Oil production capacity determination method and device, computer equipment and storage medium

Abstract

The invention provides an oil production capacity determination method and device, computer equipment and a storage medium, and belongs to the field of oil and gas investigation. The method comprises the steps of determining reservoir information of a reservoir in a target block based on logging information of the target block; determining reservoir information of a reservoir in the target block based on the logging information of the target block; determining an index value of a first index of the reservoir based on the reservoir information; determining an index value of an oil production index of a reservoir-related pilot production well based on the well test data of the target block; and determining the oil production capacity of the target block based on the index value of the first index, the index value of the oil production index and the oil production capacity relation graph. According to the technical scheme, the related parameters capable of indicating the oil production capacity of the target block are determined based on the well logging information and the well testing information of the target block under the salt cement slurry condition, so that the characteristics of the low-porosity and low-permeability tight sandstone reservoir under the salt cement slurry condition are comprehensively reflected, and the accuracy of the oil production capacity determination method is ensured.

Description

Technical Field

[0001] The present application relates to the field of oil and gas exploration, and in particular to a method, device, computer equipment and storage medium for determining oil production capacity. Background Art

[0002] In the field of oil and gas exploration, the oil production capacity of a reservoir is the primary indicator of reservoir development. Accurately predicting the oil production capacity of a reservoir is a key link in the dynamic analysis of reservoir development. If the oil production capacity of a reservoir can be accurately predicted, it can help companies to reasonably allocate resources, carry out production planning and scheduling, and improve production efficiency. Therefore, how to accurately predict the oil production capacity of a reservoir is a problem that needs to be solved.

[0003] At present, comprehensive logging is usually carried out using logging methods such as natural gamma, natural potential and three-porosity logging. After obtaining relevant parameters such as reservoir porosity, permeability and resistivity, the oil production capacity of the reservoir is predicted.

[0004] However, due to the complex pore structure and lithology of low-porosity and low-permeability tight sandstone reservoirs under saline water slurry conditions, the existing relevant parameters cannot fully reflect the characteristics of low-porosity and low-permeability tight sandstone reservoirs, resulting in the inability to accurately predict the oil production capacity of low-porosity and low-permeability tight sandstone reservoirs using the above prediction method. Summary of the invention

[0005] The embodiment of the present application provides a method, device, computer equipment and storage medium for determining oil production capacity, which can determine basic parameters such as porosity and permeability based on well logging data and well test data of the target block under saline water slurry conditions, and introduce relevant parameters such as mobility parameters, invasion parameters and source-reservoir matching parameters that can indicate the oil production capacity of the target block, thereby comprehensively reflecting the characteristics of low-porosity and low-permeability dense sandstone reservoirs under saline water slurry conditions, and ensuring the accuracy of the oil production capacity determination method. The technical solution is as follows:

[0006] In one aspect, a method for determining oil production capacity is provided, the method comprising:

[0007] Based on the well logging data of the target block, the reservoir information of the reservoir in the target block is determined, the reservoir information includes porosity, permeability, mobility parameter, invasion parameter and source-reservoir matching parameter, the mobility parameter is used to indicate the fluidity of the fluid in the reservoir, and the invasion parameter is used to indicate the invasion degree of the salt water slurry in the reservoir;

[0008] Based on the reservoir information, determining an index value of a first index of the reservoir, wherein the index value of the first index is positively correlated with the enrichment degree of oil in the reservoir;

[0009] Determining the index value of the oil production index of the test well related to the reservoir based on the well test data of the target block;

[0010] The oil production capacity of the target block is determined based on the index value of the first index, the index value of the oil production index and the oil production capacity relationship diagram of the target block, the horizontal axis of the oil production capacity relationship diagram is the first index, and the vertical axis is the oil production index.

[0011] In another aspect, a device for determining oil production capacity is provided, the device comprising:

[0012] A first determination module is used to determine reservoir information of a reservoir in the target block based on well logging data of the target block, wherein the reservoir information includes porosity, permeability, mobility parameter, invasion parameter and source-reservoir matching parameter, wherein the mobility parameter is used to indicate the fluidity of the fluid in the reservoir, and the invasion parameter is used to indicate the invasion degree of saline water slurry in the reservoir;

[0013] A second determination module is used to determine an index value of a first index of the reservoir based on the reservoir information, wherein the index value of the first index is positively correlated with the enrichment degree of oil in the reservoir;

[0014] A third determination module is used to determine the index value of the oil production index of the test well related to the reservoir based on the well test data of the target block;

[0015] The fourth determination module is used to determine the oil production capacity of the target block based on the index value of the first index, the index value of the oil production index and the oil production capacity relationship diagram of the target block, wherein the horizontal axis of the oil production capacity relationship diagram is the first index and the vertical axis is the oil production index.

[0016] In some embodiments, the first determining module includes:

[0017] A first determination unit is used to determine the porosity, the permeability, first information and second information of the reservoir in the target block based on the logging data of the target block, wherein the first information includes array induction resistivity at different radial detection depths, and the second information includes an envelope area between an acoustic logging curve and an array induction curve;

[0018] a second determining unit, configured to determine the intrusion parameter based on the first information;

[0019] a third determining unit, configured to determine the source-reservoir matching parameter based on the second information;

[0020] A fourth determination unit is used to determine the fluidity parameter based on the porosity, the permeability and the invasion parameter.

[0021] In some embodiments, the first determination unit is used to obtain logging data of the target block, determine the porosity, the permeability, the first information, the acoustic logging curve and the array sensing curve of the reservoir in the target block; normalize the acoustic logging curve and the array sensing curve to obtain an acoustic normalized curve and a sensing normalized curve, and the coordinate axis of the acoustic logging curve is set opposite to the coordinate axis of the array sensing curve; and determine the envelope area of ​​the acoustic normalized curve and the sensing normalized curve as the second information.

[0022] In some embodiments, the second determination unit is used to determine multiple ratios of a first resistivity to multiple second resistivities based on the first information, where the first resistivity refers to the array induced resistivity at the maximum radial detection depth, and the second resistivity refers to the array induced resistivity at any other radial detection depth; and the multiple ratios are multiplied to obtain the intrusion parameters.

[0023] In some embodiments, the second determination module is used to determine the weight coefficient of each parameter in the reservoir information based on the reservoir information, and the weight coefficient is used to indicate the influence of the parameter on the first index; based on the weight coefficient, the weighted sum of the various parameters is performed to obtain the index value of the first index.

[0024] In some embodiments, the third determination module is used to determine the oil production of the test well and the layer thickness of the reservoir based on the well testing data of the target block; and determine the ratio of the oil production and the layer thickness as the index value of the oil production index.

[0025] In some embodiments, the fourth determination module is used to determine a target point in the oil production capacity relationship diagram based on the index value of the first index and the index value of the oil production index, the horizontal coordinate of the target point is equal to the index value of the first index, and the vertical coordinate of the target point is equal to the index value of the oil production index; based on the position of the target point in the oil production capacity relationship diagram, determine the target level to which the test well belongs, and the target level is used to indicate the oil production capacity; based on the target level, determine the oil production capacity of the target block.

[0026] On the other hand, a computer device is provided, which includes a processor and a memory, wherein the memory is used to store at least one computer program, and the at least one computer program is loaded and executed by the processor to implement the oil production capacity determination method in the embodiment of the present application.

[0027] On the other hand, a computer-readable storage medium is provided, in which at least one computer program is stored. The at least one computer program is loaded and executed by a processor to implement the oil production capacity determination method in the embodiment of the present application.

[0028] On the other hand, a computer program product is provided, including a computer program, wherein the computer program is executed by a processor to implement the oil production capacity determination method in the embodiment of the present application.

