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

Abstract

The application provides an oil production capacity determination method and device, computer equipment and a storage medium, and belongs to the field of oil and gas exploration. The method comprises the following steps: determining reservoir information of a reservoir in a target block based on logging data of the target block; determining reservoir information of the reservoir in the target block based on the logging data 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 related production well of the reservoir based on well testing 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 an oil production capacity relationship diagram. The above technical solution determines related parameters capable of indicating the oil production capacity of the target block based on the logging data and the well testing data of the target block under the condition of a salt water slurry, thereby comprehensively reflecting the characteristics of a low-porosity and low-permeability tight sandstone reservoir under the condition of the salt water slurry, and ensuring the accuracy of the oil production capacity determination method.

Description

Technical Field

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

[0002] In the field of oil and gas exploration, reservoir production capacity is the primary indicator for reservoir development, and accurate prediction of reservoir production capacity is a crucial step in the dynamic analysis of reservoir development. Accurate prediction of reservoir production capacity can help companies rationally allocate resources, conduct production planning and scheduling, and improve production efficiency. Therefore, how to accurately predict reservoir production capacity is a problem that needs to be solved.

[0003] Currently, comprehensive logging methods such as natural gamma, spontaneous potential, and three-porosity logging are commonly used to obtain relevant parameters such as reservoir porosity, permeability, and resistivity, and then 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 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 methods. Summary of the Invention

[0005] This application provides a method, apparatus, computer equipment, and storage medium for determining oil production capacity. It can determine basic parameters such as porosity and permeability using well logging and well test data of a target block under saline slurry conditions. Furthermore, it introduces relevant parameters that indicate the oil production capacity of the target block, such as flowability parameters, invasion parameters, and source-reservoir matching parameters. This comprehensively reflects the characteristics of low-porosity, low-permeability tight sandstone reservoirs under saline slurry conditions, ensuring the accuracy of the oil production capacity determination method. The technical solution is as follows:

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

[0007] 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, flowability parameters, invasion parameters and source-reservoir matching parameters. The flowability parameters are used to indicate the flowability of fluids in the reservoir, and the invasion parameters are used to indicate the degree of invasion of saline slurry into the reservoir.

[0008] Based on the reservoir information, the index value of a first index of the reservoir is determined, and the index value of the first index is positively correlated with the enrichment degree of oil in the reservoir.

[0009] Based on the well test data of the target block, determine the index value of the oil production index of the reservoir-related test wells;

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

[0011] On the other hand, an oil production capacity determining apparatus is provided, the apparatus comprising:

[0012] The first determining module is used to determine the reservoir information of the reservoir in the target block based on the logging data of the target block. The reservoir information includes porosity, permeability, flowability parameters, invasion parameters and source-reservoir matching parameters. The flowability parameters are used to indicate the flowability of fluids in the reservoir, and the invasion parameters are used to indicate the degree of invasion of saline slurry into the reservoir.

[0013] The second determining module is used to determine the 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] The third determining module is used to determine the index value of the oil production index of the reservoir-related test wells based on the well test data of the target block.

[0015] The fourth determining 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] The first determining unit 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 includes array induced resistivity at different radial detection depths, and the second information includes the envelope area between the sonic logging curve and the array induced curve.

[0018] The second determining unit is used to determine the intrusion parameters based on the first information;

[0019] The third determining unit is used to determine the source-storage matching parameters based on the second information;

[0020] The fourth determining unit is used to determine the flowability parameter based on the porosity, the permeability, and the intrusion parameter.

[0021] In some embodiments, the first determining unit is configured to acquire well logging data of a target block, determine the porosity, permeability, first information, sonic logging curve, and array induction curve of the reservoir in the target block; normalize the sonic logging curve and the array induction curve to obtain a normalized sonic logging curve and an induction normalized curve, wherein the coordinate axis of the sonic logging curve is set opposite to the coordinate axis of the array induction curve; and determine the envelope area of ​​the normalized sonic logging curve and the normalized induction curve as the second information.

[0022] In some embodiments, the second determining unit is configured to determine, based on the first information, a plurality of ratios of a first resistivity to a plurality of second resistivityes, wherein 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 with any other radial detection depth; and multiply the plurality of ratios to obtain the intrusion parameter.

[0023] In some embodiments, the second determining module is configured to determine the weighting coefficients of each parameter in the reservoir information based on the reservoir information, wherein the weighting coefficients are used to represent the degree of influence of the parameters on the first index; and to perform a weighted summation of the parameters based on the weighting coefficients to obtain the index value of the first index.

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

[0025] In some embodiments, the fourth determining module is configured 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, wherein 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; determine the target level to which the test well belongs based on the position of the target point in the oil production capacity relationship diagram, wherein the target level is used to indicate oil production capacity; and determine the oil production capacity of the target block based on the target level.

