and height difference between the horizontal well and the bottom of the oil layer, determine the location of the first inflow controller, the number of inflow controllers, and the distance between adjacent inflow controllers within the horizontal well; wherein, the horizontal well includes upper horizontal wells and lower horizontal wells.

9. The method according to claim 8, characterized in that, The inflow controller includes: Outer shell (1), inlet (2), first guide cavity (3), first guide hole (4), second guide cavity (5), second guide hole (6), first base (7), second base (8), baffle (9), first connecting rod (10), first rotating shaft (11), second connecting rod (12), fixed shaft (13), second rotating shaft (14), third connecting rod (15), conduction plate (16), follower float (17), iron sheet (18), conduction cavity (19), density floating cavity (20), float (21), magnet (22), third guide hole (23), weak spring (24), outlet guide cavity (25), outlet (26); The inlet (2) and outlet (26) are respectively located on both sides of the outer shell (1). The inlet (2) is connected to the first guide cavity (3). The first guide cavity (3) is connected to the second guide cavity (5) through the first guide hole (4). The first guide cavity (3) is connected to the density floating cavity (20) through the third guide hole (23). The magnet (22) is embedded in the float (21). The float (21) floats in the density floating cavity (20). The conduction cavity (19) is a sealed cavity. The body, the conduction cavity (19) is adjacent to the density floating cavity (20), the iron plate (18) is embedded in the follower float (17), the follower float (17) moves in the conduction cavity (19) with the float (21), the conduction plate (16) is set below the follower float (17), the conduction plate (16) is connected to the first end of the third link (15), the second end of the third link (15) is connected to the first end of the second link (12) through the second rotating shaft (14), the fixed shaft ( 13) The second connecting rod (12) is set on the inner shell separating the conduction cavity (19) and the second guide cavity (5). The second connecting rod (12) passes through the inner shell separating the conduction cavity (19) and the second guide cavity (5) through the fixed shaft (13) to change the transmission direction. The second end of the second connecting rod (12) is connected to the first end of the first connecting rod (10) through the first rotating shaft (11). The second end of the first connecting rod (10) is connected to the baffle (9). The first end of the weak spring (24) is fixed on the inner shell of the second guide cavity (5). The second end of the weak spring (24) is connected to the baffle (9). The first base (7) and the second base (8) are set between the second guide cavity (5) and the outlet guide cavity (25). The second guide hole (6) is set between the first base (7) and the second base (8). The second guide cavity (5) is connected to the outlet guide cavity (25) through the second guide hole (6). The outlet guide cavity (25) is connected to the outlet (26).

10. The method according to claim 8, characterized in that, Based on formation parameters, formation pressure, horizontal well length, and the height difference between the horizontal well and the bottom of the oil reservoir, determine the location of the first inflow controller within the horizontal well, the number of inflow controllers, and the distance between adjacent inflow controllers, including: Receive preset parameters such as the position of multiple sets of first inflow controllers, the number of inflow controllers, and the distance between adjacent inflow controllers; Based on formation parameters, formation pressure, horizontal well length, and height difference between the horizontal well and the bottom of the oil layer, numerical simulation is used to sequentially read the position of the first inflow controller, the number of inflow controllers, and the distance between adjacent inflow controllers in each group to determine the maximum oil production. Based on the maximum oil production, determine the location of the first inflow controller, the number of inflow controllers, and the distance between adjacent inflow controllers within the horizontal well.

11. The method according to claim 8, characterized in that, Based on formation parameters, formation pressure, horizontal well length, and the height difference between the horizontal well and the bottom of the oil reservoir, determine the location of the first inflow controller within the horizontal well, the number of inflow controllers, and the distance between adjacent inflow controllers, including: The location parameter determination model is obtained by inputting formation-related parameters, formation pressure, horizontal well length, and height difference between the horizontal well and the bottom of the oil layer into the location parameter determination model, and outputting the location of the first inflow controller in the horizontal well, the number of inflow controllers, and the distance between adjacent inflow controllers. The location parameter determination model is obtained by training a machine learning model based on historical formation-related parameters, historical formation pressure, historical horizontal well length, historical height difference between the horizontal well and the bottom of the oil layer, and the corresponding historical location of the first inflow controller in the horizontal well, the historical number of inflow controllers, and the historical distance between adjacent inflow controllers.

