Method and product for predicting amplitude of formation pressure in front of drill bit in pressure relief zone

Abstract

The invention provides a method and a product for predicting the pressure amplitude of a formation in front of a drill bit in a pressure relief zone, belongs to the technical field of oil drilling, and aims to solve the problems that traditional formation pressure prediction lacks an accurate mathematical model and prediction algorithm and cannot comprehensively consider the complex relationship between geological and formation parameters. The method comprises the following steps: acquiring a cap reservoir pressure amplitude Cp of an adjacent well of a geological block, a vertical distance z from a cap stratum to the top of a reservoir, and a pressure amplitude Fp of the cap reservoir before pressure relief at the vertical distance z; determining a pressure relief coefficient M of the geological block; and utilizing the formation pressure amplitude prediction model and the pressure relief coefficient M to predict the pressure amplitude Cp'of the formation in front of the drill bit in the pressure relief zone of the current oil well. According to the calculation method for predicting the formation pressure amplitude of the sand body pressure relief layer in front of the drill bit based on the formation pressure amplitude of the drilled upper mudstone well section, the change trend of the formation pressure can be better captured, and a more accurate prediction result is provided.

Description

Technical Field

[0001] The present invention belongs to the technical field of oil drilling, and particularly relates to a method and product for predicting the formation pressure amplitude in front of the drill bit within a pressure relief zone. Background Art

[0002] In oil drilling engineering, accurately predicting the formation pressure in front of the drill bit is crucial because changes in formation pressure can lead to drilling accidents, damage equipment, and even endanger personnel safety. Therefore, the oil exploration field has been working hard to research and develop various methods for predicting formation pressure. Traditional formation pressure prediction methods mainly rely on parameters such as the physical properties of cores and cuttings, porosity, and permeability, and estimate formation pressure through geological interpretation and empirical formulas.

[0003] Although traditional formation pressure prediction methods have a certain degree of feasibility, they have the following problems: relying on limited laboratories, they may not cover all formation types and conditions. Lack of precise mathematical models and prediction algorithms, unable to comprehensively consider the complex relationships between geological and formation parameters. The accuracy of prediction results is affected by subjective factors in geological interpretation, with a certain degree of subjectivity and uncertainty.

[0004] Patent CN118151233A discloses a method and device for predicting formation pore pressure in a fracture structure zone. This formation pore pressure prediction method divides the fracture structure zone without drilling into two types of prediction areas, namely a pressure relief fracture development area and a non-pressure relief area, through fault classification. For the non-pressure relief area, seismic layer velocity modeling is used to obtain the pressure prediction result of this prediction area; for the pressure relief fracture development area, a mathematical model is established through seismic attributes to calculate the formation pressure; finally, the two are fused to provide the final pressure prediction result. This method is designed based on the characteristics of the fracture structure zone, improving the pressure prediction accuracy of the fracture structure zone in areas without drilling or with few wells, and providing an important reference basis for wellbore structure design and determination of drilling fluid density.

[0005] However, in this patent, for the non-pressure relief area, the Eaton method is still used for formation pore pressure prediction. Although the prediction result of the Eaton method is relatively accurate and applicable to various types of formations. Its applicable range is limited, and for formations with complex pore structures and fluid properties, the prediction result may be affected.

[0006] Therefore, it has become extremely urgent to propose a formation pressure prediction model that can cover all formation types and conditions, has precise mathematical models and prediction algorithms, comprehensively considers the complex relationships between geological and formation parameters, and the accuracy of prediction results is not affected by subjective factors in geological interpretation. Summary of the Invention

[0007] In order to more accurately predict the formation pressure in front of the drill bit, this paper proposes a calculation method for predicting the formation pressure amplitude of the sand body pressure relief layer in front of the drill bit based on the formation pressure amplitude of the upper mudstone section that has been drilled.

[0008] For the prediction of the formation pressure amplitude in front of the drill bit, one is to refer to the relevant data of adjacent wells in this geological block, and the other is to use the seismic data of this area. Seismic exploration mainly uses P-wave data, and its propagation speed is affected by various factors such as rock type, geological age, burial depth, and structure. Different rock types have different wave velocities, but the main factor affecting the wave velocity is the rock structure. Since the rock density is inversely proportional to the porosity, the seismic wave velocity is directly proportional to the rock density.

[0009] Starting from the formation mechanism of pressure relief type high pressure, this application establishes a prediction model for the formation pressure amplitude in front of the drill bit within the pressure relief zone.

