Drilling scheme selection method and apparatus based on three-dimensional seismic data

Abstract

The present application provides a drilling scheme selection method and apparatus based on three-dimensional seismic data. The corresponding method comprises: determining formation elasticity parameters of a target work area on the basis of three-dimensional seismic data and logging data of the target work area; on the basis of the formation elasticity parameters, determining overburden pressure at each depth in the target work area; on the basis of the logging data, the formation elasticity parameters, and the overburden pressure, respectively determining first pore pressure of a first formation in which abnormally high pressure is formed by a compaction mechanism and second pore pressure of a second formation in which abnormally high pressure is formed by a non-compaction mechanism; and on the basis of the formation elasticity parameters, the overburden pressure and the second pore pressure, determining a formation pore pressure coefficient, a collapse pressure coefficient and a fracture pressure coefficient of the second formation, to select a drilling scheme.

Description

Drilling plan selection method and device based on three-dimensional seismic data

[0001] Related Applications

[0002] This application claims priority to the Chinese patent application No. 202411246662.7, filed on September 05, 2024, and incorporates the disclosure of the above patent application as part of this application. TECHNICAL FIELD

[0003] The present application belongs to the technical field of oil and gas seismic exploration and development, and specifically relates to a drilling plan selection method and device based on three-dimensional seismic data. BACKGROUND

[0004] With the development of oil and gas exploration and development, deep and ultra-deep oil and gas reservoirs have gradually become an important field for increasing reserves and production. However, there are relatively few deep and ultra-deep wells, and direct data on deep and ultra-deep formations in various basins are relatively scarce. For example, the Sichuan Basin and the Tarim Basin have experienced multiple tectonic movements, and the underground geological conditions are complex. Deep and ultra-deep wells will encounter multiple formations and pressure systems, and changes in formation lithology and pressure systems can easily cause engineering risks such as blowout, lost circulation, and wellbore collapse. Therefore, the design of wellbore structure and the determination of drilling fluid safety window for deep and ultra-deep wells need to be supported by formation pore pressure coefficient, collapse pressure coefficient, and fracture pressure coefficient (three pressure coefficients).

[0005] In the prior art, the three pressure coefficients are generally predicted by the following two methods based on existing wellbore data (measured pressure data, core test data, drilling fluid density, logging data, etc.):

[0006] First, the three pressure coefficients obtained from the data of multiple adjacent wells are used to constrain the prediction of the three pressure coefficients of the well to be drilled.

[0007] Second, a three-dimensional geological model is established, and the three pressure coefficients of the well to be drilled are calculated by numerical simulation with the mechanical data of existing wells in the area as the constraint condition.

[0008] The first method is not a quantitative prediction in the strict sense, but an empirical prediction. If the reference adjacent well and the well to be drilled are not in the same tectonic unit, or the interwell heterogeneity is strong, the accuracy of the three pressure coefficients determined based on them will be greatly affected. The second method mainly obtains the three pressure coefficients by numerical simulation through modeling, but the model precision is often low, making it difficult to accurately depict the actual formation characteristics, thus resulting in insufficient prediction accuracy. SUMMARY

[0009] One purpose of the present application is to provide a drilling scheme selection method based on three-dimensional seismic data to solve the technical problems in the prior art that the calculation results of the formation pore pressure coefficient, the collapse pressure coefficient and the fracture pressure coefficient are not accurate enough and cannot be quantitatively predicted.

[0010] Another purpose of the present application is to provide a drilling scheme selection device based on three-dimensional seismic data. Still another purpose of the present application is to provide an electronic device including a memory and a processor, the memory storing a computer program, and the processor implementing the steps of the above drilling scheme selection method based on three-dimensional seismic data when executing the computer program. Still another purpose of the present application is to provide a readable medium having a computer program stored thereon, and the computer program implements the steps of the above drilling scheme selection method based on three-dimensional seismic data when executed by a processor.

[0011] To solve the technical problems in the background art, the present application provides the following technical solutions:

[0012] In a first aspect, the present application provides a drilling scheme selection method based on three-dimensional seismic data, comprising:

[0013] determining formation elastic parameters of a target work area according to three-dimensional seismic data and logging data of the target work area;

[0014] determining overburden pressure at each depth in the target work area according to the formation elastic parameters;

[0015] determining first pore pressure of a first formation in which abnormal high pressure is formed by compaction mechanism and second pore pressure of a second formation in which abnormal high pressure is formed by non-compaction mechanism according to the logging data, the formation elastic parameters and the overburden pressure, respectively;

[0016] determining formation pore pressure coefficient, collapse pressure coefficient and fracture pressure coefficient of the first formation according to the formation elastic parameters, the overburden pressure and the first pore pressure; and

[0017] determining formation pore pressure coefficient, collapse pressure coefficient and fracture pressure coefficient of the second formation according to the formation elastic parameters, the overburden pressure and the second pore pressure, to select corresponding drilling schemes of the first formation and the second formation, respectively.

[0018] In a second aspect, the present application provides a drilling scheme selection device based on three-dimensional seismic data, comprising:

[0019] a formation elastic parameter determination module configured to determine formation elastic parameters of a target work area according to three-dimensional seismic data and logging data of the target work area;

[0020] an overburden pressure determining module configured to determine an overburden pressure at each depth in the target area according to the formation elastic parameters;

[0021] a pore pressure determining module configured to determine a first pore pressure of a first formation with abnormal high pressure formed by compaction mechanism and a second pore pressure of a second formation with abnormal high pressure formed by non-compaction mechanism according to the logging data, the formation elastic parameters and the overburden pressure respectively;

[0022] a three-coefficient determining first module configured to determine a formation pore pressure coefficient, a collapse pressure coefficient and a fracture pressure coefficient of the first formation according to the formation elastic parameters, the overburden pressure and the first pore pressure; and

[0023] a three-coefficient determining second module configured to determine a formation pore pressure coefficient, a collapse pressure coefficient and a fracture pressure coefficient of the second formation according to the formation elastic parameters, the overburden pressure and the second pore pressure, so as to select a corresponding drilling scheme for the first formation and the second formation respectively.

[0024] In a third aspect, the present application provides a computer program product, which comprises computer programs / instructions, and the computer programs / instructions are executed by a processor to implement the steps of the drilling scheme selection method based on three-dimensional seismic data.

[0025] In a fourth aspect, the present application provides an electronic device, which comprises a memory, a processor and a computer program stored in the memory and executable on the processor, and the processor executes the program to implement the steps of the drilling scheme selection method based on three-dimensional seismic data.

[0026] In a fifth aspect, the present application provides a computer readable storage medium, which stores a computer program, and the computer program is executed by a processor to implement the steps of the drilling scheme selection method based on three-dimensional seismic data.