12. A horizontal well coordinated cold extraction device, characterized in that, include: The first parameter acquisition module is used to obtain the oil layer thickness and formation pressure. The height difference determination module is used to determine the height difference between the lower horizontal well and the bottom of the oil layer, and the height difference between the upper horizontal well and the lower horizontal well, based on the oil layer thickness and formation pressure; wherein each lower horizontal well is located on a first horizontal plane, and each upper horizontal well is located on a second horizontal plane; The horizontal distance determination module is used to determine the horizontal distance between adjacent upper horizontal wells and adjacent lower horizontal wells based on the oil layer thickness and formation pressure. The cold production location determination module is used to determine the cold production location of each upper horizontal well and each lower horizontal well based on the height difference between the lower horizontal well and the bottom of the oil layer, the height difference between the upper horizontal well and the lower horizontal well, the horizontal distance between adjacent upper horizontal wells, and the horizontal distance between adjacent lower horizontal wells. The production pressure differential determination module is used to determine the production pressure differential between upper and lower horizontal wells based on the oil layer thickness, formation pressure, and the cold production location of each upper and lower horizontal well; wherein, the production pressure differential of each upper horizontal well is the same, and the production pressure differential of each lower horizontal well is the same. The collaborative cold production control module is used to issue a message command to conduct collaborative cold production of the oil layer using each upper horizontal well and each lower horizontal well after determining the production pressure difference between the upper and lower horizontal wells.

13. The apparatus according to claim 12, characterized in that, The height difference determination module is specifically used for: Based on the oil layer thickness and formation pressure, numerical simulation is used to adjust the height difference between the lower horizontal well and the bottom of the oil layer, and the height difference between the upper horizontal well and the lower horizontal well, to determine the maximum oil production. Based on the maximum oil production, determine the height difference between the lower horizontal well and the bottom of the oil layer, and the height difference between the upper horizontal well and the lower horizontal well.

14. The apparatus according to claim 13, characterized in that, The height difference determination module is specifically used for: The height difference between the lower horizontal well and the bottom of the oil layer, and the height difference between the upper horizontal well and the lower horizontal well are determined using the following formulas: ； ； in, This represents the height difference between the lower horizontal well and the bottom of the oil layer, in meters. H represents the height difference between the upper and lower horizontal wells, in meters; H represents the oil layer thickness, in meters.

15. The apparatus according to claim 12, characterized in that, The horizontal distance determination module is specifically used for: Based on the oil layer thickness and formation pressure, the horizontal distance between adjacent upper horizontal wells and adjacent lower horizontal wells is adjusted using numerical simulation to determine the maximum oil production. Based on the maximum oil production, determine the horizontal distance between adjacent upper horizontal wells and the horizontal distance between adjacent lower horizontal wells; wherein the horizontal distance between adjacent upper horizontal wells is the same as the horizontal distance between adjacent lower horizontal wells.

16. The apparatus according to claim 15, characterized in that, The horizontal distance determination module is specifically used for: The horizontal distance between adjacent upper horizontal wells and the horizontal distance between adjacent lower horizontal wells are determined using the following formulas: ； Wherein, WS represents the horizontal distance between adjacent upper horizontal wells and the horizontal distance between adjacent lower horizontal wells; P Indicates formation pressure; H Indicates the thickness of the oil layer.

17. The apparatus according to claim 12, characterized in that, The production pressure differential determination module is specifically used for: Based on the oil layer thickness, formation pressure, and the cold production location of each upper and lower horizontal well, the production pressure difference between the upper and lower horizontal wells is adjusted using numerical simulation to determine the maximum oil production. The production pressure difference between the upper and lower horizontal wells is determined based on the maximum oil production.

18. The apparatus according to claim 17, characterized in that, The production pressure differential determination module is specifically used for: The production pressure difference between the upper and lower horizontal wells is determined using the following formula: in, Indicates the first i Production pressure differential of horizontal wells; Indicates the first i The first correlation coefficient of the production pressure differential of a horizontal well; Indicates the first i The second correlation coefficient of the production pressure differential of a horizontal well; Indicates the first i The third correlation coefficient of the production pressure differential of a horizontal well; i A value of 1 indicates that the production pressure differential of the upper horizontal well is calculated. i A value of 2 indicates the calculation of the production pressure differential of the lower horizontal well; P Indicates formation pressure; H Indicates the thickness of the oil layer.