[0029] The embodiment of the present application provides a method for determining oil production capacity, which determines basic parameters such as porosity and permeability based on logging data and well test data of a target block under saline water slurry conditions, and introduces relevant parameters such as fluidity parameters, invasion parameters, and source-reservoir matching parameters that can indicate the oil production capacity of the target block, thereby comprehensively reflecting the characteristics of low-porosity and low-permeability dense sandstone reservoirs under saline water slurry conditions, and ensuring the accuracy of the method for determining oil production capacity. BRIEF DESCRIPTION OF THE DRAWINGS

[0030] In order to more clearly illustrate the technical solutions in the embodiments of the present application, the drawings required for use in the description of the embodiments will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present application. For ordinary technicians in this field, other drawings can be obtained based on these drawings without creative work.

[0031] Figure 1 It is a schematic diagram of an implementation environment of a method for determining oil production capacity provided in an embodiment of the present application;

[0032] Figure 2 is a flow chart of a method for determining oil production capacity provided according to an embodiment of the present application;

[0033] Figure 3 is a flow chart of another method for determining oil production capacity provided according to an embodiment of the present application;

[0034] Figure 4 is a schematic diagram of the relationship between porosity and permeability provided according to an embodiment of the present application;

[0035] Figure 5 is a schematic diagram of a source-reservoir matching relationship provided according to an embodiment of the present application;

[0036] Figure 6 is a schematic diagram of the relationship between a parameter and an oil production index provided according to an embodiment of the present application;

[0037] Figure 7 is a schematic diagram of an oil production capacity relationship diagram provided according to an embodiment of the present application;

[0038] Figure 8 is a schematic diagram of a hierarchical classification provided according to an embodiment of the present application;

[0039] Fig. 9 is a schematic diagram of an oil production capacity determination process provided according to an embodiment of the present application;

[0040] Fig.10 It is a schematic diagram of an oil production capacity determination effect provided according to an embodiment of the present application;

[0041] Fig.11 is a block diagram of an oil production capacity determination device provided according to an embodiment of the present application;

[0042] Fig.12 is a block diagram of another oil production capacity determination device provided according to an embodiment of the present application;

[0043] Fig.13 is a schematic diagram of the structure of a terminal provided according to an embodiment of the present application;

[0044] Fig.14 It is a structural diagram of a server provided according to an embodiment of the present application. DETAILED DESCRIPTION

[0045] In order to make the objectives, technical solutions and advantages of the present application clearer, the implementation methods of the present application will be further described in detail below in conjunction with the accompanying drawings.

[0046] In this application, the terms "first", "second", etc. are used to distinguish identical or similar items with basically the same effects and functions. It should be understood that there is no logical or temporal dependency between "first", "second", and "nth", nor is there any limitation on quantity and execution order.

[0047] In the present application, the term "at least one" means one or more, and the term "plurality" means two or more.

[0048] It should be noted that the information (including but not limited to user device information, user personal information, etc.), data (including but not limited to data used for analysis, stored data, displayed data, etc.) and signals involved in this application are all authorized by the user or fully authorized by all parties, and the collection, use and processing of relevant data must comply with relevant laws, regulations and standards of relevant countries and regions. For example, the well logging data and well testing data involved in this application are all obtained with full authorization.

[0049] Figure 1 Schematic diagram of an implementation environment of a method for determining oil production capacity provided in an embodiment of the present application. Figure 1The implementation environment includes a terminal 101 and a server 102. The terminal 101 and the server 102 can be directly or indirectly connected via wired or wireless communication, which is not limited in this application.

[0050] In some embodiments, the terminal 101 is a mobile phone, a desktop computer, a laptop computer, a tablet computer, a smart watch, and other types of terminals. An application can be installed and run on the terminal 101, and the application can determine the oil production capacity based on the relevant information of the target block and display the result. The user can log in to the application to view the determination result of the oil production capacity of the target block. The application is associated with the server 102, and the server 102 provides background services to the terminal 101.

[0051] In some embodiments, the server 102 is an independent physical server, or a server cluster or distributed system composed of multiple physical servers, or a cloud server that provides basic cloud computing services such as cloud services, cloud databases, cloud computing, cloud functions, cloud storage, network services, cloud communications, middleware services, domain name services, security services, CDN (Content Delivery Network), and big data and artificial intelligence platforms. In some embodiments, the terminal 101 sends relevant information such as well logging, well testing, and logging of the target block to the server 102. Based on the relevant information of the target block, the server 102 determines the reservoir information of the reservoir in the target block, and then determines the oil production capacity of the target block, and displays the result. The server 102 returns the result to the terminal 101.

[0052] In some embodiments, the server 102 undertakes the main computing work and the terminal 101 undertakes the secondary computing work; or, the server 102 undertakes the secondary computing work and the terminal 101 undertakes the main computing work; or, the server 102 and the terminal 101 adopt a distributed computing architecture to perform collaborative computing.

[0053] Figure 2 is a flow chart of a method for determining oil production capacity according to an embodiment of the present application, the method being executed by a computer device, see Figure 2 , the method comprises the following steps:

[0054] 201. Based on the logging data of the target block, the reservoir information of the reservoir in the target block is determined. The reservoir information includes porosity, permeability, fluidity parameter, invasion parameter and source-reservoir matching parameter. The fluidity parameter is used to indicate the fluidity of the fluid in the reservoir, and the invasion parameter is used to indicate the invasion degree of saline water slurry in the reservoir.

[0055] In the embodiment of the present application, in order to more comprehensively characterize the characteristics of the reservoir in the target block, based on the logging data of the target block, the computer equipment can obtain relevant parameters such as mobility parameters, invasion parameters and source-reservoir matching parameters in addition to basic parameters such as porosity and permeability. Among them, the target block includes low-porosity and low-permeability tight sandstone reservoirs, and may also include conventional reservoir rocks such as shale, sandstone and limestone, which are not limited by the embodiment of the present application. Among them, logging data refers to the data obtained by measuring the downhole strata using various instruments in the process of exploring and developing underground oil and gas deposits. In the logging process, natural gamma, natural potential, three-porosity curves and array induction logging and other logging methods can be used, which are not limited by the embodiment of the present application. The logging data may include single-point logging data and logging curves, etc., which are not limited by the embodiment of the present application. Among them, in the drilling process, salt water mud is used as the drilling fluid, and fresh water drilling fluid, emulsified drilling fluid and polymer drilling fluid can also be used, which are not limited by the embodiment of the present application.

[0056] 202. Based on the reservoir information, determine an index value of a first index of the reservoir, where the index value of the first index is positively correlated with the enrichment degree of oil in the reservoir.

[0057] In the embodiment of the present application, the first index is obtained by integrating various parameters in the reservoir information. Compared with using a single parameter, the first index can more comprehensively represent the characteristics of the reservoir, thereby making the determination result of the oil production capacity of the target block more accurate. Among them, the first index is used to indicate the reservoir storage performance of the reservoir for oil. The higher the enrichment degree of oil in the reservoir, the better the reservoir storage performance of the reservoir for oil. The index value of the first index will be affected by the changes of various parameters in the reservoir information.

[0058] 203. Based on the well test data of the target block, determine the index value of the oil production index of the test well related to the reservoir.

[0059] In the embodiment of the present application, there may be multiple test wells in the target block, and different test wells may reflect the exploitation characteristics of different parts of the oil and gas deposits. Among them, the test well data refers to the data obtained by regularly measuring pressure, oil production, gas volume, water content, temperature and working conditions using various instruments in the process of developing underground oil and gas deposits. During the test well process, a stable test well method or an unstable method may be used, and the embodiment of the present application does not limit this. Among them, the oil production index is used to indicate the oil production capacity of the reservoir. The higher the index value of the oil production index of the reservoir, the better the oil production capacity of the reservoir.

[0060] 204. Determine the oil production capacity of the target block based on the index value of the first index, the index value of the oil production index, and the oil production capacity relationship diagram of the target block, wherein the abscissa of the oil production capacity relationship diagram is the first index and the ordinate is the oil production index.