[0027] From the above description, the drilling scheme selection method and device based on three-dimensional seismic data provided by the embodiments of the present application are known. The corresponding drilling scheme selection method based on three-dimensional seismic data comprises the following steps. First, the formation elastic parameters of a target work area are determined according to the three-dimensional seismic data and the logging data of the target work area. The overburden pressure at each depth in the target work area is determined according to the formation elastic parameters. Then, the first pore pressure of a first formation in which abnormal high pressure is formed by a compaction mechanism and the second pore pressure of a second formation in which abnormal high pressure is formed by a non-compaction mechanism are determined according to the logging data, the formation elastic parameters and the overburden pressure. The formation pore pressure coefficient, the collapse pressure coefficient and the fracture pressure coefficient of the first formation are determined according to the formation elastic parameters, the overburden pressure and the first pore pressure. Finally, the formation pore pressure coefficient, the collapse pressure coefficient and the fracture pressure coefficient of the second formation are determined according to the formation elastic parameters, the overburden pressure and the second pore pressure, so as to select the corresponding drilling scheme of the first formation and the second formation, respectively.

[0028] The present application can accurately obtain the distribution of three pressure coefficients in the three-dimensional underground space, so as to help carry out reservoir evaluation and support the design of wellbore structure and drilling fluid density window. BRIEF DESCRIPTION OF DRAWINGS

[0029] In order to more clearly illustrate the technical solutions in the embodiments of the present application or the prior art, the drawings needed to be used in the embodiments or the prior art description will be briefly introduced. Obviously, the drawings in the following description are some embodiments of the present application, and other drawings can also be obtained by those skilled in the art without any creative effort.

[0030] FIG. 1 is a flow diagram of the drilling scheme selection method based on three-dimensional seismic data in the embodiments of the present application;

[0031] FIG. 2 is a flow diagram of step 300 of the drilling scheme selection method based on three-dimensional seismic data in the embodiments of the present application;

[0032] FIG. 3 is a flow diagram of step 300 of the drilling scheme selection method based on three-dimensional seismic data in the embodiments of the present application;

[0033] FIG. 4 is a flow diagram of step 100 of the drilling scheme selection method based on three-dimensional seismic data in the embodiments of the present application;

[0034] FIG. 5 is a flow diagram of step 400 of the drilling scheme selection method based on three-dimensional seismic data in the embodiments of the present application;

[0035] FIG. 6 is a flow diagram of step 500 of the drilling scheme selection method based on three-dimensional seismic data in the embodiments of the present application;

[0036] Fig. 7 is a flowchart of a method for selecting a drilling plan based on three-dimensional seismic data according to an embodiment of the present application;

[0037] Fig. 8 is a flowchart of a method for selecting a drilling plan based on three-dimensional seismic data according to an embodiment of the present application;

[0038] Fig. 9 is a logic diagram of a method for selecting a drilling plan based on three-dimensional seismic data according to an embodiment of the present application;

[0039] Fig. 10 is a three-dimensional pore pressure coefficient volume predicted according to an embodiment of the present application;

[0040] Fig. 11 is a three-dimensional fracture pressure coefficient volume predicted according to an embodiment of the present application;

[0041] Fig. 12 is a three-dimensional collapse pressure coefficient volume predicted according to an embodiment of the present application;

[0042] Fig. 13 is a block diagram of a device for selecting a drilling plan based on three-dimensional seismic data according to an embodiment of the present application;

[0043] Fig. 14 is a block diagram of a pore pressure determination module 30 according to an embodiment of the present application;

[0044] Fig. 15 is a block diagram of a pore pressure determination module 30 according to an embodiment of the present application;

[0045] Fig. 16 is a block diagram of a formation elastic parameter determination module 10 according to an embodiment of the present application;

[0046] Fig. 17 is a block diagram of a three-coefficient determination first module 40 according to an embodiment of the present application;

[0047] Fig. 18 is a block diagram of a three-coefficient determination second module 50 according to an embodiment of the present application;

[0048] Fig. 19 is a block diagram of a device for selecting a drilling plan based on three-dimensional seismic data according to an embodiment of the present application;

[0049] Fig. 20 is a structural diagram of an electronic device according to an embodiment of the present application. DETAILED DESCRIPTION

[0050] In order to make the objectives, technical solutions, and superiorities of the embodiments of the present application clearer, the following will be combined with the accompanying drawings for the embodiments of the present application to make a clear and complete description of the technical solutions in the embodiments of the present application. Obviously, the described embodiments are some but not all of the embodiments of the present application. Based on the embodiments in the present application, all other embodiments obtained by those of ordinary skill in the art without creative work fall within the scope of the present application.

[0051] Those skilled in the art will understand that embodiments of this application can be provided as methods, systems, or computer program products. Therefore, this application can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, this application can take the form of a computer program product embodied on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0052] It should be noted that the terms "comprising" and "having," and any variations thereof, in the specification, claims, and accompanying drawings of this application are intended to cover non-exclusive inclusion. For example, a process, method, system, product, or apparatus that includes a series of steps or units is not necessarily limited to those explicitly listed, but may include other steps or units not explicitly listed or inherent to these processes, methods, products, or apparatuses. Without conflict, the embodiments and features in the embodiments of this application can be combined with each other. This application will now be described in detail with reference to the accompanying drawings and embodiments.

[0053] The acquisition, storage, use, and processing of data in this application comply with relevant laws and regulations.

[0054] To address the technical challenges described in the background section of this application, embodiments of this application provide a specific implementation of a drilling scheme selection method based on 3D seismic data. Referring to Figure 1, the drilling scheme selection method based on 3D seismic data specifically includes the following:

[0055] Step 100: Determine the formation elastic parameters of the target work area based on the 3D seismic data and well logging data of the target work area;

[0056] Step 200: Determine the overlying formation pressure at each depth within the target work area based on the formation elastic parameters;

[0057] Step 300: Based on well logging data, formation elastic parameters, and overlying formation pressure, determine the first pore pressure of the first formation where the abnormal high pressure is formed by a compaction mechanism and the second pore pressure of the second formation where the abnormal high pressure is formed by a non-compaction mechanism.

[0058] Step 400: Determine the formation pore pressure coefficient, collapse pressure coefficient, and fracture pressure coefficient of the first formation based on the formation elastic parameters, overlying formation pressure, and first pore pressure; and

[0059] Step 500: determining the formation pore pressure coefficient, the collapse pressure coefficient and the fracture pressure coefficient of the second formation according to the formation elastic parameter, the overburden pressure and the second pore pressure, so as to select the corresponding drilling scheme of the first formation and the second formation respectively.

[0060] As can be seen from the above description, the drilling scheme selection method and device based on three-dimensional seismic data are provided, and the corresponding drilling scheme selection method based on three-dimensional seismic data comprises the following steps. First, the formation elastic parameter of a target work area is determined according to the three-dimensional seismic data and the logging data of the target work area. The overburden pressure at each depth in the target work area is determined according to the formation elastic parameter. Then, the first pore pressure of a first formation formed by compaction mechanism of abnormal high pressure and the second pore pressure of a second formation formed by non-compaction mechanism of abnormal high pressure are determined according to the logging data, the formation elastic parameter and the overburden pressure. The formation pore pressure coefficient, the collapse pressure coefficient and the fracture pressure coefficient of the first formation are determined according to the formation elastic parameter, the overburden pressure and the first pore pressure. Finally, the formation pore pressure coefficient, the collapse pressure coefficient and the fracture pressure coefficient of the second formation are determined according to the formation elastic parameter, the overburden pressure and the second pore pressure, so as to select the corresponding drilling scheme of the first formation and the second formation respectively.

