Well pattern structure and well pattern deployment method

Abstract

The present invention discloses a well pattern structure and a well pattern deployment method, which include at least four production wells and one injection well. Among them, the production well includes a tubing string and a heat insulation pipe sleeved outside the tubing string. The surface of the tubing string is provided with hydrocarbon reservoir perforations, and after passing through the heat insulation pipe, the hydrocarbon reservoir perforations are communicated with the outside. The surface of the heat insulation pipe is provided with hydrate reservoir perforations, and the hydrate reservoir perforations are communicated with the outside. The hydrate reservoir perforations are located above the hydrocarbon reservoir perforations. An annular packer is arranged between the tubing string and the heat insulation pipe, and the packer is located between the hydrocarbon reservoir perforations and the hydrate reservoir perforations. By calculating the economic benefits of the combined exploitation of the production wells and the injection well, the economic benefits of the individual exploitation of the production wells, and the economic benefits of the individual exploitation of the injection well, and determining the operation conditions of the production wells and the injection well. The beneficial effect of the present invention is that the hydrate reservoir and the deep hydrocarbon reservoir can share the production wells and the injection well, saving costs such as drilling and completion costs.

Description

Technical Field

[0001] The present invention relates to the technical field of oil and gas exploitation, and particularly to a well pattern structure and a well pattern deployment method. Background Art

[0002] Hydrate is an unconventional and clean natural gas resource with a wide distribution area and a large resource volume, having great development value. At the same time, there is a close spatio-temporal relationship between the accumulation of natural gas hydrates and conventional oil and gas resources, and they can co-accumulate under certain conditions. Aiming at the physical and chemical properties of natural gas hydrates and the geological conditions where they are located, it is very difficult to carry out large-scale commercial exploitation with the existing exploitation methods.

[0003] Regarding the problem of the co-accumulation of natural gas hydrates and conventional oil and gas resources, CN112392445A discloses a combined exploitation system and method for hydrate reservoirs and conventional oil and gas reservoirs, which designs a set of systems for the combined exploitation of hydrate reservoirs and conventional oil and gas reservoirs. However, the above system only considers the exploitation problem and does not consider whether the exploitation behavior can obtain economic benefits. Since the separate exploitation of hydrate reservoirs or deep oil and gas reservoirs may not have economic benefits, the existing technology lacks supporting devices and well pattern deployment methods. Summary of the Invention

[0004] In view of the above problems, the present invention proposes a well pattern structure and a well pattern deployment method. Based on a special well pattern structure, a corresponding pre-decision plan is introduced, mainly to solve the problem that the separate exploitation of hydrate reservoirs or deep oil and gas reservoirs may not have economic benefits.

[0005] To solve the above technical problems, the first aspect of the present invention proposes a well pattern structure, which includes at least four production wells and one injection well. Among them, the production well includes a tubing string, and a heat insulation pipe sleeved outside the tubing string. The surface of the tubing string is provided with oil and gas reservoir perforations, and the oil and gas reservoir perforations communicate with the outside after passing through the heat insulation pipe. The surface of the heat insulation pipe is provided with hydrate reservoir perforations, and the hydrate reservoir perforations communicate with the outside. The hydrate reservoir perforations are located above the oil and gas reservoir perforations. A ring-shaped packer is arranged between the tubing string and the heat insulation pipe, and the packer is located between the oil and gas reservoir perforations and the hydrate reservoir perforations.

[0006] In some embodiments, a first pressure control switch is further arranged at the opening end of the hydrate reservoir perforations.

[0007] In some embodiments, a second pressure control switch is further arranged at the opening end of the oil and gas reservoir perforations.

[0008] In some embodiments, the injection well communicates with the oil and gas reservoir perforations and the hydrate reservoir perforations.

[0009] A second aspect of the present invention proposes a well pattern deployment method for the above-mentioned well pattern structure, including the following steps: calculating the economic benefits of the combined exploitation of the oil and gas reservoir and the hydrate reservoir, the economic benefits of the separate exploitation of the oil and gas reservoir, and the economic benefits of the separate exploitation of the hydrate reservoir, and determining the operation conditions of the production wells and the injection wells.

