Shale air pressure channeling well group EUR calculation method, medium and device

Abstract

The invention provides a shale gas pressure channeling well group EUR calculation method, medium and device, and the method comprises the steps: judging whether all shale gas wells in a pressure channeling well group are communicated or not according to the gas production rate and the pressure change condition, and taking the communicated gas wells as a pressure channeling well group; the bottom hole pressure of the pressure channeling well group is obtained according to the bottom hole pressure of each shale gas well in the pressure channeling well group; according to the gas production rate and the water production rate of each shale gas well, the gas production rate and the water production rate of the pressure channeling well group are obtained; according to the physical property of each shale gas well reservoir and shaft data in the pressure channeling well group, a well group analytical model is established by combining the fracturing section length, the fracturing section number and the well spacing data of the pressure channeling well group; and carrying out production history fitting on the yield of the pressure channeling well group and the bottom hole pressure through the well group analysis model, setting a discarding condition, and predicting the shale pressure channeling well group EUR. According to the method, the key parameters in the pressure channeling well group analytical model are established, the well group is used as a unit, the EUR of the pressure channeling well group can be accurately calculated, and the effect of the pressure channeling gas well is effectively evaluated.

Description

Technical Field

[0001] The present invention relates to the technical field of shale gas, and in particular to a method, medium and device for calculating the EUR of a shale gas pressure channeling well group. Background Art

[0002] Deep shale gas fields (buried at depths greater than 4,500 meters) are currently the primary focus of China's largest shale gas production base. The high frequency and long-distance impact of inter-well fracturing interference from crosstalk between gas wells severely impacts individual well production. For wells with crosstalk, wells within the same platform exhibit consistent production and pressure trends, demonstrating strong connectivity. Currently used single-well analytical models and production decline methods are no longer applicable and fail to accurately reflect the actual Estimated Ultimate Recovery (EUR) of the gas wells. Therefore, a platform-based well group EUR calculation method is urgently needed to enable the calculation and verification of EUR for connected well groups. The deep formations of southern Sichuan are currently the primary production areas. By 2023, the Luzhou block had over 170 wells in production, producing over 7 million cubic meters of gas per day, and cumulative gas production exceeding 4.5 billion cubic meters. From the first half of 2021 to 2022, the average EUR per well was 110 million cubic meters. In the second half of 2022, due to complex factors such as pressure channeling and casing deformation, the average EUR per well gradually declined to 93 million cubic meters, a significant impact. The significant variation in gas well curve characteristics after pressure channeling renders single-well EUR prediction methods unusable, resulting in poor fit between well production and pressure. Furthermore, calculating the EUR of shale gas pressure channeling well groups is a crucial step in shale gas development. Researchers both domestically and internationally are exploring the impact of shale gas pressure channeling on well group recovery, including simulations based on geological models and experimental testing. Furthermore, some companies are beginning to adopt advanced numerical simulation software and data analysis tools to optimize well group design and production management, and to improve the accuracy and reliability of EUR calculations for shale gas pressure channeling well groups.

[0003] However, the use of numerical simulation, experimental testing and other methods to carry out EUR calculation of well groups has problems such as long time consumption, and the selection of model parameters and fitting effects are greatly affected by human factors. At the same time, faced with the problem of low calculation efficiency for hundreds of gas wells, it cannot be widely promoted and applied on a large scale. More effective EUR calculation methods and evaluation technologies for pressure-channeling well groups are urgently needed to improve the accuracy, reliability and efficiency of EUR calculation of shale gas pressure-channeling well groups, support gas well effect evaluation, and provide technical support for the optimization of shale gas development technology policies and the formulation of development plans. Summary of the Invention

[0004] To address the existing issues of high connectivity in production and pressure between wells within a shale gas pressure-channeling platform, and poor accuracy and applicability in single-well EUR calculations, the present invention combines analysis of production dynamic data (including parameters such as gas production, water production, and pressure) between wells within the platform after pressure-channeling shale gas wells to provide a method, medium, and device for calculating the EUR of a shale gas pressure-channeling well group. This method enables rapid and accurate calculation of the production and EUR of a group of wells within the pressure-channeling platform, providing a reference for estimating gas well investment and rationalizing economic benefit results, supporting gas well performance evaluation, and providing technical support for optimizing shale gas development technology policies and formulating development plans. Furthermore, the EUR calculation results of the pressure-channeling well group can provide a technical basis for evaluating the degree of recovery of gas wells in the well group before and after pressure-channeling, which is of great significance for the scientific and rational formulation of production capacity maintenance measures for the pressure-channeling well group.