[0061] In the embodiment of the present application, the oil production capacity relationship diagram can be divided into multiple regions, and different regions indicate different oil production capacities. Therefore, based on the region where any coordinate point is located in the oil production capacity relationship diagram, the oil production capacity of the test well represented by the coordinate point can be determined. Among them, the oil production capacity of the test well in the target block can be determined first, and then the oil production capacity of the target block can be determined.

[0062] The embodiment of the present application provides a method for determining oil production capacity, which determines basic parameters such as porosity and permeability based on logging data and well test data of a target block under saline water slurry conditions, and introduces relevant parameters such as fluidity parameters, invasion parameters, and source-reservoir matching parameters that can indicate the oil production capacity of the target block, thereby comprehensively reflecting the characteristics of low-porosity and low-permeability dense sandstone reservoirs under saline water slurry conditions, and ensuring the accuracy of the method for determining oil production capacity.

[0063] Figure 3 is a flowchart of another oil production capacity determination method provided in an embodiment of the present application, the method is executed by a computer device, see Figure 3 , the method comprises the following steps:

[0064] 301. Based on the logging data of the target block, the reservoir information of the reservoir in the target block is determined. The reservoir information includes porosity, permeability, fluidity parameter, invasion parameter and source-reservoir matching parameter. The fluidity parameter is used to indicate the fluidity of the fluid in the reservoir, and the invasion parameter is used to indicate the invasion degree of saline water slurry in the reservoir.

[0065] In the embodiment of the present application, in order to more comprehensively characterize the characteristics of the reservoir in the target block, based on the logging data of the target block, the computer equipment can not only obtain basic parameters such as porosity and permeability, but also determine related parameters such as fluidity parameters, invasion parameters, and source-reservoir matching parameters.

[0066] Among them, the target block includes low-porosity, low-permeability, dense sandstone reservoirs, and may also include conventional reservoir rocks such as shale, sandstone, and limestone, which are not limited in the embodiments of the present application. Among them, well logging is to measure the relevant parameters of the oil well based on the characteristics of the rock formation, such as oil content, radioactivity, conductivity, acoustic properties, and nuclear physical properties. The logging method can be conventional logging methods such as natural gamma, natural potential, micro-gradient, lithology, well diameter, deep lateral, shallow lateral, sound wave, neutron, density, etc., or it can be special methods such as formation dip logging, imaging logging, nuclear magnetic resonance logging, and cable formation logging, which are not limited in the embodiments of the present application. Logging data refers to the data obtained by measuring the downhole strata using logging methods in the process of exploring and developing underground oil and gas deposits. The logging data may include single-point logging data and logging curves, etc., which are not limited in the embodiments of the present application.

[0067] Porosity is used to indicate the proportion of pores in a rock formation, and porosity can reflect the ability of a rock formation to store fluid. There is no unique method for determining the porosity of a reservoir in a target block. When the well condition is good and the pore structure is good, the porosity of the reservoir can be determined based on the intersection diagram of compensated neutron logging and compensated density logging; when the well condition is poor and the pore structure is poor, the porosity of the reservoir can be determined based on compensated sonic logging data. The embodiments of the present application do not limit the method for determining the porosity of a reservoir.

[0068] Permeability can reflect the ability of a rock formation to allow fluid to pass through under a certain pressure difference. Optionally, the permeability of a reservoir can be determined based on the porosity and mud content of the reservoir. Among them, the mud content refers to the ratio of the volume of mud to the total volume of the rock formation. The method for determining the mud content of a reservoir can use the natural potential curve method, the natural gamma logging method, the density logging method, and the intersection plot method, etc. The embodiment of the present application does not limit the method for determining the mud content of a reservoir.

[0069] The porosity and permeability of the reservoir can characterize the pore structure of the reservoir. The pore structure of the reservoir is used to indicate the geometry, size, distribution and connectivity of the pores and throats in the reservoir. Alternatively, the pore structure of the reservoir can be characterized by the ratio of porosity to permeability. It should be noted that the pore structure of the reservoir can be determined based on nuclear magnetic resonance logging data, which is not limited in the embodiments of the present application.

[0070] For example, based on the well logging data of the target area, an image indicating the relationship between porosity and permeability can be obtained, see Figure 4 As shown, Figure 4 It is a schematic diagram of the relationship between porosity and permeability provided according to an embodiment of the present application. Among them, the horizontal axis of the image is porosity, and the unit is "%"; the vertical axis of the image is permeability, and the unit is "mD (millidarcy)". The coordinate points in the image are divided into three categories, namely, fracture-pore type, which means that the voids in the rock formation are mainly fractures; pore-fracture type, which means that the voids in the rock formation are mainly pores; and pore type (small pores), which means that all the voids in the rock formation are pores without fractures. It should be noted that the greater the porosity of the reservoir, the more voids there are in the reservoir, and accordingly, the easier it is for the fluid in the reservoir to pass through, and the greater the permeability of the corresponding reservoir. Figure 4 It can be proved that the porosity and permeability of the reservoir basically show a positive correlation trend.

[0071] In some embodiments, the computer device obtains basic parameters of the target block and then determines reservoir information. Accordingly, based on the logging data of the target block, the computer device determines the porosity, permeability, first information and second information of the reservoir in the target block, the first information includes array induction resistivity at different radial detection depths, and the second information includes the envelope area between the acoustic logging curve and the array induction curve; based on the first information, the computer device determines the invasion parameter; based on the second information, the computer device determines the source-reservoir matching parameter; based on the porosity, permeability and invasion parameters, the computer device determines the mobility parameter.

[0072] Among them, the source-reservoir matching parameter can characterize the matching relationship between the source rock and the reservoir. That is to say, in the sand layer, the source-reservoir matching parameter is used to indicate the oil content; in the non-reservoir layer, the source-reservoir matching parameter is used to indicate the quality of the source rock. Among them, the source rock refers to the rock layer that generates oil, and the reservoir refers to the rock layer that stores oil. When the source rock is adjacent to the reservoir, it means that the matching relationship between the source rock and the reservoir is good; when the reservoir is far away from the source rock, it means that the matching relationship between the source rock and the reservoir is poor. Due to the poor physical properties of the low-porosity and low-permeability tight sandstone reservoir, oil and gas migration is difficult, and tight oil and gas are the reason for the source-reservoir symbiosis or near-source accumulation in the tight sandstone reservoir. Therefore, the source-reservoir matching parameter is an important parameter. Among them, under the same physical and electrical conditions, the source-reservoir matching parameter can be used to distinguish between water layers and oil layers.

[0073] See also Figure 5 As shown, Figure 5 It is a schematic diagram of a source-reservoir matching relationship provided according to an embodiment of the present application. Figure 5 In the middle left image, from shallow to deep layers, there are source rocks, reservoirs, source rocks, and reservoirs. The shallow source rocks are adjacent to the reservoirs, and the deep source rocks are adjacent to the reservoirs. Therefore, the oil wells represented by the left image have good source-reservoir matching in both shallow and deep layers. Figure 5 In the middle right image, from shallow to deep layers are source rocks, reservoirs, and reservoirs. The shallow source rocks are adjacent to the reservoirs, and the deep reservoirs are far away from the source rocks. Therefore, the oil well represented by the right image has good source-reservoir matching in the shallow layer, but poor source-reservoir matching in the deep layer.

[0074] Among them, the fluidity parameters of the reservoir are used to characterize the fluidity of the fluid in the reservoir. The fluidity of the fluid in the reservoir is affected by the size, distribution, connectivity of the pore space in the reservoir and the viscosity, density, volume coefficient and other factors of the fluid. Therefore, based on the porosity, permeability and invasion parameters of the reservoir, the fluidity parameters of the reservoir can be determined.

[0075] In some embodiments, the computer device determines the second information based on the acoustic logging curve and the array sensing curve. Accordingly, the computer device obtains the logging data of the target block, determines the porosity, permeability, first information, acoustic logging curve and array sensing curve of the reservoir in the target block; the computer device normalizes the acoustic logging curve and the array sensing curve to obtain an acoustic normalized curve and a sensing normalized curve, and the coordinate axis of the acoustic logging curve is set opposite to the coordinate axis of the array sensing curve; the computer device determines the envelope area of ​​the acoustic normalized curve and the sensing normalized curve as the second information.