[0010] In some embodiments, the operation conditions of the production wells are determined according to the following steps: defining the economic benefits W, W1, W 11 , W2 and W 21 ;

[0011] W = a1*(m 1- n1)+a2*(m 2- n2)-(S1+S2+S3+S4) (1);

[0012] W1 = a1*(m 1- n1)-(S1+S3) (2);

[0013] W 11 = a1*(m 1- n1)-S3 (3);

[0014] W2 = a2*(m 2- n2)-(S1+S2+S4) (4);

[0015] W 21 = a2*(m 2- n2)-(S2+S4) (5);

[0016] In the formula, a1 is the recoverable reserve of a production well in the hydrate reservoir, a2 is the recoverable reserve of a production well in the deep oil reservoir, m1 is the natural gas price, m2 is the crude oil price, n1 is the production and storage and transportation cost of natural gas, n2 is the production and storage and transportation cost of crude oil, S1 is the drilling cost from the mud line to the hydrate reservoir, S2 is the drilling cost from the depth of the hydrate reservoir to the deep oil reservoir, S3 is the completion cost of the hydrate reservoir, and S4 is the completion cost of the deep gas reservoir;

[0017] When W>0, W1>0 and W 21 >0, drill and complete the well for the hydrate reservoir and the deep oil reservoir corresponding to the current production well;

[0018] When W>0, W1>0 and W 21 <0, drill and complete the well for the hydrate reservoir corresponding to the current production well;

[0019] When W>0, W1<0, W2>0 and W 11 >0, drill and complete the well for the hydrate reservoir and the deep oil reservoir corresponding to the current production well;

[0020] When W > 0, W1 < 0, W2 > 0 and W 11 < 0, drill and complete the well for the deep reservoir corresponding to the current production well;

[0021] When W > 0, W1 < 0, W2 < 0, drill and complete the well for the hydrate reservoir and the deep reservoir corresponding to the current production well;

[0022] When W < 0 and W1 > 0, drill and complete the well for the hydrate reservoir corresponding to the current production well;

[0023] When W < 0, W1 < 0, W2 > 0, drill and complete the well for the deep reservoir corresponding to the current production well;

[0024] When W < 0, W1 < 0, W2 < 0, no drill and complete well operation is carried out for the current production well.

[0025] In some embodiments, the operation condition of the injection well is determined according to the following steps: Define the economic benefits V, V1, V 11 , V2 and V 21 ;

[0026] V = b1*(m 1- n1)+b2*(m 2- n2)-(S1 + S2 + S3 + S4 + c1*q + c2*q) (6);

[0027] V1 = b1*(m 1- n1)-(S1 + S3 + c1*q) (7);

[0028] V 11 = b1*(m 1- n1)-(S3 + c1*q) (8);

[0029] V2 = b2*(m 2- n2)-(S1 + S2 + S4 + c2*q) (9);

[0030] V 21 = b2*(m 2- n2)-(S2 + S4 + c2*q) (10);

[0031] Wherein, b1 is the additional recoverable reserves of the hydrate reservoir when injecting c1 cubic meters of hot water with the addition of one injection well; b2 is the additional recoverable reserves of the deep gas reservoir when injecting c2 cubic meters of hot water with the addition of one injection well; c1 is the volume of hot water that one injection well needs to inject into the hydrate reservoir; c2 is the volume of hot water that one injection well needs to inject into the deep oil reservoir; m1 is the natural gas price, m2 is the crude oil price, n1 is the production, storage, and transportation cost of natural gas, n2 is the production, storage, and transportation cost of crude oil, S1 is the drilling cost from the mud line to the hydrate reservoir, S2 is the drilling cost from the depth of the hydrate reservoir to the deep oil reservoir, S3 is the completion cost of the hydrate reservoir, and S4 is the completion cost of the deep gas reservoir;

[0032] When V > 0, V1 > 0 and V 21 > 0, drill and complete the well for the hydrate reservoir and the deep oil reservoir corresponding to the current injection well;

[0033] When V > 0, V1 > 0 and V 21 < 0, drill and complete the well for the hydrate reservoir corresponding to the current injection well;

[0034] When V > 0, V1 < 0, V2 > 0 and V 11 > 0, drill and complete the well for the hydrate reservoir and the deep oil reservoir corresponding to the current injection well;