[0005] The present invention provides a method for calculating the EUR of a shale gas pressure channeling well group, comprising the following steps:

[0006] Step 1: Determine whether the shale gas wells in the channeling well group are connected based on gas production and pressure changes, and consider the connected gas wells as a channeling well group;

[0007] Step 2: Perform a weighted average of the bottom hole pressures of the shale gas wells in the channeling well group according to the production constraints to obtain the bottom hole pressure data of the channeling well group;

[0008] Step 3: normalize the gas production and water production of each shale gas well in the pressure-channeling well group to obtain the gas production and water production of the pressure-channeling well group;

[0009] Step 4: Based on the reservoir properties and wellbore data of each shale gas well in the channeling well group, combined with the fracture length, number of fracture stages and well spacing data of the channeling well group, establish a well group analytical model;

[0010] Step 5: Use the well group analytical model to perform production history fitting on the production and bottomhole pressure data of the pressure channeling well group, set abandonment conditions, and predict the EUR of the shale gas pressure channeling well group.

[0011] Furthermore, in step 1, after channeling occurs between shale gas wells on the same platform during the fracturing process, the presence of connectivity is determined by analyzing the temporal trend of the bottom hole pressure of each shale gas well in the channeling well group during production:

[0012] If the bottomhole pressure of each shale gas well in a channeling well group shows a consistent trend over time during production, indicating that a single gas well does not independently control the surrounding shale gas reserves, then there is strong connectivity between the shale gas wells and they can be considered as a channeling well group to calculate the EUR of the channeling well group.

[0013] If the bottomhole pressure of each shale gas well in the channeling well group has a significant difference in temporal variation during production, the channeling well group EUR cannot be calculated as a single channeling well group.

[0014] Furthermore, in step 2, the bottom hole pressure data of the pressure-channeling well group is calculated by weighted averaging the cumulative gas production and the cumulative water production based on the bottom hole pressure data of each shale gas well in the pressure-channeling well group.

[0015] Furthermore, in step 2, the calculation formula for the bottom hole pressure data of the pressure channeling well group is as follows:

[0016] (1) The equivalent underground cumulative gas production and cumulative water production volume of the pressure channeling well group at a certain moment:

[0017] G tni =(G gni ·B g +G wni ·B w )

[0018] G toli =G t1i +···+G tni

[0019] Where:

[0020] G toli Indicates the total volume of gas and water produced by the channeling well group at a certain moment;

[0021] G tni It represents the total volume of gas and water produced by shale gas well n in the pressure channeling well group at a certain moment; when n=1, that is, G t1i Indicates the total volume of gas and water produced by shale gas well 1 in the pressure-channeling well group at a certain moment;

[0022] G gni It represents the cumulative gas production volume of shale gas well n in the pressure channeling well group at a certain moment;

[0023] G wni It represents the cumulative water production volume of shale gas well n in the pressure channeling well group at a certain moment;

[0024] B g represents the volume coefficient of dimensionless gas;

[0025] B w represents the volume coefficient of dimensionless water;

[0026] (2) Bottom hole pressure of the channeling well group at a certain moment:

[0027] P toli =(P 1i ·G t2i +P 2i ·G t2i +···+P ni ·G tni) / G toli

[0028] Where:

[0029] P toli Indicates the bottom hole pressure of the channeling well group at a certain moment;

[0030] P 1i , P 2i ,···P ni They represent the bottom hole pressures of shale gas well 1, shale gas well 2, ..., and shale gas well n in the pressure-channeling well group at a certain moment;

[0031] G 1i , G 2i ,···G ni represent the cumulative gas production and total water production volume of shale gas well 1, shale gas well 2, ..., shale gas well n in the pressure-channeling well group at a certain moment.

[0032] Furthermore, in step 3, the gas production and water production of each shale gas well in the pressure-connected well group are summed and calculated to obtain the gas production and water production of the pressure-connected well group, respectively. The calculation formula is as follows:

[0033] q gti =(q g1i +q g2i +···+q gni )

[0034] q wti =(q w1i +q w2i +···+q wni )

[0035] Where:

[0036] q gti Indicates the daily gas production of the channeling well group at a certain moment;

[0037] q wti Indicates the daily water production of the pressure channeling well group at a certain moment;

[0038] q g1i ,q g2i ,···q gni represent the daily gas production of shale gas well 1, shale gas well 2, ..., shale gas well n in the pressure-channeling well group at a certain moment;

[0039] q w1i ,q w2i ,···q wni represent the daily water production of shale gas well 1, shale gas well 2, ..., and shale gas well n in the pressure-channeling well group at a certain moment.