[0076] Among them, the acoustic logging curve is a logging curve determined based on the acoustic time difference logging method. The acoustic time difference logging method refers to measuring the time difference of the glide wave propagating through the formation, thereby determining the lithology and porosity of the rock formation. The array induction curve is a logging curve determined based on the array induction logging method. Array induction logging refers to measuring the conductivity of the medium using the principle of electromagnetic induction, so that water, oil and gas layers can be distinguished, permeable layers can be divided, and the degree of intrusion of drilling mud can be determined. The medium conductivity on the array induction curve changes with the depth of the well.

[0077] Among them, the coordinate axes of the ordinates of the acoustic logging curve and the resistivity logging curve are in the same direction, both representing the detection depth. The coordinate axis of the abscissa of the acoustic logging curve can be set in the opposite direction, for example, the coordinate value decreases from left to right, and the coordinate axis of the abscissa of the resistivity logging curve can be set in the positive direction, for example, the coordinate value increases from left to right. The acoustic logging curve and the array sensing curve are normalized, that is, the parameter value is limited to the range of 0-1, and the acoustic normalized curve and the sensing normalized curve are obtained. The envelope area of ​​the acoustic normalized curve and the sensing normalized curve is determined, that is, the parameter values ​​on the two curves are subtracted. Among them, the larger the envelope area, the better the oil content of the rock formation, that is, the higher the oil saturation; the smaller the envelope area, the worse the oil content of the rock formation, that is, the lower the oil saturation.

[0078] In some embodiments, the intrusion parameter is determined by the first information. Accordingly, based on the first information, the computer device determines multiple ratios of the first resistivity and multiple second resistivities, the first resistivity refers to the array induced resistivity with the largest radial detection depth, and the second resistivity refers to the array induced resistivity at any other radial detection depth; the multiple ratios are multiplied to obtain the intrusion parameter.

[0079] Among them, for the mid-deep saline water slurry completion area in the low-porosity and low-permeability tight sandstone reservoir, it is difficult to evaluate the oil production capacity of the area due to the influence of factors such as lithology, complex pore structure and saline water slurry invasion. Therefore, the invasion parameter is an important parameter that can simultaneously characterize the characteristics of the regional lithology, pore structure and invasion degree.

[0080] Among them, the invasion parameter can be used to expand the characteristic difference between the oil and water layers. The degree of influence caused by liquid invading the water layer and the oil layer is different, that is, the degree of resistivity reduction caused by liquid invading the water layer and the oil layer is different. The degree of influence caused by liquid invading the water layer is smaller than that caused by liquid invading the oil layer. The deeper the liquid invades the water layer and the oil layer, the greater the degree of influence, that is, the greater the reduction in resistivity.

[0081] The array sensing resistivity can be obtained based on the array sensing curve. The first resistivity can be the array sensing resistivity of 120 in (inch), and the second resistivity can be the array sensing resistivity of 10 in, 20 in, 30 in, 60 in, and 90 in. For ease of explanation, the intrusion parameter is named MZ, the first resistivity is named M2RX, and the second resistivity can be named M2R1, M2R2, M2R3, M2R6, and M2R9. Accordingly, the intrusion parameter is shown in the following formula (1).

[0082]

[0083] 302. Based on the reservoir information, determine an index value of a first index of the reservoir, where the index value of the first index is positively correlated with the enrichment degree of oil in the reservoir.

[0084] In the embodiment of the present application, the first index comprehensively characterizes various parameters in the reservoir information. Compared with the use of a single parameter, the use of the first index can more comprehensively represent the characteristics of the reservoir, thereby making the determination result of the oil production capacity of the target block more accurate. Among them, the first index is used to indicate the reservoir storage performance of the reservoir for oil. The higher the enrichment degree of oil in the reservoir, the better the reservoir storage performance of the reservoir for oil. The index value of the first index will be affected by the changes in various parameters in the reservoir information. Optionally, the first index can also be called a "sweet spot" evaluation index.

[0085] In some embodiments, the index value of the first index is determined by the weight coefficient of the parameter in the reservoir information. Accordingly, based on the reservoir information, the computer device determines the weight coefficient of each parameter in the reservoir information, and the weight coefficient is used to indicate the degree of influence of the parameter on the first index; based on the weight coefficient, the computer device performs weighted summation on each parameter to obtain the index value of the first index.

[0086] The parameters in the reservoir information refer to porosity, mobility parameter, invasion parameter and source-reservoir matching parameter. The first index is shown in the following formula (2).

[0087] First index = F (porosity, mobility parameter, invasion parameter, source-reservoir matching parameter) (2) where F represents the weighted sum of the parameters in brackets.

[0088] 303. Based on the well test data of the target block, determine the index value of the oil production index of the test well related to the reservoir.

[0089] In the embodiment of the present application, there may be multiple test wells in the target block, and different test wells may reflect the exploitation characteristics of different parts of the oil and gas deposits. Among them, the test well data refers to the data obtained by regularly measuring pressure, oil production, gas volume, water content, temperature and working conditions using various instruments in the process of developing underground oil and gas deposits. During the test well process, a stable test well method or an unstable method may be used, and the embodiment of the present application does not limit this. Among them, the oil production index is used to indicate the oil production capacity of the reservoir. The higher the index value of the oil production index of the reservoir, the better the oil production capacity of the reservoir.

[0090] In some embodiments, the oil production index is determined by the oil production of the test well and the thickness of the reservoir. Accordingly, based on the well test data of the target block, the computer device determines the oil production of the test well and the thickness of the reservoir; and the ratio of the oil production to the thickness is determined as the index value of the oil production index. The oil production index is shown in the following formula (3).

[0091] Oil production index = oil production / layer thickness (3)

[0092] The oil production can be the daily oil production of the test well or the multi-day oil production of the test well. The unit of oil production can be "liter" or "ton", which is not limited in the embodiments of the present application. The thickness of the reservoir can be divided into massive layers, thick layers, medium-thick layers, thin layers, lamellae and microscopic layers. The unit of the layer thickness of the reservoir can be "meter" or "centimeter", which is not limited in the embodiments of the present application.

[0093] Based on the well logging data and well test data of the target block, an image showing the relationship between parameters and oil production index can be obtained. Figure 6 As shown, Figure 6It is a schematic diagram of the relationship between a parameter and an oil production index provided according to an embodiment of the present application. The horizontal axis of the image is the parameter in the reservoir information, that is, the porosity, fluidity parameter, invasion parameter and source-reservoir matching parameter, and the unit of porosity is "%". The vertical axis of the image is the oil production index, or the liquid production index, and the unit is "liter / meter". The coordinate points of different shapes in the image are used to indicate data with different meanings, and the diagrams in the image are used to indicate the specific meanings of the coordinate points of different shapes, including the liquid production index (self), the oil production index (self), the liquid production index (pressure) and the oil production index (pressure). Among them, the oil production index and the liquid production index show a positive correlation trend with the parameters in the reservoir information, as shown by the arrows in the reference image, indicating that the parameters in the reservoir information can be used to characterize the oil production capacity of the reservoir, and then characterize the oil production capacity of the block. Among them, the distribution band of the coordinate points of each parameter is relatively wide, indicating that the correlation between a single parameter and the oil production capacity of the reservoir is weak, that is, the accuracy of the single parameter characterizing the oil production capacity of the reservoir is low.

[0094] Among them, the liquid production index is used to indicate the liquid production capacity of the reservoir. The higher the index value of the reservoir's liquid production index, the better the reservoir's liquid production capacity. The oil production index is used to indicate the oil production capacity of the reservoir. The higher the index value of the reservoir's oil production index, the better the reservoir's oil production capacity. The oil production index can be divided into two types, namely the oil production index under natural oil production and the oil production index under hydraulic fracturing, that is, the oil production index (self) and the oil production index (pressure). The liquid production index can be divided into two types, namely the liquid production index under natural liquid production and the liquid production index under hydraulic fracturing, that is, the liquid production index (self) and the liquid production index (pressure).