[0061] The three-pressure coefficient data of the three-dimensional underground space can be accurately obtained, and the corresponding drilling scheme of the first formation and the second formation can be selected based on the three-pressure coefficient data corresponding to the first formation and the second formation respectively. Then, the drilling scheme is used for drilling well structure design and drilling fluid density window design, so as to better solve the three-pressure coefficient prediction problem of supporting pre-drilling drilling engineering design to avoid blowout, leakage and well wall collapse.

[0062] For step 100, the formation elastic parameter comprises formation density, P-wave velocity and S-wave velocity. It can be understood that the three-dimensional seismic data is a vibration signal obtained by reflection of an underground geological body, which carries formation information of the three-dimensional underground space and can more finely depict the characteristics of the underground formation with higher certainty, so as to effectively improve the accuracy of three-pressure coefficient prediction. The three-dimensional seismic data can be measured based on a sensor, and the sensor sends the three-dimensional seismic data to a server. The logging data can be measured based on a logging device, and the logging device sends the logging data to the server. The server determines the formation elastic parameter of the target work area according to the three-dimensional seismic data and the logging data of the target work area, and then executes the following steps.

[0063] For step 200, a formation density body is first generated according to the formation density in the formation elastic parameter, and then the gravity generated by the overburden at each depth along the vertical direction is integrated to obtain the overburden pressure at each depth.

[0064] Abnormally high pressure refers to the pressure in the formation that is greater than the normal hydrostatic pressure. The causes of abnormally high pressure are mainly divided into compaction mechanisms and non-compaction mechanisms.

[0065] Compaction mechanism is one of the most common causes of abnormally high pressure, the core of which is that the sediments gradually compress during the burial process due to the increase of sediment load, but due to certain reasons, the pore fluid pressure cannot be fully released, thus forming abnormally high pressure.

[0066] Normal compaction process: During the burial process of sediments, with the increase of sediment load, pore water in the sediments is gradually discharged, and sediment particles are close to each other, forming a dense formation. This compaction process is accompanied by the release of fluid pressure, resulting in the maintenance of pore pressure at the level of hydrostatic pressure.

[0067] Compaction mechanism of abnormally high pressure formation: When the sediments are compacted, if the pore fluid cannot be normally discharged (such as due to the sealing effect of low permeability mudstone or shale), the pore fluid pressure cannot be released synchronously with the sediment pressure, resulting in fluid pressure exceeding the normal hydrostatic pressure level. The area of such sediments that cannot fully drain will form abnormally high pressure. This abnormally high pressure is commonly found in young sedimentary basins, such as deltas and deep-sea basins, and mudstone and shale are the most common types of rock that cause insufficient compaction. With the continuous thickening of sediments, the abnormally high pressure caused by insufficient compaction gradually appears.

[0068] The causes of abnormally high pressure caused by non-compaction mechanism are more complex, usually related to other physical and chemical processes in geological processes. Non-compaction mechanisms include:

[0069] Fluid generation: In the formation, due to the thermal maturation of organic matter, a large amount of fluid (such as oil, natural gas and water) is generated, which cannot escape in time, resulting in an increase in fluid pressure and the formation of abnormally high pressure. For example, when organic matter decomposes at a certain temperature and pressure, it generates oil or natural gas, and the increase in volume of these fluids will significantly increase the fluid pressure in the formation.

[0070] Clay mineral dehydration: Under certain temperature and pressure conditions, some minerals in the formation (such as montmorillonite) undergo dehydration, releasing water that is trapped in the formation and cannot be discharged in time, resulting in the formation of abnormally high pressure. This process usually occurs in deeply buried formations, especially in sedimentary rocks containing a large amount of clay.

[0071] Salt gypsum or salt rock expansion: Salt rock has good plasticity and fluidity. When salt rock is subjected to formation pressure, it may expand and extrude upward (forming salt dome), causing abnormally high pressure in the surrounding formation. This abnormally high pressure is closely related to the fluidity of salt rock and geological movement.

[0072] Fault sealing: The formation and activity of faults can have an impact on the flow of fluids. When a fault acts as a seal, it can block the escape of fluids, leading to the gradual accumulation of fluid pressure, forming abnormal high pressure. Abnormal high pressure caused by fault sealing is commonly found in complex structural oil and gas fields.

[0073] Tectonic stress: Tectonic movements of the Earth's crust, such as compression and rifting, can also cause abnormal high pressure. When the Earth's crust is subjected to horizontal compression, fluids in the formation cannot be released normally, leading to abnormal high pressure. This phenomenon is commonly found in oil and gas fields in compressional tectonic environments.

[0074] For step 400, the pore pressure coefficient is used to determine the minimum drilling fluid density during drilling to prevent formation fluids from entering the wellbore (to prevent well kicks or blowouts). The collapse pressure coefficient is used to determine the minimum density of the drilling fluid to ensure wellbore stability and prevent wellbore collapse. The fracture pressure coefficient refers to the pressure gradient at which the formation begins to fracture. In order to prevent the formation from fracturing, the drilling fluid density must be lower than the density corresponding to the fracture pressure. That is, the fracture pressure coefficient is used to determine the maximum density of the drilling fluid to avoid formation fracturing and drilling fluid loss. The drilling fluid density must be selected between the collapse pressure and the fracture pressure to ensure the stability of the wellbore:

[0075] In summary, during drilling, in order to ensure the stability and safety of the wellbore, the pore pressure coefficient, the collapse pressure coefficient and the fracture pressure coefficient need to be considered comprehensively to develop a reasonable drilling fluid density range and drilling plan.

[0076] In some embodiments of the present application, the formation elastic parameters include: density, P-wave velocity, and first S-wave velocity;

[0077] In some embodiments of the present application, referring to FIG. 2, step 300 includes:

[0078] Step 301: determining the rock matrix mineral content of the second formation according to the elemental logging data in the logging data.

[0079] Step 302: determining the range of the second S-wave velocity of the rock matrix of the second formation according to the rock matrix mineral content.

[0080] In step 301 and step 302, for formations with abnormal high pressure caused by non-compaction mechanisms, the rock matrix mineral content is calculated using elemental logging data (or using logging interpretation mineral content result data), and then the upper and lower limits of the rock matrix S-wave velocity, i.e. the range of the second S-wave velocity, are obtained based on the equivalent medium average theory.

[0081] Step 303: determining the second pore pressure according to the range, the first S-wave velocity, and the overlying formation pressure.

[0082] The second pore pressure is predicted using the following formula.

[0083] In the formula, P l is the overburden pressure, represents the upper limit of the rock skeleton S-wave velocity, v s represents the rock skeleton S-wave velocity, represents the lower limit of the rock skeleton S-wave velocity, d represents an empirical coefficient.