[0010] To achieve the above object, the technical solution adopted by the present invention is as follows:

[0011] An object of the present invention is to provide a method for predicting the formation pressure amplitude in front of the drill bit within the pressure relief zone, including:

[0012] Obtain the caprock-reservoir pressure amplitude C of adjacent wells in this geological block p , the vertical distance z from the caprock to the top of the reservoir, and the caprock-reservoir pressure amplitude F before pressure relief at the vertical distance z, p , and substitute them into the formation pressure amplitude prediction model to determine the pressure relief coefficient M of this geological block;

[0013] Substitute the pressure relief coefficient M, the vertical distance z' from the caprock to the top of the reservoir, and the caprock-reservoir pressure amplitude F before pressure relief at the vertical distance z' p ', into the formation pressure amplitude prediction model to predict the formation pressure amplitude C in front of the drill bit within the pressure relief zone of the current oil well p ';

[0014] Among them, the caprock-reservoir pressure amplitude F before pressure relief p and the pressure relief coefficient M are only related to the geological block.

[0015] For further limitation of the above technical solution, the formation pressure amplitude prediction model is

[0016]

[0017] Among them, F p represents the caprock-reservoir pressure amplitude before pressure relief, with the unit of MPa; C p represents the formation pressure amplitude in front of the drill bit within the pressure relief zone or the caprock-reservoir pressure amplitude, with the unit of MPa; z represents the vertical distance from the caprock to the top of the reservoir, with the unit of m; M represents the pressure relief coefficient, which is related to the permeability, compressibility, porosity of the caprock-reservoir, and the pressure relief duration of the caprock.

[0018] For further limitation of the above technical solution, the determination of the pressure relief coefficient M of the local geological block includes:

[0019] Define the product of the parameter λ and the parameter t of the formation pressure amplitude prediction model as the model pressure relief coefficient M, that is: c

[0020] M = λt c

[0021] Where λ represents a coefficient related to the permeability, compressibility, and porosity of the caprock-reservoir; t c represents the duration of pressure relief of the caprock;

[0022] Compare the theoretical calculation curve of the pressure relief coefficient M with the measured data, and determine the model pressure relief coefficient M when it meets the preset fitting range.

[0023] For further limitation of the above technical solution, the vertical distance z from the caprock of the current oil well to the top of the reservoir is

[0024] z = z0 - h

[0025] Where z0 represents the depth from the ground to the top of the reservoir obtained from the seismic data of the local geological block, and h represents the drilled depth of the current oil well.

[0026] Another object of the present invention is to provide a system for predicting the formation pressure amplitude in front of the drill bit within the pressure relief zone, including:

[0027] A model parameter acquisition module for determining the pressure relief coefficient M of the local geological block according to the caprock-reservoir pressure amplitude C p of adjacent wells in the local geological block, the vertical distance z from the caprock to the top of the reservoir, and the caprock-reservoir pressure amplitude F p before pressure relief at the vertical distance z;

[0028] A formation pressure prediction module for predicting the formation pressure amplitude C p ' in front of the drill bit within the pressure relief zone of the current oil well according to the pressure relief coefficient M, the vertical distance z' from the caprock to the top of the reservoir, and the caprock-reservoir pressure amplitude F p ' before pressure relief at the vertical distance z'.

[0029] Yet another object of the present invention is to provide an electronic device, including:

[0030] One or more processors;

[0031] A storage device for storing one or more programs,

[0032] ​Wherein, when one or more programs are executed by one or more processors, the one or more processors are caused to execute the method as described above.

[0033] Another object of the present invention is to provide a computer-readable storage medium having executable instructions stored thereon, which, when executed by a processor, implement the method as described above.

[0034] Still another object of the present invention is to provide a computer program product including a computer program, which, when executed by a processor, implements the method as described above.

[0035] Compared with the prior art, the beneficial effects of the present invention are:

[0036] This method refers to the relevant data of adjacent wells in this geological block and the seismic data of this area, and starting from the formation mechanism of pressure relief type high pressure, a prediction model of the formation pressure amplitude in front of the drill bit in the pressure relief zone is established to quickly, accurately and procedurally predict the formation pressure amplitude of the sand body pressure relief layer in front of the drill bit. According to this method, the change trend of the formation pressure can be better captured, and more accurate prediction results can be provided. It reduces unnecessary losses of manpower and material resources for the drilling engineering. BRIEF DESCRIPTION OF THE DRAWINGS

[0037] In order to more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the following will briefly introduce the drawings required for the description of the embodiments or the prior art. Obviously, the following drawings are only some embodiments of the present invention. For those of ordinary skill in the art, other drawings can be obtained based on these drawings without creative efforts.