[0095] Among them, fracturing transformation refers to the use of hydraulic action to form cracks in the oil and gas layer during the oil and gas extraction process. In other words, by causing cracks in the stratum, the flow environment of the fluid underground is improved, the circulation area of ​​the fluid underground is increased, and the circulation resistance is reduced, thereby increasing the output of the oil well and improving the production capacity of the oil well. The methods of fracturing transformation are divided into two categories: hydraulic fracturing and high-energy gas fracturing, including fracturing methods such as layered fracturing, selective fracturing, high-pressure fracturing in empty spaces, and test fracturing, which are not limited in the embodiments of the present application. Fracturing fluids include water-based fracturing fluids, oil-based fracturing fluids, foam fracturing fluids, clean fracturing fluids, and emulsion fracturing fluids, etc., which are not limited in the embodiments of the present application.

[0096] 304. Based on the index value of the first index and the index value of the oil production index, a target point is determined in the oil production capacity relationship diagram, the horizontal coordinate of the target point is equal to the index value of the first index, and the vertical coordinate of the target point is equal to the index value of the oil production index.

[0097] In the embodiment of the present application, based on the index value of the first index and the index value of the oil production index, the computer device determines the position of the target point in the oil production capacity relationship diagram. The oil production capacity relationship diagram can be divided into multiple areas, and different areas indicate different oil production capacities.

[0098] For example, see Figure 7 As shown, Figure 7 It is a schematic diagram of an oil production capacity relationship diagram provided according to an embodiment of the present application. The oil production capacity relationship diagram is divided into four areas, namely, a sweet spot area of ​​type I, a sweet spot area of ​​type II, a sweet spot area of ​​type III, and a dry layer area. A sweet spot area of ​​type I is used to indicate that the test well has the ability to produce oil under natural conditions, and the oil production capacity can reach the industrial oil flow standard; a sweet spot area of ​​type II is used to indicate that the test well has the ability to produce oil after fracturing transformation, and the oil production capacity can reach the industrial oil flow standard; a sweet spot area of ​​type III is used to indicate that the test well has the ability to produce oil after fracturing transformation, but the oil production capacity does not reach the industrial oil flow standard; a dry layer area is used to indicate that the test well does not have the ability to produce oil after fracturing transformation. Among them, the indicated oil production capacity is, from high to low, a sweet spot area of ​​type I, a sweet spot area of ​​type II, a sweet spot area of ​​type III, and a dry layer area. Among them, the industrial oil flow standard refers to the minimum stable daily production of a single well test with mining value under existing economic and technical conditions.

[0099] The horizontal coordinate of the image is the first index, and the vertical coordinate of the image is the oil production index, with the unit of "liter / meter". Different types of coordinate points in the image are used to indicate data with different meanings, and the icons in the image are used to indicate the specific meanings of different types of coordinate points. For example, the first block includes sub-blocks such as Es1s, Es1x, Es2 and Es3, the second block includes sub-blocks such as Es1x, Es2 and Es3, and the third block includes sub-blocks such as Es1s, Es1x, Es2 and Es3.

[0100] In some embodiments, based on the distribution of multiple reference test wells, the computer device divides the area in the oil production capacity relationship diagram, and the reference test wells are located in the target block.

[0101] Accordingly, the computer device determines the index value of the reference index of the reference test well and the index value of the reference oil production index. The reference index is used to indicate the storage performance of the reference reservoir where the reference test well is located for oil. The higher the enrichment of the oil in the reference reservoir, the better the storage performance of the reference reservoir for oil. The index value of the reference index is positively correlated with the enrichment of the oil in the reference reservoir. The reference oil production index is used to indicate the oil production capacity of the reference reservoir. The higher the index value of the reference oil production index of the reference reservoir, the better the oil production capacity of the reference reservoir. The ratio of the oil production of the reference test well to the layer thickness of the reference reservoir is determined as the index value of the reference oil production index.

[0102] Accordingly, the reference coordinate point corresponding to the reference test well is determined in the oil production capacity relationship diagram. The abscissa of the reference coordinate point is the index value of the reference index, and the ordinate of the reference coordinate point is the index value of the reference oil production index.

[0103] Accordingly, based on the distribution of the reference coordinate points corresponding to the reference test wells in the oil production capacity relationship diagram, the oil production capacity relationship diagram is divided into a sweet spot area of ​​type I, a sweet spot area of ​​type II, a sweet spot area of ​​type III, and a dry layer area. Among them, when the unit of the oil production index is "ton / meter", under natural conditions, the index value of the reference oil production index of the reference test wells in the sweet spot area of ​​type I is not less than 1; after fracturing transformation, the index value of the reference oil production index of the reference test wells in the sweet spot area of ​​type II is in the range of 0.5 to 1; after fracturing transformation, the index value of the reference oil production index of the reference test wells in the sweet spot area of ​​type III is in the range of 0.05 to 0.5; after fracturing transformation, the index value of the reference oil production index of the reference test wells in the dry layer area is not greater than 0.05. It should be noted that the method for determining the division area of ​​the oil production capacity relationship diagram is not unique, and the embodiments of the present application do not limit this.

[0104] 305. Based on the position of the target point in the oil production capacity relationship diagram, determine the target level to which the test well belongs. The target level is used to indicate the oil production capacity.

[0105] In the embodiment of the present application, based on the position of the target point in the oil production capacity relationship diagram, the computer device determines the area where the target point is located in the oil production capacity relationship diagram, and then determines the target level to which the test well corresponding to the target point belongs. Among them, corresponding to the regional division in the oil production capacity relationship diagram, the level to which the test well belongs includes a class I sweet spot, a class II sweet spot, a class III sweet spot and a dry layer.

[0106] See also Figure 8 As shown, Figure 8 is a schematic diagram of a hierarchical classification provided according to an embodiment of the present application. Among them, the index value of the first index can be used to represent the oil production capacity of the block, but it varies from region to region. Figure 8As shown, when the index value of the first index at the first block is greater than 10, the index value of the first index at the second block is greater than 6, and the index value of the first index at the third block is greater than 5, the reservoir has the ability to produce oil under natural conditions, and the oil production capacity can reach the industrial oil flow standard, which belongs to the first sweet spot; when the index value of the first index at the first block is in the range of 2-10, the index value of the first index at the second block is in the range of 2-6, and the index value of the first index at the third block is in the range of 2-5, the reservoir has the ability to produce oil after fracturing, and the oil production capacity can reach the industrial oil flow standard, which belongs to the second sweet spot; when the index value of the first index is in the range of 1-2, the reservoir has the ability to produce oil after fracturing, but the oil production capacity does not reach the industrial oil flow standard, which belongs to the third sweet spot; when the index value of the first index is less than 1, the reservoir does not have the ability to produce oil after fracturing, and belongs to a dry layer.

[0107] In some embodiments, the reference coordinate point may be retained in the oil production capacity relationship diagram. Accordingly, after determining the target point in the oil production capacity relationship diagram, based on the distance between the target point and the reference coordinate point and the level to which the reference test well belongs, the computer device may determine the target level to which the test well corresponding to the target point belongs. Among them, the reference test well corresponding to the reference coordinate point closest to the target point is determined as the first test well, and the level to which the first test well belongs is determined as the target level to which the test well corresponding to the target point belongs.

[0108] 306. Based on the target level, determine the oil production capacity of the target block.

[0109] In an embodiment of the present application, based on the target level to which the test well belongs, the computer device determines the oil production capacity of the target block to which the test well belongs. Wherein, when multiple test wells in the target block are at different levels, the target block can be further divided into multiple sub-blocks, and the oil production capacity of the sub-block is determined based on the level to which the test wells in the sub-block belong.

