Prediction method of abnormal formation pressure of foreign source

Abstract

The application discloses a prediction method of abnormal formation pressure of an external source, a computer readable storage medium and a computer device, wherein the method is based on collected well logging curve data, well logging interpretation results and fluid sampling results of drilled wells to obtain formation pressure P1 of a shallow gas-bearing sand body before the sand body is connected, formation pressure P2 of a deep gas-bearing sand body before the sand body is connected, hydrostatic pressure P 静1 of a position where the shallow gas-bearing sand body is located, hydrostatic pressure P 静2 of a position where the deep gas-bearing sand body is located, a mole number n1 of gas contained in the shallow gas-bearing sand body and a mole number n2 of gas contained in the deep gas-bearing sand body, and further through calculation, formation pressure P 11 of the shallow gas-bearing sand body after the sand body is connected due to fracture or drilling operation and formation pressure P 22 of the deep gas-bearing sand body. The application can predict abnormal formation pressure of an external source, is beneficial to finding oil and gas reservoirs, designing reasonable drilling fluid density and well structure, ensuring drilling safety, improving drilling success rate, reducing drilling cost and protecting oil and gas reservoirs.

Description

Technical Field

[0001] This invention relates to the field of oil and gas exploration technology, and in particular to a method for predicting anomalous formation high pressure from other sources, a computer-readable storage medium, and a computer device. Background Technology

[0002] Abnormal formation pressure is a common phenomenon in oil and gas basins. Abnormal formation pressure, especially abnormally high formation pressure, directly affects drilling and fracturing safety, the safety of life and property, and the oil and gas exploration process. Predicting abnormal formation pressure is of great significance for finding oil and gas reservoirs, designing reasonable drilling fluid densities and well structures, ensuring drilling safety, improving drilling success rates, reducing drilling costs, and protecting oil and gas reservoirs.

[0003] Externally sourced anomalous formation high pressure refers to the phenomenon where permeable formations become hydrodynamically connected with other overpressured permeable formations (with higher excess pressure (fluid potential energy)) due to various geological and engineering factors. This leads to pressure adjustment between formations with previously vastly different excess pressures, resulting in an abnormally high fluid pressure within the formation. As an effective overpressure mechanism, anomalous formation pressures caused by this mechanism frequently occur in geological bodies. Traditional prediction methods often rely on the physical properties of the formation, such as velocity, to infer pressure changes. However, for externally sourced anomalous formation high pressure, the traditional velocity-pressure relationship is no longer applicable. Conventional formation pressure prediction methods are not suitable for predicting externally sourced anomalous formation high pressure. Summary of the Invention

[0004] To address at least one of the aforementioned problems, the present invention aims to provide a method, computer-readable storage medium, and computer device for predicting externally sourced abnormal formation pressures, capable of performing such predictions.

[0005] To achieve the above objectives, the present invention adopts the following technical solution:

[0006] The first aspect of this invention provides a method for predicting externally sourced anomalous formation high pressure, comprising: collecting well logging data, well logging interpretation results, and fluid sampling results from drilled wells; the well logging data including P-wave transit time data, density curve data, and gamma data from drilled wells; and the well logging interpretation results including porosity data from drilled wells; converting the P-wave transit time data into P-wave velocity data; and calculating the overlying strata pressure P using the density curve data. o Combined with the pressure P of the overlying strata oBased on P-wave velocity data, calculate the formation pressure P1 before connection of shallow gas-bearing sand bodies and the formation pressure P2 before connection of deep gas-bearing sand bodies, which may be caused by fractures or drilling operations. Use seismic data inversion results to characterize the shallow and deep gas-bearing sand bodies, obtaining the volumes V1 and V2 of the shallow and deep gas-bearing sand bodies. Based on the volume V1 and porosity data of the shallow gas-bearing sand bodies, calculate the pore size V of the shallow gas-bearing sand bodies. 1孔 Based on the volume V2 and porosity data of the deep gas-bearing sand body, the pore size V of the deep gas-bearing sand body is calculated. 2孔 Based on the pore size V of the shallow gas-bearing sand body 1孔 Given the gas density, calculate the mass m1 of gas contained in the shallow gas-bearing sand body, and then calculate the pore size V of the deep gas-bearing sand body. 2孔 Given the gas density, calculate the mass m2 of gas contained in the deep gas-bearing sand body; based on the mass m1 of gas contained in the shallow gas-bearing sand body, calculate the number of moles n1 of gas contained in the shallow gas-bearing sand body; based on the mass m2 of gas contained in the deep gas-bearing sand body, calculate the number of moles n2 of gas contained in the deep gas-bearing sand body; calculate the hydrostatic pressure P at the location of the shallow gas-bearing sand body. 静1 The hydrostatic pressure P at the location of the deep gas-bearing sand body 静2 Based on the formation pressure P1 before the shallow gas-bearing sand bodies connect, the formation pressure P2 before the deep gas-bearing sand bodies connect, and the hydrostatic pressure P at the location of the shallow gas-bearing sand bodies. 静1 The hydrostatic pressure P at the location of the deep gas-bearing sand body 静2 The number of moles of gas in shallow gas-bearing sand bodies (n1) and the number of moles of gas in deep gas-bearing sand bodies (n2) are used to predict the formation pressure P of the shallow gas-bearing sand bodies after they become connected due to fractures or drilling operations. 11 and deep gas-bearing sandstone formation pressure P 22 .

[0007] Optionally, in the prediction method for externally sourced abnormal formation high pressure provided in at least one embodiment of the present invention, the quality of the collected well logging curve data is checked. If a problem is found, well logging curve editing and correction work is carried out. Well logging curve editing and correction work includes well logging curve data depth correction, splicing, consistency processing and singular value correction.

[0008] Optionally, in the prediction method for externally sourced anomalous formation high pressure provided in at least one embodiment of the present invention, the P-wave time difference data is converted into P-wave velocity data using the following formula:

[0009] Velocity = 1 / DT;

[0010] In the formula, Velocity is the P-wave velocity; DT is the P-wave time difference.

[0011] Optionally, in the method for predicting anomalous formation high pressure from other sources provided in at least one embodiment of the present invention, the overlying strata pressure P is calculated using the following formula. o :

[0012]

[0013] In the formula, H is the depth of the overlying rock layer; ρ(H) is the density of the overlying rock layer at depth H; and g is the gravitational acceleration.

[0014] Optionally, in the prediction method for externally sourced abnormal formation high pressure provided in at least one embodiment of the present invention, the formation pressure P1 before the shallow gas-bearing sand body connects and the formation pressure P2 before the deep gas-bearing sand body connects are calculated based on the following Eaton method formula:

[0015]

[0016] In the formula, P 静水 The hydrostatic pressure is represented by the trend line, which is the normal compaction trend line. 指 This refers to the Eaton index.

[0017] Optionally, in the method for predicting externally sourced anomalous formation high pressure provided in at least one embodiment of the present invention, the pore size V of the shallow gas-bearing sand body is calculated according to the following formula. 1孔 Pore ​​size V of deep gas-bearing sand bodies 2孔 :

[0018] V 孔 =V × Porosity;

[0019] In the formula, V is the volume of the gas-bearing sand body; Porosity is the porosity of the gas-bearing sand body.

[0020] Optionally, in the method for predicting externally sourced anomalous formation high pressure provided in at least one embodiment of the present invention, the mass m1 of gas contained in shallow gas-bearing sand bodies and the mass m2 of gas contained in deep gas-bearing sand bodies are calculated according to the following formula:

[0021] m = V 孔 ×ρ 气 ;

[0022] In the formula, V 孔 ρ represents the pore size of the gas-bearing sand body. 气 The density is the gas density.