[0084] In some embodiments of the present application, referring to FIG. 3, step 300 further includes:

[0085] Step 304: determining a third S-wave velocity of the first formation under a normal compaction trend according to the logging data;

[0086] Step 305: determining the first pore pressure according to the first S-wave velocity, the third S-wave velocity and the overburden pressure.

[0087] In step 304 and step 305, for the formation caused by the compaction mechanism, first, a normal compaction trend is established based on the first S-wave velocity in the formation elastic parameters, and the pore pressure of the corresponding formation at each depth is predicted by using the following formula.

[0088] In the formula, v s represents the inverted S-wave velocity, represents the S-wave velocity under the normal compaction trend, P h represents the hydrostatic pressure, e represents the Eaton index, and c represents an empirical coefficient.

[0089] In some embodiments of the present application, referring to FIG. 4, step 100 includes:

[0090] Step 101: generating a three-dimensional elastic parameter low-frequency initial model according to three-dimensional seismic data and logging data;

[0091] Using the logging data and the seismic horizon, a three-dimensional elastic parameter low-frequency initial model from the ground to the target layer is established by using an interpolation algorithm.

[0092] Step 102: performing pre-stack elastic parameter inversion on the three-dimensional elastic parameter low-frequency initial model according to the common-incident-point pre-stack migration trace set in the three-dimensional seismic data and the logging data, to determine the formation elastic parameters.

[0093] Based on the common-incident-point pre-stack migration trace set and the logging data (P-wave velocity, S-wave velocity, density), pre-stack elastic parameter inversion is carried out to obtain the formation density, P-wave velocity and S-wave velocity in the three-dimensional space from the ground to the target layer.

[0094] In some embodiments of the present application, referring to FIG. 5, step 400 includes:

[0095] Step 401: determining the horizontal principal stress, the fracture pressure and the collapse pressure of the first formation according to the formation elastic parameters, the overburden pressure and the first pore pressure respectively;

[0096] The maximum horizontal principal stress and the minimum horizontal principal stress are calculated by using the formation elastic parameters obtained by inversion, the overburden pressure, the first pore pressure, the rock tensile strength, and the in-situ stress obtained by measurement or well logging interpretation.

[0097] The horizontal principal stress includes the maximum horizontal principal stress and the minimum horizontal principal stress, and for the maximum horizontal principal stress, there is:

[0098] In the formula, s max is the maximum horizontal principal stress, g is the static Poisson's ratio, a is the effective stress coefficient, and b max is the tectonic stress coefficient in the direction of the maximum horizontal principal stress (related to the rock tensile strength).

[0099] For the minimum horizontal principal stress, there is:

[0100] In the formula, s min is the minimum horizontal principal stress, g is the static Poisson's ratio, a is the effective stress coefficient, and b min is the tectonic stress coefficient in the direction of the minimum horizontal principal stress (related to the rock tensile strength).

[0101] For the fracture pressure, there is:

[0102] The fracture pressure is predicted by using the formation elastic parameters obtained by inversion, the overburden pressure, the first pore pressure, and the fracture pressure obtained by measurement or well logging interpretation, and specifically:

[0103] In the formula, P f is the fracture pressure, K ss is the non-uniform tectonic stress coefficient, S t is the rock tensile strength.

[0104] For the collapse pressure, the overburden pressure, the first pore pressure, the horizontal principal stress, the rock mechanics parameters, and the existing collapse pressure data in the area are used to predict the collapse pressure based on the Mohr-Coulomb criterion.

[0105] Step 402: determining the formation pore pressure coefficient, the collapse pressure coefficient and the fracture pressure coefficient of the first formation according to the horizontal principal stress, the fracture pressure and the collapse pressure of the first formation and the hydrostatic pressure.

[0106] Specifically, the formation pore pressure coefficient, the collapse pressure coefficient and the fracture pressure coefficient are obtained according to the data body composed of the obtained horizontal principal stress, the fracture pressure and the collapse pressure divided by the hydrostatic pressure data body.

[0107] In some embodiments of the present application, referring to FIG. 6, step 500 comprises:

[0108] Step 501: determining the horizontal principal stress, the fracture pressure and the collapse pressure of the second formation according to the formation elastic parameters, the overburden pressure and the second pore pressure respectively;

[0109] Step 502: determining the formation pore pressure coefficient, the collapse pressure coefficient and the fracture pressure coefficient of the second formation according to the horizontal principal stress, the fracture pressure and the collapse pressure of the second formation and the hydrostatic pressure.

[0110] The implementation of step 501 and step 502 is similar to that of step 401 and step 402, which will not be repeated here.

[0111] In some embodiments of the present application, referring to FIG. 7, the method for selecting a drilling scheme based on three-dimensional seismic data further comprises:

[0112] Step 600: determining the first formation and the second formation according to the geological data and the drilling data of the target work area.

[0113] Specifically, all the formations from the ground to the target layer are divided into two types of formations caused by the abnormal high pressure by the compaction mechanism and the non-compaction mechanism based on the in-area geological data and the drilling data.

[0114] As can be seen from the above description, the embodiments of the present application provide a method and device for selecting a drilling scheme based on three-dimensional seismic data. The corresponding method for selecting a drilling scheme based on three-dimensional seismic data comprises: firstly, determining the formation elastic parameters of the target work area according to the three-dimensional seismic data and the logging data of the target work area; determining the overburden pressure at each depth in the target work area according to the formation elastic parameters; then, determining the first pore pressure of the first formation caused by the abnormal high pressure by the compaction mechanism and the second pore pressure of the second formation caused by the abnormal high pressure by the non-compaction mechanism according to the logging data, the formation elastic parameters and the overburden pressure; determining the formation pore pressure coefficient, the collapse pressure coefficient and the fracture pressure coefficient of the first formation according to the formation elastic parameters, the overburden pressure and the first pore pressure; finally, determining the formation pore pressure coefficient, the collapse pressure coefficient and the fracture pressure coefficient of the second formation according to the formation elastic parameters, the overburden pressure and the second pore pressure, so as to select the corresponding drilling scheme of the first formation and the second formation respectively.

[0115] The three-pressure coefficients predicted by the method provided in the application are consistent with the actual drilling conditions. The three-pressure coefficients predicted by the method can effectively support the design of the wellbore structure and the drilling fluid density, and can help effectively reduce the engineering risks such as blowout, loss of circulation, and well wall collapse, thereby reducing the safety and economic cost of deep and ultra-deep oil and gas exploration and development, and improving the exploration and development benefit.

[0116] In one specific embodiment, the application also provides a specific embodiment of a method for selecting a drilling scheme based on three-dimensional seismic data, as shown in FIGS. 8 and 9, which specifically includes the following contents.

[0117] The application uses seismic data to extract formation elastic parameters (P-wave velocity, S-wave velocity, density, Poisson's ratio), rock mechanics parameters (tensile strength, compressive strength, cohesion, internal friction angle), and ground stress (vertical principal stress, horizontal maximum principal stress, and horizontal minimum principal stress) to predict formation pore pressure coefficient, collapse pressure coefficient, and fracture pressure coefficient.