[0110] To make the process of determining oil production capacity clearer, see Fig. 9 As shown, Fig. 9It is a schematic diagram of an oil production capacity determination process provided according to an embodiment of the present application. Among them, based on the test production data, the computer equipment determines the oil production, layer thickness, crude oil viscosity, etc.; based on the logging data and well logging data, the computer equipment determines the basic sensitive parameters and performs source-reservoir matching analysis. The computer equipment determines the key parameters of the reservoir oil production capacity. Specifically, based on conventional logging data, the computer equipment determines the porosity and permeability; based on the array sensing resistivity at different radial detection depths, the computer equipment determines the invasion parameters; based on the invasion parameters, permeability, and porosity, the computer equipment determines the fluidity parameters; based on the envelope area of ​​the sonic logging curve and the array sensing curve, the computer equipment determines the source-reservoir matching parameters. Based on the oil production and layer thickness, the computer equipment determines the index value of the oil production index, and based on the porosity, invasion parameters, fluidity parameters and source-reservoir matching parameters, the computer equipment determines the index value of the first index. The computer equipment establishes an oil production capacity relationship diagram and divides the area.

[0111] See also Fig.10 As shown, Fig.10 It is a schematic diagram of the effect of determining oil production capacity provided according to an embodiment of the present application. Fig.10 The upper middle image is the comprehensive logging curve diagram of the fourth block, including lithology curve, mud logging, electrical curve, porosity curve, physical property calculation, fluid evaluation, source rock and oil content, sweet spot evaluation and lithology profile. Fig.10 The lower middle image is the oil production capacity relationship diagram of Block 4. Among them, the first test well in Block 4 belongs to the second sweet spot. After actual mining, the sub-block 4 layers / 22m of the first test well was vented after pressure release, with a daily oil production of 56.07 tons and a small amount of gas, reaching the industrial oil flow standard, verifying the accuracy of the oil production capacity determination method.

[0112] The embodiment of the present application provides a method for determining oil production capacity, which determines basic parameters such as porosity and permeability based on logging data and well test data of a target block under saline water slurry conditions, and introduces relevant parameters such as fluidity parameters, invasion parameters, and source-reservoir matching parameters that can indicate the oil production capacity of the target block, thereby comprehensively reflecting the characteristics of low-porosity and low-permeability dense sandstone reservoirs under saline water slurry conditions, and ensuring the accuracy of the method for determining oil production capacity.

[0113] Fig.11 is a block diagram of an oil production capacity determination device provided according to an embodiment of the present application. The device is used to execute the steps of the above-mentioned oil production capacity determination method. Fig.11 The oil production capacity determination device includes: a first determination module 1101, a second determination module 1102, a third determination module 1103 and a fourth determination module 1104.

[0114] The first determination module 1101 is used to determine the reservoir information of the reservoir in the target block based on the well logging data of the target block, the reservoir information includes porosity, permeability, mobility parameter, invasion parameter and source-reservoir matching parameter, the mobility parameter is used to indicate the fluidity of the fluid in the reservoir, and the invasion parameter is used to indicate the invasion degree of the salt water slurry in the reservoir;

[0115] A second determination module 1102 is used to determine an index value of a first index of the reservoir based on the reservoir information, wherein the index value of the first index is positively correlated with the enrichment degree of oil in the reservoir;

[0116] The third determination module 1103 is used to determine the index value of the oil production index of the test well related to the reservoir based on the well test data of the target block;

[0117] The fourth determination module 1104 is used to determine the oil production capacity of the target block based on the index value of the first index, the index value of the oil production index and the oil production capacity relationship diagram of the target block, wherein the horizontal axis of the oil production capacity relationship diagram is the first index and the vertical axis is the oil production index.

[0118] In some embodiments, Fig.11 is a block diagram of another oil production capacity determination device provided according to an embodiment of the present application. Fig.12 As shown, the device also includes:

[0119] In some embodiments, the first determining module 1101 includes:

[0120] A first determination unit 1201 is used to determine the porosity, permeability, first information and second information of the reservoir in the target block based on the logging data of the target block, the first information including the array induction resistivity at different radial detection depths, and the second information including the envelope area between the acoustic logging curve and the array induction curve;

[0121] A second determining unit 1202 is configured to determine an intrusion parameter based on the first information;

[0122] A third determining unit 1203 is used to determine a source-reservoir matching parameter based on the second information;

[0123] The fourth determining unit 1204 is used to determine the fluidity parameter based on the porosity, permeability and invasion parameter.

[0124] In some embodiments, the first determination unit 1201 is used to obtain logging data of the target block, determine the porosity, permeability, first information, acoustic logging curve and array sensing curve of the reservoir in the target block; normalize the acoustic logging curve and the array sensing curve to obtain an acoustic normalized curve and a sensing normalized curve, and the coordinate axis of the acoustic logging curve is set opposite to the coordinate axis of the array sensing curve; and determine the envelope area of ​​the acoustic normalized curve and the sensing normalized curve as the second information.

[0125] In some embodiments, the second determination unit 1202 is used to determine multiple ratios of a first resistivity to multiple second resistivities based on the first information, where the first resistivity refers to the array induced resistivity at the maximum radial detection depth, and the second resistivity refers to the array induced resistivity at any other radial detection depth; and the multiple ratios are multiplied to obtain the intrusion parameters.

[0126] In some embodiments, the second determination module 1102 is used to determine the weight coefficient of each parameter in the reservoir information based on the reservoir information, and the weight coefficient is used to indicate the influence of the parameter on the first index; based on the weight coefficient, the weighted sum of each parameter is performed to obtain the index value of the first index.

[0127] In some embodiments, the third determination module 1103 is used to determine the oil production of the test well and the thickness of the reservoir based on the well testing data of the target block; and determine the ratio of the oil production and the layer thickness as the index value of the oil production index.

[0128] In some embodiments, the fourth determination module 1104 is used to determine the target point in the oil production capacity relationship diagram based on the index value of the first index and the index value of the oil production index, the horizontal coordinate of the target point is equal to the index value of the first index, and the vertical coordinate of the target point is equal to the index value of the oil production index; based on the position of the target point in the oil production capacity relationship diagram, determine the target level to which the test well belongs, and the target level is used to indicate the oil production capacity; based on the target level, determine the oil production capacity of the target block.

[0129] The embodiment of the present application provides a method for determining oil production capacity, which determines basic parameters such as porosity and permeability based on logging data and well test data of a target block under saline water slurry conditions, and introduces relevant parameters such as fluidity parameters, invasion parameters, and source-reservoir matching parameters that can indicate the oil production capacity of the target block, thereby comprehensively reflecting the characteristics of low-porosity and low-permeability dense sandstone reservoirs under saline water slurry conditions, and ensuring the accuracy of the method for determining oil production capacity.

[0130] It should be noted that: the oil production capacity determination device provided in the above embodiment only uses the division of the above functional modules as an example when running the application program. In actual applications, the above functions can be assigned to different functional modules as needed, that is, the internal structure of the terminal is divided into different functional modules to complete all or part of the functions described above. In addition, the oil production capacity determination device provided in the above embodiment and the oil production capacity determination method embodiment belong to the same concept, and the specific implementation process is shown in the method embodiment, which will not be repeated here.

[0131] Fig.13 1 is a schematic diagram of a terminal structure provided according to an embodiment of the present application. The terminal 1300 may be a portable mobile terminal, such as a smart phone, a tablet computer, an MP3 player (Moving Picture Experts Group Audio Layer III), an MP4 player (Moving Picture Experts Group Audio Layer IV), a laptop computer or a desktop computer. The terminal 1300 may also be referred to as a user device, a portable terminal, a laptop terminal, a desktop terminal or other names.

[0132] Typically, the terminal 1300 includes a processor 1301 and a memory 1302 .