[0023] Optionally, in the prediction method for externally sourced anomalous formation high pressure provided in at least one embodiment of the present invention, the number of moles of gas contained in shallow gas-bearing sand bodies, n1, and the number of moles of gas contained in deep gas-bearing sand bodies, n2, are calculated according to the following formula:

[0024] n = m / M

[0025] In the formula, m is the mass of the gas; M is the molar mass.

[0026] Optionally, in the method for predicting externally sourced anomalous formation high pressure provided in at least one embodiment of the present invention, the hydrostatic pressure P at the location of the shallow gas-bearing sand body is calculated according to the following formula. 静1 The hydrostatic pressure P at the location of the deep gas-bearing sand body 静2 :

[0027] P 静 =ρ 水 gh

[0028] In the formula, ρ 水 ρ is the density of the formation water; h is the depth.

[0029] Optionally, in the method for predicting abnormal formation high pressure from other sources provided in at least one embodiment of the present invention, the formation pressure P of the shallow gas-bearing sand body after connection caused by fracture or drilling operations is calculated according to the following formula. 11 and deep gas-bearing sandstone formation pressure P 22 :

[0030]

[0031]

[0032] In the formula, P1 is the formation pressure before the shallow gas-bearing sand body is connected; P2 is the formation pressure before the deep gas-bearing sand body is connected.

[0033] A second aspect of the present invention provides a computer-readable storage medium storing a computer program that, when executed by a processor, implements the steps of the method for predicting externally sourced anomalous formation high pressure as described above.

[0034] A third aspect of the present invention provides a computer device, including a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the computer program to implement the steps of the method for predicting externally sourced anomalous formation high pressure as described above.

[0035] Because the present invention adopts the above technical solution, it has at least the following advantages:

[0036] I. The method for predicting abnormal formation pressure from other sources provided by this invention can predict abnormal formation pressure from other sources, thereby facilitating the search for oil and gas reservoirs, designing reasonable drilling fluid densities and well structures, ensuring drilling safety, improving drilling success rates, reducing drilling costs, and protecting oil and gas reservoirs. This method can improve the accuracy of predicting abnormal formation pressure from other sources, solving the problem that conventional formation pressure prediction methods are difficult to predict such abnormal formation pressure.

[0037] II. The prediction method for abnormal formation high pressure from other sources provided by this invention can be used to explain the causes of some formation pressure characteristics.

[0038] Third, the method for predicting abnormal formation high pressure from other sources provided by the present invention can predict abnormal formation high pressure from other sources formed by the connection between shallow gas-bearing sand bodies and deep gas-bearing sand bodies caused by fractures or drilling operations, without relying on the relationship between velocity and formation pressure.

[0039] Fourth, the prediction method for abnormal formation high pressure from other sources provided by this invention can improve the accuracy of prediction of abnormal formation high pressure from other sources compared with conventional methods, and can better guide engineering drilling mud design, etc. Attached Figure Description

[0040] Figure 1 This is a flowchart illustrating a method for predicting abnormal formation high pressure from other sources in at least one embodiment of the present invention. Detailed Implementation

[0041] To make the objectives, technical solutions, and advantages of this invention clearer, the technical solutions of this invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some, not all, of the embodiments of this invention. All other embodiments obtained by those skilled in the art based on the embodiments of this invention without creative effort are within the scope of protection of this invention.

[0042] In the description of this invention, it should be noted that the terms "upper", "lower", "front", "rear", etc., indicate the orientation or positional relationship based on the orientation or positional relationship shown in the accompanying drawings. They are only for the convenience of describing this invention and simplifying the description, and do not indicate or imply that the system or element referred to must have a specific orientation, or be constructed and operated in a specific orientation. Therefore, they should not be construed as limitations on this invention.