[0118] S1: Collect basic information.

[0119] The main collection is to obtain the basic information for carrying out the prediction of the three-pressure coefficients, including geological data (including but not limited to stratigraphic sequence, lithology, tectonic evolution, sedimentary cycle, and sedimentary facies), seismic data (including but not limited to three-dimensional common incidence point prestack migration trace set, three-dimensional prestack migration velocity model, seismic horizon, and seismic fault), existing drilling information in the area (including but not limited to well coordinates, trajectory, stratification, well condition, drilling display, and drilling fluid density), logging data (including but not limited to P-wave, S-wave, density, natural gamma, caliper, spontaneous potential, resistivity, neutron, elemental logging data, and imaging logging data), and geomechanics data (including but not limited to elastic parameters varying with pressure, dynamic and static elastic parameters, measured pore pressure, measured fracture pressure, ground stress, logging interpreted three-pressure coefficients and ground stress, tensile strength, compressive strength, cohesion, and internal friction angle) obtained from core experiments.

[0120] S2: Perform seismic prestack inversion.

[0121] Firstly, a three-dimensional elastic parameter low-frequency initial model from the ground to the target layer is established by using the logging data (P-wave velocity, S-wave velocity, and density) and the seismic horizon through an interpolation algorithm; then, the prestack elastic parameter inversion is carried out by using the common incidence point prestack migration trace set and the logging data (P-wave, S-wave, and density) to obtain the formation density, P-wave velocity, and S-wave velocity in the three-dimensional space from the ground to the target layer, calculate the dynamic Young's modulus and dynamic Poisson's ratio and other rock mechanics parameters based on the formation velocity and density, and convert each dynamic elastic parameter body into a static elastic parameter body based on the dynamic and static elastic parameter relationship obtained from the measured data.

[0122] S3: Obtain the 3D rock mechanics parameters such as rock tensile strength, compressive strength and cohesion from the fitting relationship based on the measured data.

[0123] S4: Perform stratigraphic longitudinal classification.

[0124] Based on the geological data and drilling data in the area, all the strata from the ground to the target layer are divided into two types of strata caused by abnormal high pressure by compaction mechanism and non-compaction mechanism.

[0125] S5: Calculate the overburden pressure.

[0126] The gravity generated by the overlying strata at each depth is integrated vertically using the obtained stratigraphic density body to obtain the overburden pressure at each depth.

[0127] S6: Predict pore pressure.

[0128] For the strata conforming to the compaction mechanism, the normal compaction trend of the shear wave velocity is established, and the Eaton index e and the empirical coefficient c in the following formula are determined using the measured pore pressure or the logging interpreted pore pressure. Finally, the pore pressure of the corresponding strata at each depth is predicted using the following formula:

[0129] In the formula, v s represents the inverted shear wave velocity, represents the shear wave velocity under normal compaction trend, P h represents hydrostatic pressure, e represents Eaton index, and c represents empirical coefficient.

[0130] For the strata with abnormal high pressure caused by non-compaction mechanism, the rock skeleton mineral content is calculated using the elemental logging data (or using the logging interpreted mineral content data), the upper and lower limits of the rock skeleton shear wave velocity are obtained based on the equivalent medium average theory, the 3D shear wave velocity upper and lower limits are obtained by interpolation algorithm combined with the seismic horizon, and the empirical coefficient d in the following formula is determined using the measured or logging interpreted pore pressure. Finally, the pore pressure of the corresponding strata at each depth is predicted using the following formula:

[0131] In the formula, represents the upper limit of the rock skeleton shear wave velocity, represents the lower limit of the rock skeleton shear wave velocity, and d represents the empirical coefficient.

[0132] S7: Predict the horizontal principal stress.

[0133] Based on the inverted elastic parameters, overburden pressure, rock tensile strength, and measured or logging interpreted in-situ stress data, the maximum and minimum horizontal principal stresses are calculated.

[0134] S8: predict the fracture pressure.

[0135] The fracture pressure is predicted according to the elastic parameters, rock mechanics parameters, overburden pressure, pore pressure, measured or interpreted fracture pressure (or well condition data).

[0136] S9: predict the collapse pressure.

[0137] The collapse pressure is predicted based on the Mohr-Coulomb criterion according to the overburden pressure, pore pressure, horizontal principal stress, rock mechanics parameters, and existing collapse pressure data in the area.

[0138] S10: calculate the tri-pressure coefficient volume.

[0139] The tri-pressure data volume is divided by the hydrostatic pressure data volume to obtain the tri-pressure coefficient volume, as shown in FIGS. 10, 11, and 12.

[0140] The above method has been effectively applied in the exploration and development of ultra-deep oil and gas in the northwest of Sichuan Basin. The tri-pressure coefficient predicted by the method is consistent with the actual drilling situation. The tri-pressure coefficient predicted by the method can effectively support the design of the wellbore structure and the drilling fluid density, and can help effectively reduce the engineering risks such as blowout, loss of circulation, and wellbore collapse, thereby reducing the safety and economic cost of deep and ultra-deep oil and gas exploration and development, and improving the exploration and development benefit.

[0141] As can be seen from the above description, the specific embodiment of the present application provides a drilling scheme selection method and device based on three-dimensional seismic data. The corresponding drilling scheme selection method based on three-dimensional seismic data includes: first, determining the formation elastic parameters of a target work area according to the three-dimensional seismic data and the logging data of the target work area; determining the overburden pressure at each depth in the target work area according to the formation elastic parameters; then, determining the first pore pressure of a first formation in which abnormal high pressure is formed by compaction mechanism and the second pore pressure of a second formation in which abnormal high pressure is formed by non-compaction mechanism according to the logging data, the formation elastic parameters, and the overburden pressure; determining the formation pore pressure coefficient, the collapse pressure coefficient, and the fracture pressure coefficient of the first formation according to the formation elastic parameters, the overburden pressure, and the first pore pressure; finally, determining the formation pore pressure coefficient, the collapse pressure coefficient, and the fracture pressure coefficient of the second formation according to the formation elastic parameters, the overburden pressure, and the second pore pressure, so as to select the corresponding drilling scheme of the first formation and the second formation, respectively.

[0142] At present, the application has been effectively applied in the super deep layer oil and gas exploration and development in the northwest of Sichuan Basin. The three pressure coefficients predicted by the method provided by the application are more consistent with the actual drilling. The three pressure coefficients predicted by the method can effectively support the design of the wellbore structure and the drilling fluid density, and can help to effectively reduce the engineering risks such as blowout, loss of circulation, and well wall collapse, thereby reducing the safety and economic cost of deep and super deep layer oil and gas exploration and development, and improving the exploration and development benefit.