[0040] Furthermore, in step 4, based on the analytical model of single-well multi-stage fracturing horizontal wells, the fracturing section length is set to the sum of the fracturing section lengths of each shale gas well in the channeling well group, representing the distance in the y direction within the total reserve control range of the channeling well group; the number of fracturing segments is set to the sum of the number of segments of each shale gas well in the channeling well group, representing the number of main fracturing cracks after hydraulic fracturing in the channeling well group; the well spacing distances of each shale gas well in the channeling well group are averaged, representing the distance in the x direction within the total reserve control range of the channeling well group.

[0041] Furthermore, the parameter calculation formula of the well group analytical model in step 4 is as follows:

[0042] L t =L1+L2+···+L n

[0043] N t =N1+N2+···+N n

[0044] X t =X1+X2+···+X n

[0045] Where:

[0046] L t It represents the total fracture length of the channeling well group, that is, the distance in the y direction within the total reserves control range;

[0047] N t Indicates the total number of fracturing stages in the channeling well group;

[0048] X t Indicates the distance in the x direction within the total reserves control range of the channeling well group;

[0049] L1, L2, ···L n They represent the fracturing lengths of shale gas well 1, shale gas well 2, ..., and shale gas well n in the fracturing well group respectively;

[0050] N1, N2,...N n They represent the number of fracturing stages of shale gas well 1, shale gas well 2, ..., and shale gas well n in the fracturing well group, respectively.

[0051] Furthermore, in step five, abandonment conditions are set according to the bottom hole pressure limit and production time.

[0052] The present invention also provides a computer terminal storage medium storing computer terminal executable instructions, wherein the computer terminal executable instructions are used to execute the above-mentioned shale gas pressure channeling well group EUR calculation method.

[0053] The present invention further provides a computing device, comprising:

[0054] At least one processor; and a memory communicatively connected to the at least one processor; wherein the memory stores instructions executable by the at least one processor, and the instructions are executed by the at least one processor to enable the at least one processor to execute the above-mentioned shale gas pressure channeling well group EUR calculation method.

[0055] In summary, due to the adoption of the above technical solution, the beneficial effects of the present invention are:

[0056] 1. The present invention analyzes the time-varying curve of the bottomhole pressure of each shale gas well in the pressure-channeling well group to quickly determine the degree of gas well connectivity and guide the production and EUR prediction of the shale gas well group.

[0057] 2. The present invention starts with the production data of a single shale gas well after pressure-induced channeling, establishes a calculation method for the bottomhole pressure, gas production, and water production of a shale gas channeling well group, forms a basic data processing technology for the channeling well group, supports the evaluation of the effect of channeling gas wells, and provides a technical basis for evaluating the degree of recovery of gas wells in the well group before and after pressure-induced channeling.

[0058] 3. The present invention addresses the problem that the single-well EUR prediction method cannot be used to effectively evaluate the gas well effect after the shale gas platform is pumped and channeled. By establishing key parameters in the analytical model of the pumped and channeled well group, the EUR of the pumped and channeled well group can be accurately calculated on a well group basis, thereby achieving effective evaluation of the pumped and channeled gas well effect. BRIEF DESCRIPTION OF THE DRAWINGS

[0059] In order to more clearly illustrate the technical solutions of the embodiments of the present invention, the drawings in the embodiments will be briefly introduced below. It should be understood that the following drawings only illustrate certain embodiments of the present invention and therefore should not be regarded as limiting the scope. For ordinary technicians in this field, other relevant drawings can be obtained based on these drawings without paying any creative work.

[0060] Figure 1 Flowchart of the EUR calculation method for a shale gas pressure channeling well group in an embodiment of the present invention.

[0061] Figure 2 1 is a graph showing the pressure variation over time of each shale gas well in a pressure-channeling well group exemplified in an embodiment of the present invention.