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

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

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

[0029] This application provides a method for determining oil production capacity. By using well logging and well test data of a target block under saline slurry conditions, basic parameters such as porosity and permeability are determined. Relevant parameters that can indicate the oil production capacity of the target block, such as fluidity parameters, invasion parameters, and source-reservoir matching parameters, are introduced to comprehensively reflect the characteristics of low-porosity and low-permeability tight sandstone reservoirs under saline slurry conditions, thus ensuring the accuracy of the oil production capacity determination method. Attached Figure Description

[0030] To more clearly illustrate the technical solutions in the embodiments of this application, the accompanying drawings used in the description of the embodiments will be briefly introduced below. Obviously, the accompanying drawings described below are only some embodiments of this application. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0031] Figure 1 This is a schematic diagram of the implementation environment of a method for determining oil production capacity according to an embodiment of this application;

[0032] Figure 2 This is a flowchart of a method for determining oil production capacity according to an embodiment of this application;

[0033] Figure 3 This is a flowchart of another method for determining oil production capacity according to an embodiment of this application;

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

[0035] Figure 5 This is a schematic diagram of a source-storage matching relationship provided according to an embodiment of this application;

[0036] Figure 6 This is a schematic diagram illustrating the relationship between parameters and the oil production index according to an embodiment of this application;

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

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

[0039] Figure 9 This is a schematic diagram of an oil production capacity determination process provided according to an embodiment of this application;

[0040] Figure 10 This is a schematic diagram illustrating the effect of determining oil production capacity according to an embodiment of this application;

[0041] Figure 11 This is a block diagram of an oil production capacity determination device according to an embodiment of this application;

[0042] Figure 12 This is a block diagram of another oil production capacity determination device provided according to an embodiment of this application;

[0043] Figure 13 This is a schematic diagram of the structure of a terminal according to an embodiment of this application;

[0044] Figure 14 This is a schematic diagram of the structure of a server according to an embodiment of this application. Detailed Implementation

[0045] To make the objectives, technical solutions, and advantages of this application clearer, the embodiments of this application will be described in further detail below with reference to the accompanying drawings.

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

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

[0048] It should be noted that all information (including but not limited to user equipment 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 have been authorized by the user or fully authorized by all parties, and the collection, use, and processing of related data must comply with the relevant laws, regulations, and standards of the relevant countries and regions. For example, the well logging data and well test data involved in this application were obtained with full authorization.

[0049] Figure 1 This is a schematic diagram illustrating the implementation environment of a method for determining oil production capacity according to an embodiment of this application. See also... Figure 1The implementation environment includes terminal 101 and server 102. Terminal 101 and server 102 can be connected directly or indirectly via wired or wireless communication, which is not limited herein.

[0050] In some embodiments, terminal 101 can be various types of terminals such as mobile phones, desktop computers, laptops, tablets, and smartwatches. An application can be installed and run on terminal 101, which can determine the oil production capacity based on relevant data of the target block and display the results. Users can log in to the application to view the determination results of the oil production capacity of the target block. The application is associated with server 102, which provides background services to terminal 101.

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

[0052] In some embodiments, server 102 undertakes the main computing work and terminal 101 undertakes the secondary computing work; or, server 102 undertakes the secondary computing work and terminal 101 undertakes the main computing work; or, server 102 and terminal 101 collaborate on computing using a distributed computing architecture.

[0053] Figure 2 This is a flowchart of a method for determining oil production capacity according to an embodiment of this application. The method is executed by a computer device. See also... Figure 2 The method includes the following steps:

[0054] 201. Based on the logging data of the target block, determine the reservoir information of the reservoir in the target block. The reservoir information includes porosity, permeability, flow parameters, invasion parameters and source-reservoir matching parameters. Flow parameters are used to indicate the flowability of fluids in the reservoir, and invasion parameters are used to indicate the degree of invasion of saline slurry in the reservoir.

[0055] In this embodiment, to more comprehensively characterize the reservoir features in the target block, based on the well logging data of the target block, the computer equipment can acquire not only basic parameters such as porosity and permeability, but also related parameters such as flowability parameters, invasion parameters, and source-reservoir matching parameters. The target block includes low-porosity, low-permeability tight sandstone reservoirs, but may also include conventional reservoir rocks such as shale, sandstone, and limestone; this embodiment does not impose any limitations on this. Well logging data refers to the data obtained by measuring the downhole formation using various instruments during the exploration and development of underground oil and gas deposits. Natural gamma ray, spontaneous potential, three-porosity curves, and array induction logging methods can be used during the well logging process; this embodiment does not impose any limitations on this. Well logging data may include single-point logging data and logging curves; this embodiment does not impose any limitations on this. During drilling, saline cement slurry can be used as the drilling fluid, but freshwater drilling fluid, emulsion drilling fluid, and polymer drilling fluid can also be used; this embodiment does not impose any limitations on this.