[0133] The processor 1301 may include one or more processing cores, such as a 4-core processor, an 8-core processor, etc. The processor 1301 may be implemented in at least one hardware form of DSP (Digital Signal Processing), FPGA (Field-Programmable Gate Array), and PLA (Programmable Logic Array). The processor 1301 may also include a main processor and a coprocessor. The main processor is a processor for processing data in the awake state, also known as a CPU (Central Processing Unit); the coprocessor is a low-power processor for processing data in the standby state. In some embodiments, the processor 1301 may be integrated with a GPU (Graphics Processing Unit), which is responsible for rendering and drawing the content to be displayed on the display screen. In some embodiments, the processor 1301 may also include an AI (Artificial Intelligence) processor, which is used to process computing operations related to machine learning.

[0134] The memory 1302 may include one or more computer-readable storage media, which may be non-transitory. The memory 1302 may also include a high-speed random access memory, and a non-volatile memory, such as one or more disk storage devices, flash memory storage devices. In some embodiments, the non-transitory computer-readable storage medium in the memory 1302 is used to store at least one computer program, which is used to be executed by the processor 1301 to implement the oil production capacity determination method provided in the method embodiment of the present application.

[0135] In some embodiments, the terminal 1300 may further optionally include: a peripheral device interface 1303 and at least one peripheral device. The processor 1301, the memory 1302 and the peripheral device interface 1303 may be connected via a bus or a signal line. Each peripheral device may be connected to the peripheral device interface 1303 via a bus, a signal line or a circuit board. Specifically, the peripheral device includes: at least one of a radio frequency circuit 1304, a display screen 1305, a camera assembly 1306, an audio circuit 1307 and a power supply 1308.

[0136] The peripheral device interface 1303 may be used to connect at least one peripheral device related to I / O (Input / Output) to the processor 1301 and the memory 1302. In some embodiments, the processor 1301, the memory 1302, and the peripheral device interface 1303 are integrated on the same chip or circuit board; in some other embodiments, any one or two of the processor 1301, the memory 1302, and the peripheral device interface 1303 may be implemented on a separate chip or circuit board, which is not limited in this embodiment.

[0137] The radio frequency circuit 1304 is used to receive and transmit RF (Radio Frequency) signals, also known as electromagnetic signals. The radio frequency circuit 1304 communicates with the communication network and other communication devices through electromagnetic signals. The radio frequency circuit 1304 converts the electrical signal into an electromagnetic signal for transmission, or converts the received electromagnetic signal into an electrical signal. In some embodiments, the radio frequency circuit 1304 includes: an antenna system, an RF transceiver, one or more amplifiers, a tuner, an oscillator, a digital signal processor, a codec chipset, a user identity module card, and the like. The radio frequency circuit 1304 can communicate with other terminals through at least one wireless communication protocol. The wireless communication protocol includes, but is not limited to: the World Wide Web, a metropolitan area network, an intranet, various generations of mobile communication networks (2G, 3G, 4G and 5G), a wireless local area network and / or a WiFi (Wireless Fidelity) network. In some embodiments, the radio frequency circuit 1304 may also include circuits related to NFC (Near Field Communication), which is not limited in this application.

[0138] The display screen 1305 is used to display a UI (User Interface). The UI may include graphics, text, icons, videos, and any combination thereof. When the display screen 1305 is a touch display screen, the display screen 1305 also has the ability to collect touch signals on the surface or above the surface of the display screen 1305. The touch signal can be input to the processor 1301 as a control signal for processing. At this time, the display screen 1305 can also be used to provide virtual buttons and / or virtual keyboards, also known as soft buttons and / or soft keyboards. In some embodiments, the display screen 1305 can be one, set on the front panel of the terminal 1300; in other embodiments, the display screen 1305 can be at least two, respectively set on different surfaces of the terminal 1300 or in a folding design; in other embodiments, the display screen 1305 can be a flexible display screen, set on a curved surface or a folding surface of the terminal 1300. Even, the display screen 1305 can also be set to a non-rectangular irregular shape, that is, a special-shaped screen. The display screen 1305 can be made of materials such as LCD (Liquid Crystal Display) and OLED (Organic Light-Emitting Diode).

[0139] The camera assembly 1306 is used to capture images or videos. In some embodiments, the camera assembly 1306 includes a front camera and a rear camera. Typically, the front camera is disposed on the front panel of the terminal, and the rear camera is disposed on the back of the terminal. In some embodiments, there are at least two rear cameras, which are any one of a main camera, a depth of field camera, a wide-angle camera, and a telephoto camera, so as to realize the fusion of the main camera and the depth of field camera to realize the background blur function, the fusion of the main camera and the wide-angle camera to realize the panoramic shooting and the VR (Virtual Reality) shooting function or other fusion shooting functions. In some embodiments, the camera assembly 1306 may also include a flash. The flash may be a monochrome temperature flash or a dual-color temperature flash. A dual-color temperature flash refers to a combination of a warm light flash and a cold light flash, which can be used for light compensation at different color temperatures.

[0140] The audio circuit 1307 may include a microphone and a speaker. The microphone is used to collect sound waves from the user and the environment, and convert the sound waves into electrical signals and input them into the processor 1301 for processing, or input them into the radio frequency circuit 1304 to achieve voice communication. For the purpose of stereo acquisition or noise reduction, there may be multiple microphones, which are respectively arranged at different parts of the terminal 1300. The microphone may also be an array microphone or an omnidirectional acquisition microphone. The speaker is used to convert the electrical signal from the processor 1301 or the radio frequency circuit 1304 into sound waves. The speaker may be a traditional film speaker or a piezoelectric ceramic speaker. When the speaker is a piezoelectric ceramic speaker, it can not only convert the electrical signal into sound waves audible to humans, but also convert the electrical signal into sound waves inaudible to humans for purposes such as ranging. In some embodiments, the audio circuit 1307 may also include a headphone jack.

[0141] The power supply 1308 is used to power various components in the terminal 1300. The power supply 1308 can be an alternating current, a direct current, a disposable battery, or a rechargeable battery. When the power supply 1308 includes a rechargeable battery, the rechargeable battery can support wired charging or wireless charging. The rechargeable battery can also be used to support fast charging technology.

[0142] In some embodiments, the terminal 1300 further includes one or more sensors 1309 , including but not limited to: an acceleration sensor 1310 , a gyroscope sensor 1311 , a pressure sensor 1312 , an optical sensor 1313 , and a proximity sensor 1314 .

[0143] The acceleration sensor 1310 can detect the magnitude of acceleration on the three coordinate axes of the coordinate system established by the terminal 1300. For example, the acceleration sensor 1310 can be used to detect the components of gravity acceleration on the three coordinate axes. The processor 1301 can control the display screen 1305 to display the user interface in a horizontal view or a vertical view according to the gravity acceleration signal collected by the acceleration sensor 1310. The acceleration sensor 1310 can also be used to collect motion data of games or users.

[0144] The gyro sensor 1311 can detect the body direction and rotation angle of the terminal 1300, and the gyro sensor 1311 can cooperate with the acceleration sensor 1310 to collect the user's 3D actions on the terminal 1300. The processor 1301 can implement the following functions based on the data collected by the gyro sensor 1311: motion sensing (such as changing the UI according to the user's tilt operation), image stabilization during shooting, game control, and inertial navigation.

[0145] The pressure sensor 1312 can be set on the side frame of the terminal 1300 and / or the lower layer of the display screen 1305. When the pressure sensor 1312 is set on the side frame of the terminal 1300, it can detect the user's holding signal of the terminal 1300, and the processor 1301 performs left and right hand recognition or shortcut operation according to the holding signal collected by the pressure sensor 1312. When the pressure sensor 1312 is set on the lower layer of the display screen 1305, the processor 1301 controls the operability controls on the UI interface according to the user's pressure operation on the display screen 1305. The operability controls include at least one of a button control, a scroll bar control, an icon control, and a menu control.