[0143] Based on the same inventive concept, the embodiments of the application also provide a drilling scheme selection device based on three-dimensional seismic data, which can be used to implement the method described in the above embodiments, as follows. Since the drilling scheme selection device based on three-dimensional seismic data has a similar problem-solving principle to the drilling scheme selection method based on three-dimensional seismic data, the implementation of the drilling scheme selection device based on three-dimensional seismic data can be referred to the implementation of the drilling scheme selection method based on three-dimensional seismic data, and the repeated parts will not be described here. The term "unit" or "module" used below can be a combination of software and / or hardware that can implement a predetermined function. Although the system described in the following embodiments is preferably implemented in software, hardware, or a combination of software and hardware is also possible and is conceived.

[0144] The embodiments of the application provide a specific implementation of a drilling scheme selection device based on three-dimensional seismic data, which can implement the drilling scheme selection method based on three-dimensional seismic data, wherein, referring to FIG. 13, a drilling scheme selection device based on three-dimensional seismic data comprises:

[0145] The formation elastic parameter determination module 10 is configured to determine the formation elastic parameters of the target work area according to the three-dimensional seismic data and the logging data of the target work area.

[0146] The overlying formation pressure determination module 20 is configured to determine the overlying formation pressure at each depth in the target work area according to the formation elastic parameters.

[0147] The pore pressure determination module 30 is configured to determine the first pore pressure of the first formation in which the abnormal high pressure is formed by the compaction mechanism and the second pore pressure of the second formation in which the abnormal high pressure is formed by the non-compaction mechanism according to the logging data, the formation elastic parameters, and the overlying formation pressure, respectively.

[0148] The three-coefficient determination first module 40 is configured to determine the formation pore pressure coefficient, the collapse pressure coefficient, and the fracture pressure coefficient of the first formation according to the formation elastic parameters, the overlying formation pressure, and the first pore pressure.

[0149] The third coefficient determining first module 40 is configured to determine the horizontal principal stress, the fracture pressure and the collapse pressure of the first formation according to the formation elastic parameters, the overburden pressure and the first pore pressure.

[0150] In some embodiments of the present application, the formation elastic parameters include: density, P-wave velocity and first S-wave velocity.

[0151] In some embodiments of the present application, referring to FIG. 14, the pore pressure determining module 30 comprises:

[0152] The mineral content determining unit 30a is configured to determine the rock framework mineral content of the second formation according to the element logging data in the logging data.

[0153] The range determining unit 30b is configured to determine the range of the second S-wave velocity of the rock framework of the second formation according to the rock framework mineral content.

[0154] The second pore pressure determining unit 30c is configured to determine the second pore pressure according to the range, the first S-wave velocity and the overburden pressure.

[0155] In some embodiments of the present application, referring to FIG. 15, the pore pressure determining module 30 further comprises:

[0156] The third S-wave velocity determining unit 30d is configured to determine the third S-wave velocity of the first formation under the normal compaction trend according to the logging data.

[0157] The first pore pressure determining unit 30e is configured to determine the first pore pressure according to the first S-wave velocity, the third S-wave velocity and the overburden pressure.

[0158] In some embodiments of the present application, referring to FIG. 16, the formation elastic parameter determining module 10 comprises:

[0159] The initial model generating unit 10a is configured to generate a three-dimensional elastic parameter low-frequency initial model according to the three-dimensional seismic data and the logging data.

[0160] The formation elastic parameter determining unit 10b is configured to perform pre-stack elastic parameter inversion on the three-dimensional elastic parameter low-frequency initial model according to the common incidence point pre-stack migration trace set in the three-dimensional seismic data and the logging data, so as to determine the formation elastic parameters.

[0161] In some embodiments of the present application, referring to FIG. 17, the third coefficient determining first module 40 comprises:

[0162] The stress determining first unit 40a is configured to determine the horizontal principal stress, the fracture pressure and the collapse pressure of the first formation according to the formation elastic parameters, the overburden pressure and the first pore pressure, respectively.

[0163] The three-coefficient determining first unit 40b is configured to determine the formation pore pressure coefficient, the collapse pressure coefficient and the fracture pressure coefficient of the first formation according to the horizontal principal stress, the collapse pressure and the fracture pressure of the first formation and the hydrostatic pressure.

[0164] In some embodiments of the present application, referring to FIG. 18, the three-coefficient determining second module 50 comprises:

[0165] The stress determining second unit 50a is configured to determine the horizontal principal stress, the collapse pressure and the fracture pressure of the second formation according to the formation elastic parameters, the overburden pressure and the second pore pressure, respectively.

[0166] The three-coefficient determining second unit 50b is configured to determine the formation pore pressure coefficient, the collapse pressure coefficient and the fracture pressure coefficient of the second formation according to the horizontal principal stress, the collapse pressure and the fracture pressure of the second formation and the hydrostatic pressure.

[0167] In some embodiments of the present application, referring to FIG. 19, the drilling scheme selection device based on three-dimensional seismic data further comprises:

[0168] The formation determining module 60 is configured to determine the first formation and the second formation according to the geological data and the drilling data of the target work area.

[0169] As can be seen from the above description, the embodiments of the present application provide a drilling scheme selection device based on three-dimensional seismic data, which comprises: a formation elastic parameter determining module configured to determine the formation elastic parameters of a target work area according to three-dimensional seismic data and logging data of the target work area; an overburden pressure determining module configured to determine the overburden pressure at each depth in the target work area according to the formation elastic parameters; a pore pressure determining module configured to determine the first pore pressure of a first formation formed by a compaction mechanism of abnormal high pressure and the second pore pressure of a second formation formed by a non-compaction mechanism of abnormal high pressure according to the logging data, the formation elastic parameters and the overburden pressure, respectively; a three-coefficient determining first module configured to determine the formation pore pressure coefficient, the collapse pressure coefficient and the fracture pressure coefficient of the first formation according to the formation elastic parameters, the overburden pressure and the first pore pressure; and a three-coefficient determining second module configured to determine the formation pore pressure coefficient, the collapse pressure coefficient and the fracture pressure coefficient of the second formation according to the formation elastic parameters, the overburden pressure and the second pore pressure, so as to select the corresponding drilling scheme of the first formation and the second formation, respectively.

[0170] The present application can accurately obtain the distribution of the three pressure coefficients in the three-dimensional underground space, so as to help carry out reservoir evaluation and support the design of the drilling well structure and the design of the drilling fluid density window.