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

[0057] In this embodiment, the first index is obtained by comprehensively considering various parameters in the reservoir information. Compared to using a single parameter, using the first index can more comprehensively represent the characteristics of the reservoir, thereby making the determination of the oil production capacity of the target block more accurate. Specifically, the first index indicates the reservoir's ability to store oil; the higher the enrichment of oil in the reservoir, the better its oil storage performance. The value of the first index is affected by changes in the 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 reservoir-related test wells.

[0059] In this embodiment, the target block may have multiple test wells, and different test wells can reflect the exploitation characteristics of different parts of the oil and gas deposit. Well test data refers to the data obtained during the development of underground oil and gas deposits by periodically measuring pressure, oil production, gas volume, water content, temperature, and operating conditions using various instruments. During the well testing process, both stable and unstable testing methods can be used; this embodiment does not impose any restrictions on this. The oil production index is used to indicate the oil production capacity of the reservoir; the higher the oil production index value, the better the oil production capacity of the reservoir.

[0060] 204. 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, determine the oil production capacity 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.

[0061] In this embodiment, the oil production capacity relationship diagram can be divided into multiple regions, with different regions indicating 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 that coordinate point can be determined. Specifically, the oil production capacity of the test wells in the target block can be determined first, and then the oil production capacity of the target block can be determined.

[0062] This application provides a method for determining oil production capacity. By using well logging and well test data of a target block under saline slurry conditions, basic parameters such as porosity and permeability are determined. Relevant parameters that can indicate the oil production capacity of the target block, such as fluidity parameters, invasion parameters, and source-reservoir matching parameters, are introduced to comprehensively reflect the characteristics of low-porosity and low-permeability tight sandstone reservoirs under saline slurry conditions, thus ensuring the accuracy of the oil production capacity determination method.

[0063] Figure 3 This is a flowchart of another method for determining oil production capacity according to an embodiment of this application. This method is executed by a computer device. See [link to flowchart]. Figure 3 The method includes the following steps:

[0064] 301. Based on the logging data of the target block, determine the reservoir information of the reservoir in the target block. The reservoir information includes porosity, permeability, flow parameters, invasion parameters and source-reservoir matching parameters. Flow parameters are used to indicate the flowability of fluids in the reservoir, and invasion parameters are used to indicate the degree of invasion of saline slurry in the reservoir.

[0065] In this embodiment of the application, in order to more comprehensively characterize the reservoir features 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 relevant parameters such as flowability parameters, invasion parameters and source-reservoir matching parameters.

[0066] The target block includes low-porosity, low-permeability tight sandstone reservoirs, but may also include conventional reservoir rocks such as shale, sandstone, and limestone; this application embodiment does not impose any limitations on this. Well logging involves measuring relevant parameters of the oil well based on the oil-bearing properties, radioactivity, electrical conductivity, acoustic properties, and nuclear physics properties of the rock formation. Well logging methods can be conventional methods such as natural gamma ray, spontaneous potential, microgradient, lithology, well diameter, deep lateral, shallow lateral, acoustic, neutron, and density logging, or special methods such as formation dip logging, imaging logging, nuclear magnetic resonance logging, and cable formation logging; this application embodiment does not impose any limitations on this. Well logging data refers to the data obtained by measuring the downhole formation using well logging methods during the exploration and development of underground oil and gas deposits. Well logging data may include single-point logging data and logging curves; this application embodiment does not impose any limitations on this.

[0067] Porosity indicates the proportion of pores in a rock formation and reflects its ability to store fluids. There is no single method for determining the porosity of a reservoir in a target block. When well conditions are good and the pore structure is favorable, reservoir porosity can be determined based on the cross-plot of compensated neutron logging and compensated density logging; when well conditions are poor and the pore structure is unfavorable, reservoir porosity can be determined based on compensated sonic logging data. This application does not limit the method used to determine reservoir porosity.

[0068] Permeability reflects 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 its porosity and clay content. Clay content refers to the ratio of clay volume to the total volume of the rock formation. Methods for determining the clay content of a reservoir include spontaneous potential curves, natural gamma logging, density logging, and cross-plot methods. This application does not limit the methods used to determine the clay content of a reservoir.

[0069] Porosity and permeability of a reservoir can characterize its pore structure. Specifically, the pore structure indicates the geometry, size, distribution, and connectivity of pores and throats within the reservoir. Optionally, the pore structure can be characterized by the ratio of porosity to permeability. It should be noted that the pore structure of a reservoir can be determined based on nuclear magnetic resonance logging data, and this application does not impose any limitations on this.