[0038] Figure 1 It is a flowchart of a method for predicting the formation pressure amplitude in front of the drill bit in a pressure relief zone of the present invention.

[0039] Figure 2 It is a comparison chart of the theoretical calculation data of the formation pressure predicted by the formation pressure amplitude prediction model of the present invention and the well logging interpretation data in the same block.

[0040] Figure 3 (a) It is a comparison chart of the theoretical calculation data of the formation pressure predicted by the formation pressure amplitude prediction model of the present invention and different well logging interpretation data in the same block.

[0041] Figure 3 (b) It is the theoretical calculation data of the formation pressure predicted by the formation pressure amplitude prediction model of the present invention.

[0042] Figure 4 It is a comparison chart of the theoretical calculation data of the formation pressure predicted by the formation pressure amplitude prediction model of the present invention and the measured value of the formation pressure during the drilling of the current oil well in the same block.

[0043] Figure 5 This is the on-site construction case diagram of the prediction model of the present invention. Detailed implementation manners

[0044] The present invention will be further described below in conjunction with specific embodiments. It should be understood that these embodiments are only used to illustrate the present invention and not to limit the scope of the present invention. In addition, it should be understood that after reading the content taught by the present invention, those skilled in the art make various changes or modifications to the present invention, and these equivalent forms also fall within the scope defined by the appended claims of this application.

[0045] Embodiment 1

[0046] Traditional formation pressure prediction methods mainly rely on parameters such as the physical properties of cores and cuttings, porosity and permeability, and estimate formation pressure through geological interpretation and empirical formulas. Although traditional formation pressure prediction methods have a certain degree of feasibility, there are the following problems: relying on limited laboratories, they may not be able to cover all formation types and conditions. Lack of accurate mathematical models and prediction algorithms, unable to comprehensively consider the complex relationships between geological and formation parameters. The accuracy of prediction results is affected by the subjective factors of geological interpretation, and there is a certain degree of subjectivity and uncertainty.

[0047] In order to more accurately predict the formation pressure in front of the drill bit, this application proposes a calculation method for predicting the formation pressure amplitude of the sand body pressure relief layer in front of the drill bit based on the formation pressure amplitude of the upper mudstone section that has been drilled.

[0048] For the prediction of the formation pressure amplitude in front of the drill bit, one is to refer to the relevant data of adjacent wells in this geological block, and the other is to use the seismic data of this area. Seismic exploration mainly uses P-wave data, and its propagation speed is affected by various factors such as rock type, geological age, burial depth, and structure. Different rock types have different wave velocities, but the main factor affecting wave velocity is rock structure. Since the rock density is inversely proportional to the porosity, the seismic wave velocity is proportional to the rock density.

[0049] This application starts from the formation mechanism of pressure-relief type high pressure and establishes a prediction model for the formation pressure amplitude in front of the drill bit in the pressure relief zone.

[0050] The model construction process of the present invention is as follows:

[0051] Assume that during the reservoir pressure relief process, the reservoir pressure decreases linearly with time. Therefore, the transient pore pressure of the caprock can be described by the radial flow equation of the fluid:

[0052]

[0053] Among them, P represents the formation pore pressure; Z represents the vertical distance from the caprock of the oil well to the top of the reservoir; represents porosity; μ represents the viscosity of the fluid in the pores; c, c1 represent the compressibility; k represents the permeability; t represents time.

[0054] When t = 0, the pore pressure of the caprock is the pore pressure before pressure relief, i.e.:

[0055] p = p i , 0 < z < ∞, t = 0

[0056] where, P represents the formation pore pressure; P i represents the caprock pressure before pressure relief.

[0057] When t > 0, the pore pressure of the caprock changes linearly, i.e.:

[0058]

[0059] where, P i represents the caprock pressure before pressure relief; P represents the current caprock pressure or the shale pressure at a vertical distance of z; t c represents the duration of caprock pressure relief; p r represents the reservoir pressure.