[0062] Figure 3 This is a graph showing the production data of a channeling well group changing over time, as exemplified in an embodiment of the present invention. DETAILED DESCRIPTION

[0063] To make the objectives, technical solutions, and advantages of the embodiments of the present invention more clear, the technical solutions of the embodiments of the present invention will be clearly and completely described below in conjunction with the accompanying drawings of the embodiments of the present invention. Obviously, the described embodiments are only part of the embodiments of the present invention, not all of the embodiments. Generally, the components of the embodiments of the present invention described and shown in the drawings herein can be arranged and designed in various different configurations.

[0064] Therefore, the following detailed description of the embodiments of the present invention provided in the accompanying drawings is not intended to limit the scope of the invention as claimed, but rather merely represents selected embodiments of the present invention. All other embodiments derived by persons of ordinary skill in the art based on the embodiments of the present invention without creative effort are intended to fall within the scope of protection of the present invention.

[0065] Example

[0066] like Figure 1 As shown, this embodiment proposes a method for calculating the EUR of a shale gas pressure channeling well group, including the following steps:

[0067] Step 1: Determine whether the shale gas wells in the channeling well group are connected based on gas production and pressure changes, and consider the connected gas wells as a channeling well group;

[0068] In step 1, after channeling occurs between shale gas wells on the same platform during the fracturing process, the presence of connectivity is determined by analyzing the temporal variation trend of the bottom hole pressure of each shale gas well in the channeling well group during production:

[0069] If the bottomhole pressure of each shale gas well in a channeling well group shows a consistent trend over time during production, indicating that a single gas well does not independently control the surrounding shale gas reserves, then there is strong connectivity between the shale gas wells and they can be considered as a channeling well group to calculate the EUR of the channeling well group.

[0070] If the bottomhole pressure of each shale gas well in the channeling well group has a significant difference in temporal variation during production, the channeling well group EUR cannot be calculated as a single channeling well group.

[0071] Step 2: Perform a weighted average of the bottom hole pressures of the shale gas wells in the channeling well group according to the production constraints to obtain the bottom hole pressure data of the channeling well group;

[0072] In step 2, the bottom hole pressure data of the shale gas wells in the pressure channeling well group is calculated by weighted average of the cumulative gas production and the cumulative water production. The calculation formula is as follows:

[0073] (1) The equivalent underground cumulative gas production and cumulative water production volume of the pressure channeling well group at a certain moment:

[0074] G tni=(G gni ·B g +G wni ·B w )

[0075] G toli =G t1i +···+G tni

[0076] Where:

[0077] G toli Indicates the total volume of gas and water produced by the channeling well group at a certain moment;

[0078] G tni It represents the total volume of gas and water produced by shale gas well n in the pressure channeling well group at a certain moment; when n=1, that is, G t1i Indicates the total volume of gas and water produced by shale gas well 1 in the pressure-channeling well group at a certain moment;

[0079] G gni It represents the cumulative gas production volume of shale gas well n in the pressure channeling well group at a certain moment;

[0080] G wni It represents the cumulative water production volume of shale gas well n in the pressure channeling well group at a certain moment;

[0081] B g represents the volume coefficient of dimensionless gas;

[0082] B w represents the volume coefficient of dimensionless water;

[0083] (2) Bottom hole pressure of the channeling well group at a certain moment:

[0084] P toli =(P 1i ·G t2i +P 2i ·G t2i +···+P ni ·G tni ) / G toli

[0085] Where:

[0086] P toli Indicates the bottom hole pressure of the channeling well group at a certain moment;

[0087] P 1i , P 2i ,···P ni They represent the bottom hole pressures of shale gas well 1, shale gas well 2, ..., and shale gas well n in the pressure-channeling well group at a certain moment;

[0088] G 1i , G 2i ,···G ni represent the cumulative gas production and total water production volume of shale gas well 1, shale gas well 2, ..., shale gas well n in the pressure-channeling well group at a certain moment.

[0089] Step 3: normalize the gas production and water production of each shale gas well in the pressure-channeling well group to obtain the gas production and water production of the pressure-channeling well group;

[0090] In step 3, the gas production and water production of each shale gas well in the pressure-connected well group are summed and calculated to obtain the gas production and water production of the pressure-connected well group, respectively. The calculation formula is as follows:

[0091] q gti =(q g1i +q g2i +···+q gni )

[0092] q wti =(q w1i +q w2i +···+q wni )

[0093] Where:

[0094] q gti Indicates the daily gas production of the channeling well group at a certain moment;

[0095] q wti Indicates the daily water production of the pressure channeling well group at a certain moment;

[0096] q g1i ,q g2i ,···q gni represent the daily gas production of shale gas well 1, shale gas well 2, ..., shale gas well n in the pressure-channeling well group at a certain moment;

[0097] q w1i ,q w2i ,···q wni represent the daily water production of shale gas well 1, shale gas well 2, ..., and shale gas well n in the pressure-channeling well group at a certain moment.