[0035] When V > 0, V1 < 0, V2 > 0 and V 11 < 0, drill and complete the well for the deep oil reservoir corresponding to the current injection well;

[0036] When V > 0, V1 < 0, V2 < 0, drill and complete the well for the hydrate reservoir and the deep oil reservoir corresponding to the current injection well;

[0037] When V < 0 and V1 > 0, drill and complete the well for the hydrate reservoir corresponding to the current injection well;

[0038] When V < 0, V1 < 0, V2 > 0, drill and complete the well for the deep oil reservoir corresponding to the current injection well;

[0039] When V < 0, V1 < 0, V2 < 0, no drilling and completion operations are performed on the current injection well.

[0040] The beneficial effects of the present invention are as follows: The hydrate reservoir and the deep oil and gas reservoir can share facilities such as production wells and injection wells, saving costs such as drilling and completion, reducing costs and improving efficiency. Moreover, by analyzing the economic effects of separate or combined exploitation of the oil and gas reservoir and the hydrate reservoir, an optimal operation plan can be obtained. BRIEF DESCRIPTION OF THE DRAWINGS

[0041] Figure 1 It is a schematic structural diagram of the well pattern structure disclosed in Embodiment 1 of the present invention;

[0042] Figure 2 The structural schematic diagram of the production well disclosed in the first embodiment of the present invention;

[0043] Figure 3 The schematic diagram of the production well operation decision-making disclosed in the second embodiment of the present invention;

[0044] Figure 4 The schematic diagram of the injection well operation decision-making disclosed in the second embodiment of the present invention. Detailed implementation manners

[0045] To make the objectives, technical solutions and advantages of the present invention clearer and more definite, the content of the present invention will be further described in detail below with reference to the accompanying drawings and specific implementation manners. It can be understood that the specific embodiments described herein are only used to explain the present invention, rather than limiting the present invention. In addition, it should be noted that for the convenience of description, only the parts related to the present invention are shown in the drawings rather than all the content.

[0046] Embodiment 1

[0047] As Figure 1 、 2 shown, this embodiment proposes a well pattern structure, including at least four production wells 1 and one injection well 9. Among them, the production well 1 includes a tubing 6 and a heat insulation pipe 7 sleeved outside the tubing 6. The surface of the tubing 6 is provided with hydrocarbon reservoir perforations 3, and the hydrocarbon reservoir perforations 3 penetrate through the heat insulation pipe 7 and communicate with the outside. The surface of the heat insulation pipe 7 is provided with hydrate reservoir perforations 2, and the hydrate reservoir perforations 2 communicate with the outside. The hydrate reservoir perforations 2 are located above the hydrocarbon reservoir perforations 3. An annular packer 8 is arranged between the tubing 6 and the heat insulation pipe 7, and the packer 8 is located between the hydrocarbon reservoir perforations 3 and the hydrate reservoir perforations 2.

[0048] In this embodiment, a well pattern for combined exploitation is designed. By sharing facilities such as production wells, the drilling and completion costs can be significantly reduced, and finally the commercial exploitation of hydrate reservoirs and deep hydrocarbon reservoirs can be realized. At the same time, the well pattern deployment method disclosed in Embodiment 2 is only applicable to the well pattern structure described in this embodiment. For the specific scheme, see Embodiment 2.

[0049] Optionally, a first pressure control switch 4 is further arranged at the open end of the hydrate reservoir perforation 2.

[0050] Optionally, a second pressure control switch 5 is further arranged at the open end of the hydrocarbon reservoir perforation 3.

[0051] Optionally, the injection well 9 communicates with the hydrocarbon reservoir perforations 3 and the hydrate reservoir perforations 2.

[0052] The following describes the structures appearing in this embodiment:

[0053] Production well 1: A well capable of simultaneously exploiting a hydrate reservoir and a deep oil and gas reservoir.

[0054] Hydrate reservoir perforation 2: Establish a channel to facilitate the injection or production of fluids in the hydrate reservoir.

[0055] Deep oil and gas reservoir perforation 3: Establish a channel to facilitate the injection or production of fluids in the deep oil and gas reservoir.

[0056] First pressure control switch 4: Used to control the injection or outflow of fluids in the perforation section of the hydrate reservoir.