[0171] The embodiment of the present application also provides a specific implementation of an electronic device capable of implementing all steps of the drilling scheme selection method based on three-dimensional seismic data in the above embodiment, referring to FIG. 20, the electronic device specifically includes the following contents:

[0172] a processor 1201, a memory 1202, a communications interface 1203 and a bus 1204;

[0173] The processor 1201, the memory 1202 and the communications interface 1203 can communicate with each other through the bus 1204; the communications interface 1203 is configured to realize information transmission between the server-side device, the client-side device and other related devices;

[0174] The processor 1201 is configured to call a computer program in the memory 1202, and when the processor executes the computer program, all steps of the drilling scheme selection method based on three-dimensional seismic data in the above embodiment are implemented, for example, when the processor executes the computer program, the following steps are implemented:

[0175] Step 100: determining formation elastic parameters of a target work area according to three-dimensional seismic data and logging data of the target work area;

[0176] Step 200: determining overburden pressure at each depth in the target work area according to the formation elastic parameters;

[0177] Step 300: respectively determining first pore pressure of a first formation in which abnormal high pressure is formed by a compaction mechanism and second pore pressure of a second formation in which abnormal high pressure is formed by a non-compaction mechanism according to the logging data, the formation elastic parameters and the overburden pressure;

[0178] Step 400: determining formation pore pressure coefficient, collapse pressure coefficient and fracture pressure coefficient of the first formation according to the formation elastic parameters, the overburden pressure and the first pore pressure; and

[0179] Step 500: determining formation pore pressure coefficient, collapse pressure coefficient and fracture pressure coefficient of the second formation according to the formation elastic parameters, the overburden pressure and the second pore pressure, so as to select corresponding drilling schemes of the first formation and the second formation respectively.

[0180] The embodiment of the present application also provides a computer readable storage medium capable of implementing all steps of the drilling scheme selection method based on three-dimensional seismic data in the above embodiment, and the computer readable storage medium stores a computer program, and when the computer program is executed by a processor, all steps of the drilling scheme selection method based on three-dimensional seismic data in the above embodiment are implemented, for example, when the processor executes the computer program, the following steps are implemented:

[0181] Step 100: determining formation elastic parameters of the target work area according to three-dimensional seismic data and logging data of the target work area;

[0182] Step 200: determining overburden pressure at each depth in the target work area according to the formation elastic parameters;

[0183] Step 300: determining first pore pressure of a first formation in which abnormal high pressure is formed by compaction mechanism and second pore pressure of a second formation in which abnormal high pressure is formed by non-compaction mechanism according to logging data, formation elastic parameters and overburden pressure, respectively;

[0184] Step 400: determining formation pore pressure coefficient, collapse pressure coefficient and fracture pressure coefficient of the first formation according to formation elastic parameters, overburden pressure and the first pore pressure; and

[0185] Step 500: determining formation pore pressure coefficient, collapse pressure coefficient and fracture pressure coefficient of the second formation according to formation elastic parameters, overburden pressure and the second pore pressure, so as to select a corresponding drilling scheme for the first formation and the second formation, respectively.

[0186] Each of the embodiments in the specification is described in a progressive manner, and the same or similar parts between the embodiments can be referred to each other. Each embodiment focuses on the difference from other embodiments. In particular, for the hardware + program type embodiment, since it is basically similar to the method embodiment, the description is relatively simple, and the relevant part can be referred to the part of the method embodiment.

[0187] The above describes specific embodiments of the specification. Other embodiments are within the scope of the appended claims. In some cases, the actions or steps recited in the claims can be performed in an order different than the order in which the embodiments are described, and still achieve desirable results. In addition, the processes depicted in the figures do not necessarily require the particular order shown, or sequential order, to achieve the desired results. In certain implementations, multitasking and parallel processing can be advantageous.

[0188] Although the present application provides method operation steps such as embodiments or flowcharts, more or fewer operation steps can be included based on conventional or non-creative labor. The order of steps listed in the embodiments is only one of the many execution orders of the steps, and does not represent the only execution order. When the device or client product is executed in practice, the method order shown in the embodiments or the drawings can be executed in sequence or in parallel (for example, in the environment of parallel processor or multi-thread processing).

[0189] For ease of description, the above apparatus is described in various modules with different functions respectively. Of course, in the implementation of the embodiments of the present specification, the functions of each module can be implemented in the same or more software and / or hardware, or the modules implementing the same function can be implemented by a combination of multiple sub-modules or sub-units, etc. The apparatus embodiment described above is only schematic. For example, the division of the units is only a logical function division, and there can be another division manner in actual implementation. For example, multiple units or components can be combined or integrated into another system, or some features can be ignored or not executed. In addition, the coupling or direct coupling or communication connection between the displayed or discussed units can be indirect coupling or communication connection through some interfaces, devices or units, and can be electrical, mechanical or other forms.

[0190] Those skilled in the art also know that, in addition to implementing the controller in the form of pure computer readable program code, the controller can also be implemented in the form of logic gates, switches, application specific integrated circuits, programmable logic controllers and embedded microcontrollers, etc. by logically programming the method steps to achieve the same functions. Therefore, such a controller can be considered as a hardware component, and the devices included therein for implementing various functions can also be considered as structures within the hardware component. Alternatively, the devices for implementing various functions can even be considered as both software modules implementing the method and structures within the hardware component.

[0191] In a typical configuration, a computing device includes one or more processors (CPUs), input / output interfaces, network interfaces, and memory.

[0192] The memory can include non-persistent memory in computer readable media, random access memory (RAM), and / or non-volatile memory, such as read-only memory (ROM) or flash memory (flash RAM). The memory is an example of computer readable media.

[0193] Each of the embodiments in the specification is described in a progressive manner, and the same or similar parts between the embodiments can be referred to each other. Each of the embodiments focuses on the difference from other embodiments. In particular, the system embodiments are described simply because they are basically similar to the method embodiments, and the relevant parts can be referred to the description of the method embodiments. In the description of the specification, the description of the terms "one embodiment", "some embodiments", "an example", "a specific example", or "some examples" means that the specific features, structures, materials or characteristics described in connection with the embodiment or example are included in at least one embodiment or example of the embodiments of the specification. The illustrative description of the above terms in the specification does not necessarily refer to the same embodiment or example. Moreover, the specific features, structures, materials or characteristics described can be combined in any suitable manner in any one or more embodiments or examples. In addition, the person skilled in the art can combine and combine the different embodiments or examples described in the specification and the features of the different embodiments or examples without contradiction.

[0194] The above only describes the embodiments of the embodiments of the specification and does not limit the embodiments of the specification. The embodiments of the specification can have various changes and variations for those skilled in the art. Any modification, equivalent replacement, improvement, etc. made within the spirit and principle of the embodiments of the specification shall be included in the scope of claims of the embodiments of the specification.

Claims

1. A method for selecting a drilling program based on three-dimensional seismic data, characterized in that, The method comprises: determining formation elastic parameters of a target work area according to three-dimensional seismic data and logging data of the target work area; determining overburden pressure at each depth in the target work area according to the formation elastic parameters; determining first pore pressure of a first formation in which abnormal high pressure is formed by compaction mechanism and second pore pressure of a second formation in which abnormal high pressure is formed by non-compaction mechanism according to the logging data, the formation elastic parameters and the overburden pressure respectively; determining formation pore pressure coefficient, collapse pressure coefficient and fracture pressure coefficient of the first formation according to the formation elastic parameters, the overburden pressure and the first pore pressure; and determining formation pore pressure coefficient, collapse pressure coefficient and fracture pressure coefficient of the second formation according to the formation elastic parameters, the overburden pressure and the second pore pressure to select corresponding drilling schemes of the first formation and the second formation respectively. The formation elastic parameters comprise density, P-wave velocity and first S-wave velocity.