[0043] In the description of this invention, it should be noted that, unless otherwise explicitly specified and limited, the terms "assembly," "setup," and "connection" should be interpreted broadly. For example, they can refer to a fixed connection, a detachable connection, or an integral connection; they can refer to a mechanical connection or an electrical connection; they can refer to a direct connection or an indirect connection through an intermediate medium; and they can refer to the internal connection of two components. Those skilled in the art can understand the specific meaning of the above terms in this invention based on the specific circumstances.

[0044] This invention provides a method for predicting externally sourced anomalous formation high pressure, a computer-readable storage medium, and a computer device. The method for predicting externally sourced anomalous formation high pressure, as provided by this invention, can predict abnormal formation pressure, thereby facilitating oil and gas reservoir discovery, designing reasonable drilling fluid densities and well structures, ensuring drilling safety, improving drilling success rates, reducing drilling costs, and protecting oil and gas reservoirs. This method improves the accuracy of predicting externally sourced anomalous formation high pressure, solving the problem that conventional formation pressure prediction methods are insufficient for predicting such anomalous formation high pressure.

[0045] Furthermore, the prediction method for externally sourced abnormal formation high pressure provided by this invention can be used to explain the causes of some formation pressure characteristics.

[0046] Furthermore, the method for predicting externally sourced abnormal formation high pressure provided by the present invention can predict externally sourced abnormal formation high pressure formed by the connection between shallow and deep gas-bearing sand bodies caused by fractures or drilling operations, without relying on the relationship between velocity and formation pressure.

[0047] Furthermore, the prediction method for externally sourced abnormal formation high pressure provided by this invention can improve the accuracy of prediction of externally sourced abnormal formation high pressure compared with conventional methods, and can better guide engineering drilling mud design, etc.

[0048] The following is a detailed description, in conjunction with the accompanying drawings, of the method for predicting externally sourced anomalous formation high pressure, the computer-readable storage medium, and the computer equipment provided in the embodiments of the present invention.

[0049] Example 1:

[0050] Reference Figure 1 As shown, the method for predicting externally sourced anomalous formation high pressure provided by the present invention includes the following steps S1 to S10:

[0051] S1, collect well logging curve data, well logging interpretation results and fluid sampling results of drilled wells. Well logging curve data includes P-wave transit time data, density curve data and gamma data of drilled wells. Well logging interpretation results include porosity data of drilled wells.

[0052] S2 converts P-wave time difference data into P-wave velocity data;

[0053] S3, calculate the overlying strata pressure P using density curve data. o ;

[0054] S4, combined with the pressure of the overlying strata P o Based on the P-wave velocity data, calculate the formation pressure P1 before the shallow gas-bearing sand body connects and the formation pressure P2 before the deep gas-bearing sand body connects, which may be caused by the fracture or drilling operation.

[0055] S5. Using the seismic data inversion results, shallow gas-bearing sand bodies and deep gas-bearing sand bodies are characterized, and the volumes of shallow gas-bearing sand bodies V1 and deep gas-bearing sand bodies V2 are obtained.

[0056] S6. Based on the volume V1 and porosity data of the shallow gas-bearing sand body, calculate the pore size V of the shallow gas-bearing sand body. 1孔 Based on the volume V2 and porosity data of the deep gas-bearing sand body, the pore size V of the deep gas-bearing sand body is calculated. 2孔 ;

[0057] S7, based on the pore size V of the shallow gas-bearing sand body 1孔 Given the gas density, calculate the mass m1 of gas contained in the shallow gas-bearing sand body, and then calculate the pore size V of the deep gas-bearing sand body. 2孔 Given the gas density, calculate the mass m2 of gas contained in the deep gas-bearing sand body;

[0058] S8. Based on the mass m1 of the gas contained in the shallow gas-bearing sand body, calculate the number of moles n1 of the gas contained in the shallow gas-bearing sand body. Based on the mass m2 of the gas contained in the deep gas-bearing sand body, calculate the number of moles n2 of the gas contained in the deep gas-bearing sand body.