[0060] Therefore, when z = 0, the shale pressure at a vertical distance of z is:

[0061]

[0062] Combining the above equations and letting M = λt c , F p = p i - p, C p = p i - p r , the formation pressure amplitude prediction model is obtained as:

[0063]

[0064] As Figure 1 shown, an embodiment of the present invention provides a method for predicting the formation pressure amplitude in front of the drill bit in the pressure relief zone, including:

[0065] Obtain the caprock-reservoir pressure amplitudes C p , the vertical distance z from the caprock to the top of the reservoir, and the caprock-reservoir pressure amplitudes F p before pressure relief at a vertical distance of z in adjacent wells of the local geological block;

[0066] Substitute the above parameters into the formation pressure amplitude prediction model to determine the pressure relief coefficient M of the local geological block;

[0067] The pressure relief coefficient M, the vertical distance z' from the cap rock to the top of the reservoir, and the pressure amplitude F of the cap rock before the pressure relief at the vertical distance z' are calculated. p ', substitute it into the formation pressure amplitude prediction model to predict the formation pressure amplitude C in front of the drill bit in the pressure relief zone of the current oil well p ';

[0068] Among them, the pressure amplitude of the reservoir before pressure relief is F p and the pressure relief coefficient M are only related to the geological block.

[0069] In this embodiment, the pressure amplitude of the reservoir before pressure relief is F p The pressure relief coefficient M is only related to the geological block. Under the same formation system, the user only needs to determine the pressure relief coefficient M based on the adjacent wells to use the formation pressure amplitude prediction model of the present application to predict the formation pressure amplitude.

[0070] In an embodiment of the present invention, the formation pressure amplitude prediction model is:

[0071]

[0072] Among them, F p Indicates the pressure amplitude of the reservoir before pressure relief, in MPa; C p It represents the formation pressure amplitude in front of the drill bit in the pressure relief zone or the caprock pressure amplitude, in MPa; z represents the vertical distance from the caprock to the top of the reservoir, in m; M represents the pressure relief coefficient, which is related to the permeability, compressibility, porosity of the reservoir caprock and the duration of caprock pressure relief.

[0073] This application refers to the relevant data of neighboring wells in the local geological block and the seismic data in the area. Starting from the formation mechanism of pressure relief type high pressure, a prediction model for the formation pressure amplitude in front of the drill bit in the pressure relief zone is established to quickly, accurately and process-based predict the formation pressure amplitude in the sand body pressure relief layer in front of the drill bit. According to this method, the changing trend of formation pressure can be better captured and more accurate prediction results can be provided. It can reduce unnecessary manpower and material losses for drilling projects.

[0074] In an embodiment of the present invention, determining the local geological block pressure relief coefficient M includes:

[0075] The parameters λ and t of the formation pressure amplitude prediction model are c The product of is defined as the model pressure relief coefficient M, that is:

[0076] M=λt c

[0077] Where, λ represents the coefficient related to the permeability, compressibility and porosity of the reservoir caprock; t c Indicates the duration of caprock pressure relief;

[0078] Compare the theoretically calculated curve of the pressure relief coefficient M with the measured data, and determine the pressure relief coefficient M when it falls within the preset fitting range.

[0079] In this embodiment, compare the theoretically calculated curve of the model pressure relief coefficient M with the measured data such as well logging interpretation data or measured pressure data, and determine the pressure relief coefficient M when the overall error is minimized.

[0080] This application defines the product of parameter λ and parameter t c as the model pressure relief coefficient M. Considering the physical properties of the caprock and reservoir and the influence of the pressure relief time, treating the two parameters as a whole can simplify the model, making it easier to understand and process, and helping to more intuitively display the changing trends and laws of data in charts or models.

[0081] In the embodiment of the present invention, the vertical distance z from the caprock of the current oil well to the top of the reservoir is

[0082] z = z0 - h

[0083] where z0 represents the depth from the ground to the top of the reservoir obtained from the seismic data of the local geological block, and h represents the drilled depth of the current oil well.

[0084] In this embodiment, the positive direction of z is towards the ground, that is, the bottom of the sand body is at a distance of 0, and the predicted result depth is targeted at the distance from the bottom of the pressure relief sand body.

[0085] The embodiment of the present invention provides a system for predicting the formation pressure amplitude in front of the drill bit within the pressure relief zone, including:

[0086] A model parameter acquisition module, configured to determine the pressure relief coefficient M of the local geological block according to the caprock and reservoir pressure amplitudes C p , the vertical distance z from the caprock to the top of the reservoir, and the caprock and reservoir pressure amplitude F before pressure relief at the vertical distance z p ;

[0087] A formation pressure prediction module, configured to predict the formation pressure amplitude C p ' in front of the drill bit within the pressure relief zone of the current oil well according to the pressure relief coefficient M, the vertical distance z' from the caprock to the top of the reservoir, and the caprock and reservoir pressure amplitude F p ' before pressure relief at the vertical distance z'.