[0098] Step 4: Based on the reservoir properties and wellbore data of each shale gas well in the channeling well group, combined with the fracture length, number of fracture stages and well spacing data of the channeling well group, establish a well group analytical model;

[0099] In step 4, based on the single-well multi-stage fracturing horizontal well analytical model, the fracturing section length is set to the sum of the fracturing section lengths of each shale gas well in the channeling well group, representing the distance in the y direction within the total reserve control range of the channeling well group; the number of fracturing segments is set to the sum of the number of segments of each shale gas well in the channeling well group, representing the number of main fracturing fractures after hydraulic fracturing in the channeling well group; the distance between each shale gas well in the channeling well group is averaged, representing the distance in the x direction within the total reserve control range of the channeling well group. Thus, the parameter calculation formula of the well group analytical model established is as follows:

[0100] L t =L1+L2+···+L n

[0101] N t =N1+N2+···+N n

[0102] X t =X1+X2+···+X n

[0103] Where:

[0104] L t It represents the total fracture length of the channeling well group, that is, the distance in the y direction within the total reserves control range;

[0105] N t Indicates the total number of fracturing stages in the channeling well group;

[0106] X t Indicates the distance in the x direction within the total reserves control range of the channeling well group;

[0107] L1, L2, ···L n They represent the fracturing lengths of shale gas well 1, shale gas well 2, ..., and shale gas well n in the fracturing well group respectively;

[0108] N1, N2,...N n They represent the number of fracturing stages of shale gas well 1, shale gas well 2, ..., and shale gas well n in the fracturing well group, respectively.

[0109] Step 5: Using the well group analytical model, perform production history fitting on the production and bottomhole pressure data of the pressure-channeling well group, set abandonment conditions, and predict the EUR of the shale gas pressure-channeling well group. Abandonment conditions can be set based on bottomhole pressure limits and production duration, for example, when the bottomhole pressure is no less than 2.5 MPa and the production duration is 20 years.

[0110] Example:

[0111] The shale gas channeling platform is W1 platform, and the shale gas wells in the channeling well group within the platform are W1-1, W1-2, W1-3, and W1-4. The lengths of the fracturing sections of the four shale gas wells are 1861 meters, 1826 meters, 1850 meters, and 1938 meters, respectively. The number of fracturing stages is 27, 27, 28, and 28, respectively. The well spacing is 300 meters, and the gas volume coefficient B is 0. g The volume coefficient of water is 0.00275, B w is 1.01. According to the gas production q recorded during the production process g , water production q w , bottom hole pressure P and other parameters. Some specific data tables are shown in Table 1, Table 2, Table 3 and Table 4.

[0112] Table 1, W1-1 well production data table (partial):

[0113]

[0114]

[0115] Table 2, W1-2 well production data table (partial):

[0116]

[0117]

[0118] Table 3, W1-3 well production data table (partial):

[0119]

[0120] Table 4, W1-4 well production data table (partial):

[0121]

[0122]

[0123] According to the steps 1, 2 and 3, the bottom hole pressure, gas production and water production of the channeling well group are calculated. Figure 3 and Table 5.

[0124] Table 5, W1 well group production data table (partial):

[0125]

[0126] According to step 1, a curve of the bottom hole pressure of each shale gas well in the pressure channeling well group over time is drawn during the production process. Figure 2 ,from Figure 2It can be found that the overall pressure decrease trend is basically the same, indicating that there is strong connectivity between the pressure-channeling well groups, and they can be regarded as a pressure-channeling well group to calculate the EUR of the pressure-channeling well group.

[0127] According to step 2, based on the bottom hole pressure, gas production, and water production data of each shale gas well in the pressure channeling well group and combined with the bottom hole pressure calculation method of the pressure channeling well group, the bottom hole pressure data of the pressure channeling well group are obtained, as shown in Table 5.

[0128] According to step 3, based on the gas production and water production of each shale gas well in the pressure-channeling well group, the gas production and water production of the pressure-channeling well group are calculated, as shown in Table 5.