[0059] S9, Calculate the hydrostatic pressure P at the location of the shallow gas-bearing sand body. 静1 The hydrostatic pressure P at the location of the deep gas-bearing sand body 静2 ;

[0060] S10, based on the formation pressure P1 before the shallow gas-bearing sand body connects, the formation pressure P2 before the deep gas-bearing sand body connects, and the hydrostatic pressure P at the location of the shallow gas-bearing sand body. 静1 The hydrostatic pressure P at the location of the deep gas-bearing sand body 静2 The number of moles of gas in shallow gas-bearing sand bodies (n1) and the number of moles of gas in deep gas-bearing sand bodies (n2) are used to predict the formation pressure P of the shallow gas-bearing sand bodies after they become connected due to fractures or drilling operations. 11 and deep gas-bearing sandstone formation pressure P 22 .

[0061] It should be noted that this method for predicting abnormal formation high pressure from other sources is applicable to predicting abnormal formation high pressure from other sources formed by the connection between shallow and deep gas-bearing sand bodies caused by fractures or drilling operations. Optionally, in this embodiment, to simplify the formula derivation, this method for predicting abnormal formation high pressure from other sources assumes that the shallow and deep gas-bearing sand bodies contain the same type of gas, have the same gas density, 100% gas saturation, and the same temperature.

[0062] Furthermore, in this embodiment, the quality of the collected logging curve data is checked. If problems are found, logging curve editing and correction work is carried out. The logging curve editing and correction work includes, but is not limited to, logging curve data depth correction, splicing, consistency processing and outlier correction.

[0063] Optionally, in step S2, the P-wave time difference data is converted into P-wave velocity data using the following formula:

[0064] Velocity = 1 / DT (1)

[0065] In equation (1), Velocity is the longitudinal wave velocity; DT is the longitudinal wave time difference.

[0066] Optionally, in step S3, the overlying stratum pressure P is calculated using the following formula. o :

[0067]

[0068] In equation (2), H is the depth of the overlying rock layer; ρ(H) is the density of the overlying rock layer at depth H; and g is the gravitational acceleration.

[0069] Optionally, in step S4, the overlying strata pressure P is considered. o Using P-wave velocity data, conventional formation pressure prediction methods (such as the Eaton method) are employed to calculate the formation pressure P1 before the shallow gas-bearing sand body connects and the formation pressure P2 before the deep gas-bearing sand body connects.

[0070] Furthermore, based on the Eaton method formula below, the formation pressure P1 before the shallow gas-bearing sand body connects and the formation pressure P2 before the deep gas-bearing sand body connects are calculated:

[0071]

[0072] In equation (3), P 静水 The hydrostatic pressure is represented by the trend line, which is the normal compaction trend line. 指 This refers to the Eaton index.

[0073] Optionally, in step S6, the pore size V of the shallow gas-bearing sand body is calculated according to the following formula. 1孔 Pore ​​size V of deep gas-bearing sand bodies 2孔 :

[0074] V 孔 =V×P0rosity (4)

[0075] In equation (4), V is the volume of the gas-bearing sand body; Porosity is the porosity of the gas-bearing sand body.

[0076] Optionally, in step S7, the gas densities of shallow and deep gas-bearing sand bodies are obtained from the drilling fluid sampling results; the mass m1 of gas contained in the shallow gas-bearing sand body and the mass m2 of gas contained in the deep gas-bearing sand body are calculated according to the following formulas:

[0077] m = V 孔 ×ρ 气 (5)

[0078] In equation (5), V 孔 ρ represents the pore size of the gas-bearing sand body. 气 The density is the gas density.

[0079] Optionally, in step S8, the number of moles of gas contained in the shallow gas-bearing sand body n1 and the number of moles of gas contained in the deep gas-bearing sand body n2 are calculated according to the following formulas:

[0080] n=m / M (6)

[0081] In equation (6), m is the mass of the gas; M is the molar mass.