[0088] The embodiment of the present invention also provides an electronic device, including: one or more processors; a storage device for storing one or more programs, wherein when the one or more programs are executed by the one or more processors, the one or more processors are caused to execute the above method.

[0089] Embodiments of the present invention also provide a computer-readable storage medium, on which executable instructions are stored. When the instructions are executed by a processor, the above-mentioned method is implemented.

[0090] Embodiments of the present invention also provide a computer program product, including a computer program. When the computer program is executed by a processor, the above-mentioned method is implemented.

[0091] In the pressure relief zone, the accuracy of formation pressure prediction is particularly important. Because abnormal pressures often exist in the pressure relief zone, and these abnormal pressures may lead to complex situations and safety accidents during the drilling process. Therefore, by using the formation pressure amplitude prediction model in front of the drill bit in the pressure relief zone provided by this application to accurately predict the formation pressure in front of the drill bit, important reference information can be provided for drilling engineers to guide safe and efficient drilling operations.

[0092] Embodiment 2

[0093] This embodiment further describes the present invention in conjunction with the accompanying drawings.

[0094] According to the logging data of the drilled wells or drilled well sections in the local geological block, obtain the reservoir pressure p r and shale pressure p of the adjacent wells in the local geological block, as Figure 2 shown.

[0095] Figure 2 In, the blue solid line represents the logging interpretation data, and the orange solid line represents the theoretical calculation data. Figure 2 The abscissa represents the pressure coefficient, and the ordinate represents the drilled depth h of the current oil well. It can be seen from Figure 2 that by using the formation pressure amplitude prediction model of the present invention, the theoretical calculation data of predicting the formation pressure p r ' of the pressure relief layer of the current oil well is highly fitted with the logging interpretation data.

[0096] According to the cap-rock reservoir pressure amplitude C p , the vertical distance z from the cap rock to the top of the reservoir, and the cap-rock reservoir pressure amplitude F p before pressure relief at the vertical distance z in the local geological block, determine the pressure relief coefficient M of the local geological block and calculate the pressure relief coefficient M.

[0097] The formation pressure amplitude prediction model is

[0098]

[0099] Among them, F p represents the cap-rock reservoir pressure amplitude before pressure relief, with the unit of MPa; C pIt represents the formation pressure amplitude or the cap-rock / reservoir pressure amplitude in front of the drill bit within the pressure relief zone, with the unit of MPa; z represents the vertical distance from the cap-rock to the top of the reservoir, with the unit of m; M represents the pressure relief coefficient, which is related to the permeability, compressibility, porosity of the cap-rock / reservoir and the pressure relief duration of the cap-rock.

[0100] When using this model, consider λt c as a whole. When the theoretical calculation curve and the measured data achieve the best fit, the pressure relief coefficient M of this geological block can be determined.

[0101] Figure 3 (a) is a comparison chart of the well logging interpretation data of different well logs in this geological block and the theoretical calculation data of this application. Combining Figure 3 with the state performance of a, the theoretical calculation data of this application also highly fits the interpretation data of different well logs in this geological block.

[0102] Figure 3 (b) is the formation pressure amplitude prediction model of the present invention, predicting the theoretical calculation data of the pressure p' of the pressure relief layer of the oil well in this geological block. r '

[0103] As Figure 4 shown, for the current well section, after determining the pressure relief coefficient M, during the drilling process, the shale pressure p' at the vertical distance z', the cap-rock pressure p i before pressure relief, the vertical distance z' from the cap-rock to the top of the reservoir of the current oil well, combined with the determined pressure relief coefficient M, use the formation pressure amplitude prediction model to predict the formation pressure p r ' in front of the drill bit within the pressure relief zone of the current oil well. The prediction result is Figure 4 the black solid line, Figure 4 the cross marks in it are the measured pressure values during the drilling of the current well section. According to Figure 4 it is easy to obtain that the prediction value of the formation pressure amplitude prediction model of the present invention highly coincides with the measured value.

[0104] As Figure 5 shown, for the current well section, when drilling to 3685m, the overlying shale layer starts to relieve pressure, and the sand body pressure relief layer section is from 3725 to 3751m; when drilling to 3751m, the two overlying shale layers start to relieve pressure, and the sand body pressure relief layer section of the two sections is from 3760 to 3800m. The red line segment in the figure is the mud density curve, the prediction result is the dotted line marked by the predicted value in the figure, the black solid line is the formation pore pressure calculated by the Eaton method, and the yellow dots are the measured pressure values at this point. According to Figure 5 it is easy to obtain that the pressure amplitude prediction model of the present invention has higher accuracy than the traditional reservoir pressure calculation method and can better predict the reservoir pressure.