[0057] Second pressure control switch 5: Used to control the injection or outflow of fluids in the perforation section of the deep oil and gas reservoir.

[0058] Oil pipe 6: Establish a channel between the offshore platform and the deep oil and gas reservoir to facilitate the outflow and injection of fluids in the deep oil and gas reservoir.

[0059] External heat insulation pipe 7: The annulus between it and the oil pipe is the channel between the offshore platform and the hydrate reservoir, facilitating the outflow and injection of fluids in the hydrate reservoir.

[0060] Packer 8: Located between the oil pipe and the external heat insulation pipe to prevent fluid cross-flow between the hydrate reservoir and the deep oil and gas reservoir.

[0061] Injection well 9: A well capable of simultaneously injecting fluids such as hot water or chemical agents into the hydrate reservoir and the deep oil and gas reservoir.

[0062] Example 2

[0063] This example proposes a well pattern deployment method for the well pattern structure described in Example 1. By analyzing the economic effects of separate or combined exploitation of the oil and gas reservoir and the hydrate reservoir, an optimal operation plan is obtained.

[0064] This method includes the following steps: Calculate the economic benefits of combined exploitation of the oil and gas reservoir and the hydrate reservoir, the economic benefits of separate exploitation of the oil and gas reservoir, and the economic benefits of separate exploitation of the hydrate reservoir, and determine the operation conditions of the production well and the injection well.

[0065] Specifically, the operation conditions of the production well are determined according to the following steps: Define the economic benefits W, W1, W 11 , W2 and W 21 ;

[0066] W = a1 * (m 1- n1) + a2 * (m 2- n2) - (S1 + S2 + S3 + S4) (1);

[0067] W1 = a1 * (m 1- n1) - (S1 + S3) (2);

[0068] W 11 = a1 * (m 1- n1) - S3 (3);

[0069] W2 = a2 * (m 2- n2) - (S1 + S2 + S4) (4);

[0070] W 21 = a2 * (m 2- n2) - (S2 + S4) (5);

[0071] Wherein, a1 is the recoverable reserve of a production well in the hydrate reservoir (unit: cubic meters), a2 is the recoverable reserve of a production well in the deep oil reservoir (unit: tons), m1 is the natural gas price (unit: yuan per cubic meter), m2 is the crude oil price (unit: yuan per ton), n1 is the production and storage and transportation cost of natural gas (unit: yuan per cubic meter), n2 is the production and storage and transportation cost of crude oil (unit: yuan per ton), S1 is the drilling cost from the mud line to the hydrate reservoir (unit: yuan), S2 is the drilling cost from the depth of the hydrate reservoir to the deep oil reservoir (unit: yuan), S3 is the completion cost of the hydrate reservoir (unit: yuan), and S4 is the completion cost of the deep gas reservoir (unit: yuan);

[0072] As Figure 3 shown, when W > 0, W1 > 0 and W 21 > 0, at this time both the hydrate reservoir and the deep oil reservoir are drilled and completed, with the best economic benefits. Therefore, drill and completion operations are deployed for the hydrate reservoir and the deep oil reservoir corresponding to the current production well;

[0073] When W > 0, W1 > 0 and W 21 < 0, it indicates that only drilling and completing the hydrate reservoir has the best economic benefits. At this time, the income from exploiting the deep oil reservoir cannot cover its drilling and completion costs. Therefore, drill and completion operations are deployed for the hydrate reservoir corresponding to the current production well;

[0074] When W > 0, W1 < 0, W2 > 0 and W 11 > 0, it indicates that both the hydrate reservoir and the deep oil reservoir are drilled and completed, with the best economic benefits. Therefore, drill and completion operations are deployed for the hydrate reservoir and the deep oil reservoir corresponding to the current production well;

[0075] When W > 0, W1 < 0, W2 > 0 and W 11 < 0, it indicates that only drilling and completing the deep oil reservoir has the best economic benefits. At this time, the income from exploiting the hydrate reservoir cannot cover its completion costs. Therefore, drill and completion operations are deployed for the deep oil reservoir corresponding to the current production well;

[0076] When W > 0, W1 < 0, and W2 < 0, it indicates that the separate development of the hydrate reservoir and the deep oil reservoir is not economically viable, but the combined exploitation using common production facilities has economic value. Therefore, both the hydrate reservoir and the deep oil reservoir are drilled and completed, and thus well drilling and completion operations are deployed for the hydrate reservoir and the deep oil reservoir corresponding to the current production well.