[0082] Optionally, in step S9, the hydrostatic pressure P at the location of the shallow gas-bearing sand body is calculated according to the following formula. 静1 The hydrostatic pressure P at the location of the deep gas-bearing sand body 静2 :

[0083] P 静 =ρ 水 gh (7)

[0084] In equation (7), ρ 水 ρ is the density of the formation water; h is the depth.

[0085] Optionally, in step S10, the formation pressure P of the shallow gas-bearing sand body after the connection caused by the fracture or drilling operation is calculated according to the following formula. 11 and deep gas-bearing sandstone formation pressure P 22 :

[0086]

[0087]

[0088] In equations (8) and (9), P1 is the formation pressure before the shallow gas-bearing sand body is connected; P2 is the formation pressure before the deep gas-bearing sand body is connected.

[0089] Example 2:

[0090] The method for predicting externally sourced anomalous formation high pressure provided in the first aspect of the present invention can be specifically implemented as a computer program product. The computer program product may include a computer-readable storage medium on which computer-readable program instructions for executing the method for predicting externally sourced anomalous formation high pressure described in the first aspect of the present invention are loaded.

[0091] A computer-readable storage medium can be a tangible device that holds and stores instructions for use by an instruction execution device. A computer-readable storage medium can be, for example, but not limited to, an electrical storage device, a magnetic storage device, an optical storage device, an electromagnetic storage device, a semiconductor storage device, or any combination thereof.

[0092] Example 3:

[0093] A second aspect of the present invention provides a processing device for implementing the prediction method for externally sourced anomalous formation high pressure provided in the first aspect of the present invention. The processing device can be a client-side processing device, such as a mobile phone, laptop, tablet computer, desktop computer, etc., to execute the prediction method for externally sourced anomalous formation high pressure provided in Embodiment 1.

[0094] The processing device includes a processor, a memory, a communication interface, and a bus. The processor, memory, and communication interface are connected via the bus to enable communication between them. The memory stores a computer program that can run on the processor. When the processor runs the computer program, it executes the prediction method for externally sourced anomalous formation high pressure provided in Embodiment 1.

[0095] Optionally, the memory may be high-speed random access memory (RAM), and may also include non-volatile memory, such as at least one disk storage device.

[0096] Optionally, the processor can be any type of general-purpose processor such as a central processing unit (CPU) or a digital signal processor (DSP), and there is no limitation on this.

[0097] It should be noted that the "and / or" in the text includes three options. Taking "A and / or B" as an example, it includes technical option A, technical option B, and technical option that satisfies both A and B.

[0098] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention, and not to limit them; although the present invention has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that modifications can still be made to the technical solutions described in the foregoing embodiments, or equivalent substitutions can be made to some of the technical features; and these modifications or substitutions do not cause the essence of the corresponding technical solutions to deviate from the spirit and scope of the technical solutions of the embodiments of the present invention.