[0105] The above content is a further detailed description of the present invention in combination with specific preferred implementation schemes, which is convenient for those skilled in the art of this technology to understand and apply the present invention. It cannot be determined that the specific implementation of the present invention is only limited to these descriptions. For those of ordinary skill in the technical field to which the present invention pertains, without departing from the concept of the present invention, several simple deductions or substitutions can be made without the need for creative labor. Therefore, any simple improvements made by those skilled in the art based on the disclosure of the present invention should be within the protection scope of the present invention.

Claims

1. A method for predicting the formation pressure amplitude in front of the bit within a pressure relief zone, characterized in that, including: Obtain the caprock-reservoir pressure amplitude C of adjacent wells in the local geological block p , the vertical distance z from the caprock to the top of the reservoir, and the caprock-reservoir pressure amplitude F before pressure relief at the vertical distance z p , and substitute them into the formation pressure amplitude prediction model to determine the pressure relief coefficient M of the local geological block; Substitute the pressure relief coefficient M, the vertical distance z' from the caprock to the top of the reservoir, and the pressure amplitude F of the caprock-reservoir before pressure relief at the vertical distance z' into the formation pressure amplitude prediction model to predict the formation pressure amplitude C' in front of the drill bit within the pressure relief zone of the current oil well p '; p '; Among them, the reservoir pressure amplitude F of the pressure relief front cover p and the pressure relief coefficient M are only related to the geological block.

2. The method for predicting the formation pressure amplitude in front of the drill bit inside the pressure relief belt according to claim 1, characterized in that, The formation pressure amplitude prediction model is: Among them, F p represents the reservoir pressure amplitude of the pressure relief front cover, with the unit of MPa; C p represents the formation pressure amplitude in front of the drill bit or the reservoir pressure amplitude in the pressure relief zone, with the unit of MPa; z represents the vertical distance from the caprock to the top of the reservoir, with the unit of m; M represents the pressure relief coefficient, which is related to the permeability, compressibility, porosity of the reservoir-caprock and the pressure relief duration of the caprock.

3. The method for predicting the formation pressure amplitude in front of the drill bit within the pressure relief zone according to claim 1, characterized in that The determination of the pressure relief coefficient M of the local geological block includes: Define the product of the parameters λ and t of the formation pressure amplitude prediction model c as the pressure relief coefficient M, i.e.: M = λt c where λ represents a coefficient related to the permeability, compressibility, and porosity of the reservoir-caprock; t c represents the duration of caprock pressure relief; Compare the theoretical calculation curve of the pressure relief coefficient M with the measured data, and determine the pressure relief coefficient M when it meets the preset fitting range.

4. The method for predicting the formation pressure amplitude in front of the bit within the pressure relief zone according to claim 1, characterized in that, The vertical distance z from the caprock to the top of the reservoir of the current oil well is z = z0 - h where z0 represents the depth from the ground to the top of the reservoir obtained from the seismic data of the local geological block, and h represents the drilled depth of the current oil well.

5. A system for predicting the formation pressure amplitude in front of the drill bit in a pressure relief zone, including: A model parameter acquisition module, which is used to determine the pressure relief coefficient M of the local geological block according to the caprock-reservoir pressure amplitude C of adjacent wells in the local geological block p , the vertical distance z from the caprock to the top of the reservoir, and the caprock-reservoir pressure amplitude F before pressure relief at the vertical distance z p , and determine the pressure relief coefficient M of the local geological block; A formation pressure prediction module, which is used to predict the formation pressure amplitude C p ' in front of the drill bit within the pressure relief zone of the current oil well according to the pressure relief coefficient M, the vertical distance z' from the caprock to the top of the reservoir, and the pressure amplitude F p ' between the caprock and the reservoir at the vertical distance z'.

6. An electronic device, including: One or more processors; A storage device for storing one or more programs, wherein, when the one or more programs are executed by the one or more processors, the one or more processors execute the method according to any one of claims 1 to 5.

7. A computer-readable storage medium, on which executable instructions are stored, and when the instructions are executed by a processor, the method according to any one of claims 1 to 5 is implemented.

8. A computer program product, including a computer program, and when the computer program is executed by a processor, the method according to any one of claims 1 to 5 is implemented.

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