[0129] According to step 4, the calculated distance in the x-direction within the total reserves control range in the analytical model of the hydraulically-induced well group is 300 meters, the distance in the y-direction within the total reserves control range is 7475 meters, and the number of main fracturing fractures after hydraulic fracturing in the analytical model of the well group is 110.

[0130] According to step five, based on the analytical model of a single-well multi-stage fracturing horizontal well, by setting the x- and y-direction distances in the total reserves control range to 300 meters and 7475 meters, respectively, and the number of main fractures to 110, the production and bottomhole pressure of the channeling well group were fitted. The bottomhole pressure was set to no less than 2.5 MPa and the abandonment condition after 20 years of production was set. The cumulative gas production over 20 years was predicted, which is the EUR of the channeling well group. The predicted cumulative gas production over 20 years is 350 million cubic meters, that is, the EUR of the W1 well group is 350 million cubic meters, and the average EUR of each of the four wells is 87.5 million cubic meters.

[0131] Furthermore, in some embodiments, a computer terminal storage medium is provided, storing computer terminal executable instructions for executing the EUR calculation method for a shale gas pressure channeling well group as described in the preceding embodiments. Examples of computer storage media include magnetic storage media (e.g., floppy disks, hard disks, etc.), optical recording media (e.g., CD-ROMs, DVDs, etc.), or memory devices such as memory cards, ROM, or RAM. Computer storage media can also be distributed across networked computer systems, such as in an application store.

[0132] In some embodiments, a computing device is provided, comprising: at least one processor; and a memory communicatively coupled to the at least one processor; wherein the memory stores instructions executable by the at least one processor, and the instructions are executed by the at least one processor to enable the at least one processor to perform the EUR calculation method for a shale gas pressure channeling well group as described in the above embodiments. Examples of computing devices include a PC, a tablet computer, a smartphone, or a PDA.

[0133] The foregoing description is merely a preferred embodiment of the present invention and is not intended to limit the present invention. Those skilled in the art will readily appreciate that various modifications and variations of the present invention are possible. Any modifications, equivalent substitutions, or improvements made within the spirit and principles of the present invention are intended to be within the scope of protection of the present invention.

Claims

1. A method for calculating EUR of a shale gas pressure channeling well group, characterized in that: The steps include: Step 1: Determine whether the shale gas wells in the channeling well group are connected based on gas production and pressure changes, and consider the connected gas wells as a channeling well group; Step 2: Perform a weighted average of the bottom hole pressures of the shale gas wells in the channeling well group according to the production constraints to obtain the bottom hole pressure data of the channeling well group; Step 3: normalize the gas production and water production of each shale gas well in the pressure-channeling well group to obtain the gas production and water production of the pressure-channeling well group; Step 4: Based on the reservoir properties and wellbore data of each shale gas well in the channeling well group, combined with the fracture length, number of fracture stages and well spacing data of the channeling well group, establish a well group analytical model; Step 5: Use the well group analytical model to perform production history fitting on the production and bottomhole pressure data of the pressure channeling well group, set abandonment conditions, and predict the EUR of the shale gas pressure channeling well group.

2. The EUR calculation method for a shale gas pressure channeling well group according to claim 1, characterized in that: In step 1, after channeling occurs between shale gas wells on the same platform during the fracturing process, the presence of connectivity is determined by analyzing the temporal trend of the bottomhole pressure of each shale gas well in the channeling well group during production: If the bottomhole pressure of each shale gas well in a channeling well group shows a consistent trend over time during production, indicating that a single gas well does not independently control the surrounding shale gas reserves, then there is strong connectivity between the shale gas wells and they can be considered as a channeling well group to calculate the EUR of the channeling well group. If the bottomhole pressure of each shale gas well in the channeling well group has a significant difference in temporal variation during production, the channeling well group EUR cannot be calculated as a single channeling well group.

3. The EUR calculation method for a shale gas pressure channeling well group according to claim 1, characterized in that: In step 2, the bottom hole pressure data of the channeling well group is calculated based on the bottom hole pressure data of each shale gas well in the channeling well group by weighted averaging the cumulative gas production and the cumulative water production.