Claims

1. A method for predicting anomalous formation high pressure from other sources, characterized in that, include: Collect well logging data, well logging interpretation results, and fluid sampling results from drilled wells. Well logging data includes P-wave transit time data, density curve data, and gamma data from drilled wells. Well logging interpretation results include porosity data from drilled wells. The P-wave time difference data is converted into P-wave velocity data using the following formula: ； In the formula, For longitudinal wave velocity; For P-wave time difference; Calculate the overlying strata pressure P using density curve data o ; Combined with the pressure P of the overlying strata o Based on the P-wave velocity data and the Eaton method formula below, calculate the formation pressure P1 and the formation pressure P2 before the shallow gas-bearing sand body connects to the deep gas-bearing sand body, which may be caused by fracture or drilling operations: ； In the formula, It is the hydrostatic pressure; This is a normal compaction trend line; Eaton Index; Using the seismic data inversion results, shallow gas-bearing sand bodies and deep gas-bearing sand bodies are characterized, and the volumes V1 and V2 of shallow gas-bearing sand bodies and deep gas-bearing sand bodies are obtained. Based on the volume V1 and porosity data of the shallow gas-bearing sand body, the pore size V of the shallow gas-bearing sand body is calculated. 1孔 Based on the volume V2 and porosity data of the deep gas-bearing sand body, the pore size V of the deep gas-bearing sand body is calculated. 2孔 ; Based on the pore size V of the shallow gas-bearing sand body 1孔 Given the gas density, calculate the mass m1 of gas contained in the shallow gas-bearing sand body, and then calculate the pore size V of the deep gas-bearing sand body. 2孔 Given the gas density, calculate the mass m2 of gas contained in the deep gas-bearing sand body; Based on the mass m1 of the gas contained in the shallow gas-bearing sand body, calculate the number of moles n1 of the gas contained in the shallow gas-bearing sand body; based on the mass m2 of the gas contained in the deep gas-bearing sand body, calculate the number of moles n2 of the gas contained in the deep gas-bearing sand body. Calculate the hydrostatic pressure P at the location of the shallow gas-bearing sand body. 静1 The hydrostatic pressure P at the location of the deep gas-bearing sand body 静2 ; Based on the formation pressure P1 before the shallow gas-bearing sand body connects, the formation pressure P2 before the deep gas-bearing sand body connects, and the hydrostatic pressure P at the location of the shallow gas-bearing sand body. 静1 The hydrostatic pressure P at the location of the deep gas-bearing sand body 静2 The formation pressure P of the shallow gas-bearing sand body after connection due to fracture or drilling operations is calculated using the following formula, based on the number of moles of gas contained in the shallow gas-bearing sand body n1 and the number of moles of gas contained in the deep gas-bearing sand body n2. 11 and deep gas-bearing sandstone formation pressure P 22 : ； 。 2. The method for predicting anomalous formation high pressure from other sources according to claim 1, characterized in that, Check the quality of the collected logging curve data. If problems are found, carry out logging curve editing and correction work, which includes logging curve data depth correction, splicing, consistency processing and outlier correction.

3. The method for predicting anomalous formation high pressure from other sources according to claim 1, characterized in that, The pressure P of the overlying strata is calculated using the following formula. o : ； In the formula, The depth of the overlying rock strata; The density of the overlying rock layer at depth H; This is the acceleration due to gravity.

4. The method for predicting anomalous formation high pressure from other sources according to claim 3, characterized in that, The pore size V of shallow gas-bearing sand bodies can be calculated using the following formula. 1孔 Pore ​​size V of deep gas-bearing sand bodies 2孔 : ； In the formula, The volume of the gas-bearing sand body; Porosity of gas-bearing sand bodies.

5. The method for predicting anomalous formation high pressure from other sources according to claim 4, characterized in that, Calculate the mass m1 of gas contained in shallow gas-bearing sand bodies and the mass m2 of gas contained in deep gas-bearing sand bodies using the following formulas: ； In the formula, The pore size of the gas-bearing sand body; The density is the gas density.

6. The method for predicting anomalous formation high pressure from other sources according to claim 5, characterized in that, Calculate the number of moles of gas in shallow gas-bearing sand bodies, n1, and the number of moles of gas in deep gas-bearing sand bodies, n2, using the following formulas: In the formula, The mass of the gas; It is the molar mass.

7. The method for predicting anomalous formation high pressure from other sources according to claim 6, characterized in that, Calculate the hydrostatic pressure P at the location of the shallow gas-bearing sand body using the following formula. 静1 The hydrostatic pressure P at the location of the deep gas-bearing sand body 静2 : In the formula, Density of formation water; For depth.

8. A computer-readable storage medium storing a computer program, characterized in that, When the computer program is executed by a processor, it implements the steps of the method for predicting externally sourced anomalous formation high pressure as described in any one of claims 1 to 7.

9. 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 steps of the prediction method for externally sourced anomalous formation high pressure as described in any one of claims 1-7.

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