2. The method of well plan selection of claim 1, wherein, The determination of the second pore pressure according to the logging data, the formation elastic parameters and the overburden pressure comprises: determining rock framework mineral content of the second formation according to element logging data in the logging data; determining a range of second S-wave velocity of the rock framework of the second formation according to the rock framework mineral content; determining the second pore pressure according to the range, the first S-wave velocity and the overburden pressure. The determination of the first pore pressure according to the logging data, the formation elastic parameters and the overburden pressure comprises:

3. The method of well plan selection of claim 2, wherein, determining third S-wave velocity of the first formation under normal compaction trend according to the logging data; determining the first pore pressure according to the first S-wave velocity, the third S-wave velocity and the overburden pressure. The determination of the formation elastic parameters of the target work area according to three-dimensional seismic data and logging data of the target work area comprises:

4. The method of claim 1, wherein, generating a three-dimensional elastic parameter low-frequency initial model according to the three-dimensional seismic data and the logging data; performing pre-stack elastic parameter inversion on the three-dimensional elastic parameter low-frequency initial model according to common incidence point pre-stack migration trace sets in the three-dimensional seismic data and the logging data to determine the formation elastic parameters. The determination of the formation pore pressure coefficient, the collapse pressure coefficient and the fracture pressure coefficient of the first formation according to the formation elastic parameters, the overburden pressure and the first pore pressure comprises:

5. The method of selecting a drilling program according to any one of claims 1 to 4, wherein, determining horizontal principal stress, fracture pressure and collapse pressure of the first formation according to the formation elastic parameters, the overburden pressure and the first pore pressure respectively; determining the formation pore pressure coefficient, the collapse pressure coefficient and the fracture pressure coefficient of the first formation according to the horizontal principal stress, the fracture pressure and the collapse pressure of the first formation and hydrostatic pressure. The determination of the formation pore pressure coefficient, the collapse pressure coefficient and the fracture pressure coefficient of the second formation according to the formation elastic parameters, the overburden pressure and the second pore pressure comprises:

6. The method of selecting a drilling program according to any one of claims 1 to 4, wherein, ​ determine a horizontal principal stress, a collapse pressure and a fracture pressure of the second formation according to the formation elastic parameters, the overburden pressure and the second pore pressure respectively; determine a formation pore pressure coefficient, a collapse pressure coefficient and a fracture pressure coefficient of the second formation according to the horizontal principal stress, the collapse pressure, the fracture pressure and a hydrostatic pressure of the second formation.

7. The method of well plan selection of claim 1, wherein, Further comprising: determine the first formation and the second formation according to geological data and drilling data of the target work area.

8. A device for selecting a drilling program based on three-dimensional seismic data, characterized in that Comprise: a formation elastic parameter determination module, configured to determine formation elastic parameters of a target work area according to three-dimensional seismic data and logging data of the target work area; an overburden pressure determination module, configured to determine an overburden pressure at each depth in the target work area according to the formation elastic parameters; a pore pressure determination module, configured to determine a first pore pressure of a first formation in which abnormal high pressure is formed by compaction mechanism and a second pore pressure of a second formation in which abnormal high pressure is formed by non-compaction mechanism according to the logging data, the formation elastic parameters and the overburden pressure respectively; a three-coefficient determination first module, configured to determine a formation pore pressure coefficient, a collapse pressure coefficient and a fracture pressure coefficient of the first formation according to the formation elastic parameters, the overburden pressure and the first pore pressure; and a three-coefficient determination second module, configured to determine a formation pore pressure coefficient, a collapse pressure coefficient and a fracture pressure coefficient of the second formation according to the formation elastic parameters, the overburden pressure and the second pore pressure, so as to select a corresponding drilling scheme for the first formation and the second formation respectively.

9. The drilling program selection apparatus of claim 8, wherein, The formation elastic parameters comprise: density, P-wave velocity and first S-wave velocity; The pore pressure determination module comprises: a mineral content determination unit, configured to determine rock framework mineral content of the second formation according to element logging data in the logging data; a range determination unit, configured to determine a range of second S-wave velocity of the rock framework of the second formation according to the rock framework mineral content; a second pore pressure determination unit, configured to determine the second pore pressure according to the range, the first S-wave velocity and the overburden pressure.

10. The drilling program selection apparatus of claim 9, wherein, The pore pressure determination module further comprises: a third S-wave velocity determination unit, configured to determine a third S-wave velocity of the first formation under normal compaction trend according to the logging data; a first pore pressure determination unit, configured to determine the first pore pressure according to the first S-wave velocity, the third S-wave velocity and the overburden pressure.

11. The drilling program selection apparatus of claim 8, wherein, The formation elastic parameter determination module comprises: an initial model generation unit, configured to generate a three-dimensional elastic parameter low-frequency initial model according to the three-dimensional seismic data and the logging data; a formation elastic parameter determination unit, configured to perform pre-stack elastic parameter inversion on the three-dimensional elastic parameter low-frequency initial model according to common incidence point pre-stack migration gathers in the three-dimensional seismic data and the logging data, so as to determine the formation elastic parameters.

12. A drilling plan selection apparatus according to any one of claims 8 to 11, characterised in that, The three-coefficient determination first module comprises: The stress determining first unit is configured to determine the horizontal principal stress, the fracture pressure and the collapse pressure of the first formation according to the formation elastic parameters, the overburden pressure and the first pore pressure, respectively. The three-coefficient determining first unit is configured to determine the formation pore pressure coefficient, the collapse pressure coefficient and the fracture pressure coefficient of the first formation according to the horizontal principal stress, the fracture pressure and the collapse pressure of the first formation and the hydrostatic pressure.

13. The drilling program selection apparatus of any one of claims 8 to 11, wherein, The three-coefficient determining second module comprises: The stress determining second unit is configured to determine the horizontal principal stress, the fracture pressure and the collapse pressure of the second formation according to the formation elastic parameters, the overburden pressure and the second pore pressure, respectively. The three-coefficient determining second unit is configured to determine the formation pore pressure coefficient, the collapse pressure coefficient and the fracture pressure coefficient of the second formation according to the horizontal principal stress, the fracture pressure and the collapse pressure of the second formation and the hydrostatic pressure.

14. The drilling program selection apparatus of claim 8, wherein, Further comprising: The formation determining module is configured to determine the first formation and the second formation according to the geological data and the drilling data of the target work area.

15. A computer program product comprising computer programs / instructions, characterized in that, The computer program / instruction is executed by the processor to realize the steps of the method for selecting a drilling scheme based on three-dimensional seismic data according to any one of claims 1 to 7.

16. An electronic device comprising a memory, a processor, and a computer program stored on the memory and executable on the processor, characterized in that, The processor executes the program to realize the steps of the method for selecting a drilling scheme based on three-dimensional seismic data according to any one of claims 1 to 7.

17. A computer readable storage medium having stored thereon a computer program, characterized in that, The computer program is executed by the processor to realize the steps of the method for selecting a drilling scheme based on three-dimensional seismic data according to any one of claims 1 to 7.

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