4. The EUR calculation method for a shale gas pressure channeling well group according to claim 3, characterized in that: In step 2, the calculation formula for the bottom hole pressure data of the pressure channeling well group is as follows: (1) The equivalent underground cumulative gas production and cumulative water production volume of the pressure channeling well group at a certain moment: G tni =(G gni ·B g +G wni ·B w ) G toli =G t1i +···+G tni Where: G toli Indicates the total volume of gas and water produced by the channeling well group at a certain moment; G tni It represents the total volume of gas and water produced by shale gas well n in the pressure channeling well group at a certain moment; when n=1, that is, G t1i Indicates the total volume of gas and water produced by shale gas well 1 in the pressure-channeling well group at a certain moment; G gni It represents the cumulative gas production volume of shale gas well n in the pressure channeling well group at a certain moment; G wni It represents the cumulative water production volume of shale gas well n in the pressure channeling well group at a certain moment; B g represents the volume coefficient of dimensionless gas; B w represents the volume coefficient of dimensionless water; (2) Bottom hole pressure of the channeling well group at a certain moment: P toli =(P 1i ·G t2i +P 2i ·G t2i +···+P ni ·G tni ) / G toli Where: P toli Indicates the bottom hole pressure of the channeling well group at a certain moment; P 1i , P 2i ,···P ni They represent the bottom hole pressures of shale gas well 1, shale gas well 2, ..., and shale gas well n in the pressure-channeling well group at a certain moment; G 1i , G 2i ,···G ni represent the cumulative gas production and total water production volume of shale gas well 1, shale gas well 2, ..., shale gas well n in the pressure-channeling well group at a certain moment.

5. The EUR calculation method for a shale gas pressure channeling well group according to claim 1, characterized in that: In step 3, the gas production and water production of each shale gas well in the pressure-connected well group are summed and calculated to obtain the gas production and water production of the pressure-connected well group. The calculation formula is as follows: q gti =(q g1i +q g2i +···+q gni ) q wti =(q w1i +q w2i +···+q wni ) Where: q gti Indicates the daily gas production of the channeling well group at a certain moment; q wti Indicates the daily water production of the pressure channeling well group at a certain moment; q g1i ,q g2i ,···q gni represent the daily gas production of shale gas well 1, shale gas well 2, ..., shale gas well n in the pressure-channeling well group at a certain moment; q w1i ,q w2i ,···q wni represent the daily water production of shale gas well 1, shale gas well 2, ..., and shale gas well n in the pressure-channeling well group at a certain moment.

6. The EUR calculation method for a shale gas pressure channeling well group according to claim 1, characterized in that: In step 4, based on the analytical model of single-well multi-stage fracturing horizontal wells, the fracturing section length is set to the sum of the fracturing section lengths of each shale gas well in the channeling well group, representing the distance in the y direction within the total reserve control range of the channeling well group; the number of fracturing segments is set to the sum of the number of segments of each shale gas well in the channeling well group, representing the number of main fracturing fractures after hydraulic fracturing in the channeling well group; the average well spacing distance of each shale gas well in the channeling well group is calculated, representing the distance in the x direction within the total reserve control range of the channeling well group.

7. The EUR calculation method for a shale gas pressure channeling well group according to claim 6, characterized in that: The parameter calculation formula of the well group analytical model in step 4 is as follows: L t =L1+L2+···+L n N t =N1+N2+···+N n X t =X1+X2+···+X n Where: L t It represents the total fracture length of the channeling well group, that is, the distance in the y direction within the total reserves control range; N t Indicates the total number of fracturing stages in the channeling well group; X t Indicates the distance in the x direction within the total reserves control range of the channeling well group; L1, L2, ···L n They represent the fracturing lengths of shale gas well 1, shale gas well 2, ..., and shale gas well n in the fracturing well group respectively; N1, N2,...N n They represent the number of fracturing stages of shale gas well 1, shale gas well 2, ..., and shale gas well n in the fracturing well group, respectively.

8. The EUR calculation method for a shale gas pressure channeling well group according to claim 1, characterized in that: In step five, the abandonment conditions are set according to the bottom hole pressure limit and production time.

9. A computer terminal storage medium storing computer terminal executable instructions, characterized in that: The computer terminal executable instructions are used to execute the EUR calculation method for a shale gas pressure channeling well group according to any one of claims 1 to 8.

10. A computing device, characterized in that: include: at least one processor; and a memory communicatively connected to the at least one processor; wherein the memory stores instructions executable by the at least one processor, and the instructions are executed by the at least one processor so that the at least one processor can execute the EUR calculation method for a shale gas pressure channeling well group as described in any one of claims 1 to 8.

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