[0146] The optical sensor 1313 is used to collect the ambient light intensity. In one embodiment, the processor 1301 can control the display brightness of the display screen 1305 according to the ambient light intensity collected by the optical sensor 1313. Optionally, when the ambient light intensity is high, the display brightness of the display screen 1305 is increased; when the ambient light intensity is low, the display brightness of the display screen 1305 is decreased. In another embodiment, the processor 1301 can also dynamically adjust the shooting parameters of the camera assembly 1309 according to the ambient light intensity collected by the optical sensor 1313.

[0147] The proximity sensor 1314, also called a distance sensor, is disposed on the front panel of the terminal 1300. The proximity sensor 1314 is used to collect the distance between the user and the front of the terminal 1300. In one embodiment, when the proximity sensor 1314 detects that the distance between the user and the front of the terminal 1300 is gradually decreasing, the processor 1301 controls the display screen 1305 to switch from the screen-on state to the screen-off state; when the proximity sensor 1314 detects that the distance between the user and the front of the terminal 1300 is gradually increasing, the processor 1301 controls the display screen 1305 to switch from the screen-off state to the screen-on state.

[0148] Those skilled in the art will understand that Fig.13 The structure shown in the figure does not constitute a limitation on the terminal 1300, and the terminal 1300 may include more or less components than those shown in the figure, or combine some components, or adopt a different component arrangement.

[0149] Fig.14 It is a structural diagram of a server provided according to an embodiment of the present application. The server 1400 may have relatively large differences due to different configurations or performances, and may include one or more processors (Central Processing Units, CPU) 1401 and one or more memories 1402, wherein the memory 1402 stores at least one computer program, and the at least one computer program is loaded and executed by the processor 1401 to implement the oil production capacity determination method provided by the above-mentioned various method embodiments. Of course, the server may also have components such as a wired or wireless network interface, a keyboard, and an input and output interface for input and output, and the server may also include other components for implementing device functions, which will not be described in detail here.

[0150] The embodiment of the present application also provides a computer-readable storage medium, in which at least one computer program is stored, and the at least one computer program is loaded and executed by a processor to implement the oil production capacity determination method in the above embodiment. For example, the computer-readable storage medium can be a read-only memory (ROM), a random access memory (RAM), a compact disc read-only memory (CD-ROM), a magnetic tape, a floppy disk, and an optical data storage device.

[0151] The embodiment of the present application also provides a computer program product, including a computer program, which is executed by a processor to implement the oil production capacity determination method in the embodiment of the present application.

[0152] A person skilled in the art will understand that all or part of the steps to implement the above embodiments may be accomplished by hardware or by instructing related hardware through a program, and the program may be stored in a computer-readable storage medium, and the above-mentioned storage medium may be a read-only memory, a disk or an optical disk, etc.

[0153] The above description is only an optional embodiment of the present application and is not intended to limit the present application. Any modifications, equivalent substitutions, improvements, etc. made within the spirit and principles of the present application shall be included in the protection scope of the present application.

Claims

1. A method for determining oil production capacity, characterized in that: The method comprises: Based on the well logging data of the target block, the reservoir information of the reservoir in the target block is determined, the reservoir information includes porosity, permeability, mobility parameter, invasion parameter and source-reservoir matching parameter, the mobility parameter is used to indicate the fluidity of the fluid in the reservoir, and the invasion parameter is used to indicate the invasion degree of the salt water slurry in the reservoir; Based on the reservoir information, determining an index value of a first index of the reservoir, wherein the index value of the first index is positively correlated with the enrichment degree of oil in the reservoir; Determining the index value of the oil production index of the test well related to the reservoir based on the well test data of the target block; The oil production capacity of the target block is determined based on the index value of the first index, the index value of the oil production index and the oil production capacity relationship diagram of the target block, the horizontal axis of the oil production capacity relationship diagram is the first index, and the vertical axis is the oil production index.

2. The method according to claim 1, characterized in that: The step of determining reservoir information of a reservoir in the target block based on the well logging data of the target block includes: Based on the logging data of the target block, determine the porosity, the permeability, first information and second information of the reservoir in the target block, wherein the first information includes array induction resistivity at different radial detection depths, and the second information includes an envelope area between the acoustic logging curve and the array induction curve; Based on the first information, determining the intrusion parameter; Based on the second information, determining the source-reservoir matching parameter; The fluidity parameter is determined based on the porosity, the permeability, and the invasion parameter.

3. The method according to claim 2, characterized in that The step of determining the porosity, the permeability, the first information and the second information of the reservoir in the target block based on the well logging data of the target block includes: Acquire logging data of a target block, and determine the porosity, the permeability, the first information, the acoustic logging curve, and the array sensing curve of a reservoir in the target block; Normalizing the acoustic logging curve and the array sensing curve to obtain an acoustic normalized curve and a sensing normalized curve, wherein the coordinate axis of the acoustic logging curve is set opposite to the coordinate axis of the array sensing curve; The envelope areas of the acoustic wave normalized curve and the induction normalized curve are determined as the second information.

4. The method according to claim 2, characterized in that: The determining the intrusion parameter based on the first information includes: Based on the first information, determining multiple ratios of a first resistivity to multiple second resistivities, wherein the first resistivity refers to the array induced resistivity at the maximum radial detection depth, and the second resistivity refers to the array induced resistivity at any other radial detection depth; The multiple ratios are multiplied to obtain the intrusion parameter.

5. The method according to claim 1, characterized in that The step of determining an index value of a first index of the reservoir based on the reservoir information comprises: Based on the reservoir information, determining a weight coefficient of each parameter in the reservoir information, wherein the weight coefficient is used to indicate the degree of influence of the parameter on the first index; Based on the weight coefficients, weighted summation is performed on the parameters to obtain an index value of the first index.

6. The method according to claim 1, characterized in that The step of determining the oil production index value of the test well related to the reservoir based on the test well data of the target block includes: Based on the well test data of the target block, determine the oil production of the test well and the layer thickness of the reservoir; The ratio of the oil production amount to the layer thickness is determined as the index value of the oil production index.

7. The method according to claim 1, characterized in that The determining the oil production capacity of the target block based on the index value of the first index, the index value of the oil production index and the oil production capacity relationship diagram of the target block includes: Based on the index value of the first index and the index value of the oil production index, a target point is determined in the oil production capacity relationship diagram, the abscissa of the target point is equal to the index value of the first index, and the ordinate of the target point is equal to the index value of the oil production index; Based on the position of the target point in the oil production capacity relationship diagram, determining the target level to which the test well belongs, the target level being used to indicate the oil production capacity; Based on the target level, the oil production capacity of the target block is determined.

8. An oil production capacity determination device, characterized in that: The device comprises: A first determination module is used to determine reservoir information of a reservoir in the target block based on well logging data of the target block, wherein the reservoir information includes porosity, permeability, mobility parameter, invasion parameter and source-reservoir matching parameter, wherein the mobility parameter is used to indicate the fluidity of the fluid in the reservoir, and the invasion parameter is used to indicate the invasion degree of saline water slurry in the reservoir; A second determination module is used to determine an index value of a first index of the reservoir based on the reservoir information, wherein the index value of the first index is positively correlated with the enrichment degree of oil in the reservoir; A third determination module is used to determine the index value of the oil production index of the test well related to the reservoir based on the well test data of the target block; The fourth determination module is used to determine the oil production capacity of the target block based on the index value of the first index, the index value of the oil production index and the oil production capacity relationship diagram of the target block, wherein the horizontal axis of the oil production capacity relationship diagram is the first index and the vertical axis is the oil production index.

9. A computer device, characterized in that: The computer device includes a processor and a memory, wherein the memory is used to store at least one computer program, and the at least one computer program is loaded by the processor and executes the oil production capacity determination method according to any one of claims 1 to 7.

10. A computer-readable storage medium, characterized in that: The computer-readable storage medium is used to store at least one computer program, and the at least one computer program is used to execute the oil production capacity determination method according to any one of claims 1 to 7.

11. A computer program product, comprising a computer program, characterized in that When the computer program is executed by a processor, the method for determining oil production capacity according to any one of claims 1 to 7 is implemented.

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