19. The apparatus according to claim 12, characterized in that, Also includes: The second parameter acquisition module is used to acquire formation-related parameters, including: permeability, porosity, oil saturation, number of interlayers, vertical position of interlayers in the formation, and lateral position of interlayers in the formation, or any combination thereof. The location parameter determination module is used to determine the location of the first inflow controller, the number of inflow controllers, and the distance between adjacent inflow controllers in the horizontal well based on formation-related parameters, formation pressure, horizontal well length, and the height difference between the horizontal well and the bottom of the oil layer; wherein, the horizontal well includes upper horizontal wells and lower horizontal wells.

20. The apparatus according to claim 19, characterized in that, The inflow controller includes: Outer shell (1), inlet (2), first guide cavity (3), first guide hole (4), second guide cavity (5), second guide hole (6), first base (7), second base (8), baffle (9), first connecting rod (10), first rotating shaft (11), second connecting rod (12), fixed shaft (13), second rotating shaft (14), third connecting rod (15), conduction plate (16), follower float (17), iron sheet (18), conduction cavity (19), density floating cavity (20), float (21), magnet (22), third guide hole (23), weak spring (24), outlet guide cavity (25), outlet (26); The inlet (2) and outlet (26) are respectively located on both sides of the outer shell (1). The inlet (2) is connected to the first guide cavity (3). The first guide cavity (3) is connected to the second guide cavity (5) through the first guide hole (4). The first guide cavity (3) is connected to the density floating cavity (20) through the third guide hole (23). The magnet (22) is embedded in the float (21). The float (21) floats in the density floating cavity (20). The conduction cavity (19) is a sealed cavity. The body, the conduction cavity (19) is adjacent to the density floating cavity (20), the iron plate (18) is embedded in the follower float (17), the follower float (17) moves in the conduction cavity (19) with the float (21), the conduction plate (16) is set below the follower float (17), the conduction plate (16) is connected to the first end of the third link (15), the second end of the third link (15) is connected to the first end of the second link (12) through the second rotating shaft (14), the fixed shaft ( 13) The second connecting rod (12) is set on the inner shell separating the conduction cavity (19) and the second guide cavity (5). The second connecting rod (12) passes through the inner shell separating the conduction cavity (19) and the second guide cavity (5) through the fixed shaft (13) to change the transmission direction. The second end of the second connecting rod (12) is connected to the first end of the first connecting rod (10) through the first rotating shaft (11). The second end of the first connecting rod (10) is connected to the baffle (9). The first end of the weak spring (24) is fixed on the inner shell of the second guide cavity (5). The second end of the weak spring (24) is connected to the baffle (9). The first base (7) and the second base (8) are set between the second guide cavity (5) and the outlet guide cavity (25). The second guide hole (6) is set between the first base (7) and the second base (8). The second guide cavity (5) is connected to the outlet guide cavity (25) through the second guide hole (6). The outlet guide cavity (25) is connected to the outlet (26).

21. The apparatus according to claim 19, characterized in that, The position parameter determination module is specifically used for: Receive preset parameters such as the position of multiple sets of first inflow controllers, the number of inflow controllers, and the distance between adjacent inflow controllers; Based on formation parameters, formation pressure, horizontal well length, and height difference between the horizontal well and the bottom of the oil layer, numerical simulation is used to sequentially read the position of the first inflow controller, the number of inflow controllers, and the distance between adjacent inflow controllers in each group to determine the maximum oil production. Based on the maximum oil production, determine the location of the first inflow controller, the number of inflow controllers, and the distance between adjacent inflow controllers within the horizontal well.

22. The apparatus according to claim 19, characterized in that, The position parameter determination module is specifically used for: The location parameter determination model is obtained by inputting formation-related parameters, formation pressure, horizontal well length, and height difference between the horizontal well and the bottom of the oil layer into the location parameter determination model, and outputting the location of the first inflow controller in the horizontal well, the number of inflow controllers, and the distance between adjacent inflow controllers. The location parameter determination model is obtained by training a machine learning model based on historical formation-related parameters, historical formation pressure, historical horizontal well length, historical height difference between the horizontal well and the bottom of the oil layer, and the corresponding historical location of the first inflow controller in the horizontal well, the historical number of inflow controllers, and the historical distance between adjacent inflow controllers.

23. A computer device, comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that, When the processor executes the computer program, it implements the method of any one of claims 1 to 11.

24. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores a computer program that, when executed by a processor, implements the method of any one of claims 1 to 11.

25. A computer program product, characterized in that, The computer program product includes a computer program that, when executed by a processor, implements the method of any one of claims 1 to 11.

Images