[0077] When W < 0 and W1 > 0, it indicates that only drilling and completing the hydrate reservoir has the best economic benefit. At this time, the revenue from exploiting the deep oil reservoir cannot cover its well drilling and completion costs. Therefore, well drilling and completion operations are deployed for the hydrate reservoir corresponding to the current production well.

[0078] When W < 0, W1 < 0, and W2 > 0, it indicates that only drilling and completing the deep oil reservoir has the best economic benefit. At this time, the revenue from exploiting the hydrate reservoir cannot cover its well completion costs. Therefore, well drilling and completion operations are deployed for the deep oil reservoir corresponding to the current production well.

[0079] When W < 0, W1 < 0, and W2 < 0, it is assumed here that the production well has no economic benefit. Therefore, no well drilling and completion operations are carried out for the current production well.

[0080] Specifically, the operation conditions of the injection well are determined according to the following steps: Define the economic benefits of the injection well as V, V1, V 11 、V2 and V 21 ;

[0081] V = b1 * (m 1- n1) + b2 * (m 2- n2) - (S1 + S2 + S3 + S4 + c1 * q + c2 * q) (6);

[0082] V1 = b1 * (m 1- n1) - (S1 + S3 + c1 * q) (7);

[0083] V 11 = b1 * (m 1- n1) - (S3 + c1 * q) (8);

[0084] V2 = b2 * (m 2- n2) - (S1 + S2 + S4 + c2 * q) (9);

[0085] V 21 = b2 * (m 2- n2) - (S2 + S4 + c2 * q) (10);

[0086] In the formula, b1 is the additional recoverable reserve of the hydrate reservoir (unit: cubic meters) when injecting c1 cubic meters of hot water with the addition of one injection well; b2 is the additional recoverable reserve of the deep gas reservoir (unit: tons) when injecting c2 cubic meters of hot water with the addition of one injection well; c1 is the volume of hot water that one injection well needs to inject into the hydrate reservoir (unit: cubic meters); c2 is the volume of hot water that one injection well needs to inject into the deep oil reservoir (unit: cubic meters); m1 is the natural gas price (unit: yuan per cubic meter), m2 is the crude oil price (unit: yuan per ton), n1 is the production and storage and transportation cost of natural gas (unit: yuan per cubic meter), n2 is the production and storage and transportation cost of crude oil (unit: yuan per ton), S1 is the drilling cost from the mud line to the hydrate reservoir (unit: yuan), S2 is the drilling cost from the depth of the hydrate reservoir to the deep oil reservoir (unit: yuan), S3 is the completion cost of the hydrate reservoir (unit: yuan), and S4 is the completion cost of the deep gas reservoir (unit: yuan).

[0087] As Figure 4 shown, when V > 0, V1 > 0 and V 21 > 0, drill and complete the well for the hydrate reservoir and the deep oil reservoir corresponding to the current injection well;

[0088] When V > 0, V1 > 0 and V 21 < 0, drill and complete the well for the hydrate reservoir corresponding to the current injection well;

[0089] When V > 0, V1 < 0, V2 > 0 and V 11 > 0, drill and complete the well for the hydrate reservoir and the deep oil reservoir corresponding to the current injection well;

[0090] When V > 0, V1 < 0, V2 > 0 and V 11 < 0, drill and complete the well for the deep oil reservoir corresponding to the current injection well;

[0091] When V > 0, V1 < 0, V2 < 0, drill and complete the well for the hydrate reservoir and the deep oil reservoir corresponding to the current injection well;

[0092] When V < 0 and V1 > 0, drill and complete the well for the hydrate reservoir corresponding to the current injection well;

[0093] When V < 0, V1 < 0, V2 > 0, drill and complete the well for the deep oil reservoir corresponding to the current injection well;

[0094] When V < 0, V1 < 0, V2 < 0, no drill and complete well operation is performed for the current injection well.

[0095] For the drill and complete well operation strategy of the above injection wells, please refer to the drill and complete well operation strategy of the above production wells.

[0096] Illustrative example:

[0097] There is a co-generation reservoir system of a certain hydrate reservoir and a deep oil and gas reservoir in the South China Sea. In this system, the deep oil and gas reservoir is located directly below the hydrate reservoir, and a three-dimensional development mode of co-production from top to bottom can be adopted. Through the calculation of numerical simulation software, it is found that the recoverable reserves of Well A, a production well, in the hydrate reservoir are 1×10 9 cubic meters of natural gas; the recoverable reserves in the deep oil reservoir are 1×10 6 tons; the price of natural gas is 2.2 yuan per cubic meter; the price of crude oil is 4,000 yuan per ton; assuming that the production and storage and transportation costs of natural gas are 1.2 yuan per cubic meter; the production and storage and transportation costs of crude oil are 2,000 yuan per ton; the drilling cost from the mud line to the hydrate reservoir is 1×10 9 yuan; the drilling cost from the hydrate reservoir to the deep oil reservoir is 1×10 9 yuan; the completion cost of the hydrate reservoir is 2×10 7 yuan; the completion cost of the deep gas reservoir is 1×10 7 yuan;

[0098] Result analysis: The economic benefit of developing the hydrate reservoir alone is W1 = 1×10 9 -1×10 9 -2×10 7 < 0, without economic benefits;

[0099] The economic benefit of developing the deep oil and gas reservoir alone is W2 = 1×10 6 ×2000 - 1×10 9 -1×10 9 -1×10 7 < 0, also without economic benefits;

[0100] However, when co-producing, W = 1×10 9 +1×10 6 ×2000 - 1×10 9 -1×10 9 -1×10 7 -2×10 7 > 0, with economic benefits; Therefore, both the hydrate reservoir and the deep oil reservoir are drilled and completed.

[0101] The above embodiments are only for illustrating the technical concept and characteristics of the present invention, and the purpose is to enable ordinary technical personnel in the field to understand the content of the present invention and implement it accordingly, and it cannot be used to limit the protection scope of the present invention. Any equivalent changes or modifications made according to the essence of the content of the present invention should be covered within the protection scope of the present invention.

Claims

1. A well pattern deployment method for the following well pattern structure, the well pattern structure comprising at least four production wells and one injection well, wherein, The production well includes a tubing string, and a heat insulation pipe sleeved outside the tubing string. The surface of the tubing string is provided with hydrocarbon reservoir perforations, and the hydrocarbon reservoir perforations penetrate through the heat insulation pipe and communicate with the outside. There are hydrate reservoir perforations on the surface of the heat insulation pipe, and the hydrate reservoir perforations communicate with the outside. The hydrate reservoir perforations are located above the hydrocarbon reservoir perforations. An annular packer is arranged between the tubing string and the heat insulation pipe, and the packer is located between the hydrocarbon reservoir perforations and the hydrate reservoir perforations. It is characterized by the following steps: calculating the economic benefits of the combined exploitation of the hydrocarbon reservoir and the hydrate reservoir, the economic benefits of the separate exploitation of the hydrocarbon reservoir, and the economic benefits of the separate exploitation of the hydrate reservoir, and determining the operation conditions of the production well and the injection well; The operating conditions of the production well are determined according to the following steps: Define the economic benefits W, W1, W 11 , W2 and W 21 ; W = a1 * (m 1- n1) + a2 * (m 2- n2) - (S1 + S2 + S3 + S4) (1); W1 = a1 * (m 1- n1) - (S1 + S3) (2); W 11 = a1 * (m 1- n1) - S3 (3); W2 = a2 * (m 2- n2) - (S1 + S2 + S4) (4); W 21 = a2 * (m 2- n2) - (S2 + S4) (5); In the formula, a1 is the recoverable reserve of a production well in the hydrate reservoir, a2 is the recoverable reserve of a production well in the deep oil reservoir, m1 is the natural gas price, m2 is the crude oil price, n1 is the production and storage and transportation cost of natural gas, n2 is the production and storage and transportation cost of crude oil, S1 is the drilling cost from the mud line to the hydrate reservoir, S2 is the drilling cost from the depth of the hydrate reservoir to the deep oil reservoir, S3 is the completion cost of the hydrate reservoir, and S4 is the completion cost of the deep gas reservoir; When W > 0, W1 > 0 and W 21 > 0, drilling and completion operations are deployed for the hydrate reservoir and the deep oil reservoir corresponding to the current production well; When W > 0, W1 > 0 and W 21 < 0, deploy drilling and completion operations for the hydrate reservoir corresponding to the current production well; When W > 0, W1 < 0, W2 > 0 and W 11 > 0, deploy well drilling and completion operations for the hydrate reservoir and deep oil reservoir corresponding to the current production well; When W > 0, W1 < 0, W2 > 0 and W 11 < 0, deploy well drilling and completion operations for the deep reservoir corresponding to the current production well; When W>0, W1<0, and W2<0, drill and complete the well for the hydrate reservoir and the deep oil reservoir corresponding to the current production well; When W<0 and W1>0, drill and complete the well for the hydrate reservoir corresponding to the current production well; When W<0, W1<0, and W2>0, drill and complete the well for the deep oil reservoir corresponding to the current production well; When W<0, W1<0, and W2<0, no drill and complete well operation is carried out for the current production well.

2. The well pattern deployment method according to claim 1, wherein, The operating conditions of the injection well are determined according to the following steps: Define the economic benefits V, V1, V 11 , V2 and V 21 ; V = b1 * (m 1- n1) + b2 * (m 2- n2) - (S1 + S2 + S3 + S4 + c1 * q + c2 * q) (6); V1 = b1 * (m 1- n1) - (S1 + S3 + c1 * q) (7); V 11 = b1 * (m 1- n1) - (S3 + c1 * q) (8); V2 = b2 * (m 2- n2) - (S1 + S2 + S4 + c2 * q) (9); V 21 = b2 * (m 2- n2) - (S2 + S4 + c2 * q) (10); In the formula, b1 is the increased recoverable reserve of the hydrate reservoir when injecting c1 cubic meters of hot water with the addition of one injection well; b2 is the increased recoverable reserve of the deep gas reservoir when injecting c2 cubic meters of hot water with the addition of one injection well; c1 is the volume of hot water that one injection well needs to inject into the hydrate reservoir; c2 is the volume of hot water that one injection well needs to inject into the deep oil reservoir; m1 is the natural gas price, m2 is the crude oil price, n1 is the production and storage and transportation cost of natural gas, n2 is the production and storage and transportation cost of crude oil, S1 is the drilling cost from the mud line to the hydrate reservoir, S2 is the drilling cost from the depth of the hydrate reservoir to the deep oil reservoir, S3 is the completion cost of the hydrate reservoir, and S4 is the completion cost of the deep gas reservoir; When V > 0, V1 > 0 and V 21 > 0, drilling and completion operations are deployed for the hydrate reservoir and the deep oil reservoir corresponding to the current injection well; When V > 0, V1 > 0 and V 21 < 0, deploy drilling and completion operations for the hydrate reservoir corresponding to the current injection well; When V > 0, V1 < 0, V2 > 0 and V 11 > 0, drilling and completion operations are deployed for the hydrate reservoir and the deep oil reservoir corresponding to the current injection well; When V>0, V1<0, V2>0 and V 11 <0, deploy drilling and completion operations for the deep reservoir corresponding to the current injection well; When V>0, V1<0, and V2<0, drill and complete the well for the hydrate reservoir and the deep oil reservoir corresponding to the current injection well; When V<0 and V1>0, drill and complete the well for the hydrate reservoir corresponding to the current injection well; When V<0, V1<0, and V2>0, drill and complete the well for the deep oil reservoir corresponding to the current injection well; When V<0, V1<0, and V2<0, no drill and complete well operation is carried out for the current injection well.

3. The well pattern deployment method according to claim 1, characterized in that, It also includes a first pressure control switch arranged at the open end of the hydrate reservoir perforation.

4. The well pattern deployment method according to claim 1, wherein It also includes a second pressure control switch arranged at the open end of the hydrocarbon reservoir perforation.

5. The well pattern deployment method according to claim 1, characterized in that, The injection well communicates with the hydrocarbon reservoir perforation and the hydrate reservoir perforation.

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