[0070] For example, based on well logging data from a target block, an image indicating the relationship between porosity and permeability can be obtained; see [link to relevant documentation]. Figure 4 As shown, Figure 4 This is a schematic diagram illustrating the relationship between porosity and permeability according to an embodiment of this application. The horizontal axis of the image represents porosity in "%"; the vertical axis represents permeability in "mD (millidarcy)". The coordinate points in the image are divided into three categories: fracture-pore type, indicating that the voids in the rock layer are mainly fractures; pore-fracture type, indicating that the voids in the rock layer are mainly pores; and pore type (micropores), indicating that the voids in the rock layer are entirely pores, with no fractures. It should be noted that the greater the porosity of the reservoir, the more voids there are in the reservoir, and correspondingly, the easier it is for fluids to pass through the reservoir, resulting in a higher permeability. Figure 4 The porosity and permeability of the middle reservoir generally show a positive correlation, which can be verified.

[0071] In some embodiments, the computer device obtains basic parameters of the target block, thereby determining 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 induced resistivity at different radial depths, and the second information includes the envelope area between the sonic logging curve and the array induced resistivity curve. Based on the first information, the computer device determines invasion parameters. Based on the second information, the computer device determines source-reservoir matching parameters. Based on the porosity, permeability, and invasion parameters, the computer device determines flowability parameters.

[0072] Source-reservoir matching parameters characterize the matching relationship between source rocks and reservoirs. Specifically, in sandstone formations, these parameters indicate oil-bearing potential; in non-reservoir formations, they indicate source rock quality. Source rocks refer to oil-generating formations, and reservoirs refer to oil-bearing formations. When source rocks and reservoirs are adjacent, it indicates a good matching relationship; when the reservoir is far from the source rock, it indicates a poor matching relationship. Due to the poor physical properties of low-porosity, low-permeability tight sandstone reservoirs, hydrocarbon migration is difficult, and tight hydrocarbons are the cause of source-reservoir symbiosis or near-source accumulation in tight sandstone reservoirs. Therefore, source-reservoir matching parameters are crucial. Under the same physical and electrical properties, source-reservoir matching parameters can be used to distinguish between water-bearing and oil-bearing layers.

[0073] See Figure 5 As shown, Figure 5 This is a schematic diagram of a source-storage matching relationship provided according to an embodiment of this application. Figure 5 In the left-hand image, the layers from shallow to deep are source rock, reservoir, source rock, and reservoir. The shallow source rock is adjacent to the reservoir, and the deep source rock is adjacent to the reservoir. Therefore, the source-reservoir matching of the oil well represented by the left-hand image is good in both shallow and deep layers. Figure 5 In the right-hand image, from shallow to deep layers are source rock, reservoir, and reservoir. The shallow source rock is adjacent to the reservoir, while the deep reservoir is far from the source rock. Therefore, the source-reservoir matching of the oil wells represented by the right-hand image is good in the shallow layers and poor in the deep layers.

[0074] Among these parameters, reservoir fluidity parameters characterize the flowability of fluids within the reservoir. The flowability of fluids in a reservoir is influenced by factors such as the size, distribution, and connectivity of the pore space, as well as the fluid's viscosity, density, and volume coefficient. Therefore, reservoir fluidity parameters can be determined based on the reservoir's porosity, permeability, and invasion parameters.

[0075] In some embodiments, the computer device determines the second information based on the acoustic logging curve and the array induction curve. Accordingly, the computer device acquires logging data for the target block, determines the porosity, permeability, first information, acoustic logging curve, and array induction curve of the reservoir in the target block; the computer device normalizes the acoustic logging curve and the array induction curve to obtain a normalized acoustic curve and a normalized induction curve, with the coordinate axes of the acoustic logging curve and the array induction curve set oppositely; the computer device determines the envelope area of ​​the normalized acoustic curve and the normalized induction curve as the second information.

[0076] Among them, the sonic logging curve is a logging curve determined based on the sonic time-of-flight logging method. The sonic time-of-flight logging method measures the time difference of slip waves propagating through the formation, thereby determining the lithology and porosity of the formation. The array induction logging curve is a logging curve determined based on the array induction logging method. Array induction logging uses the principle of electromagnetic induction to measure the conductivity of the medium, thereby distinguishing water, oil, and gas layers, delineating permeable layers, and determining the degree of drilling mud invasion. The conductivity of the medium on the array induction logging curve varies with well depth.

[0077] In this system, the vertical axes of both the sonic logging curve and the resistivity logging curve are aligned, representing the depth of exploration. The horizontal axis of the sonic logging curve can be reversed, for example, decreasing from left to right, while the horizontal axis of the resistivity logging curve can be forward-oriented, for example, increasing from left to right. The sonic logging curve and the array induction logging curve are normalized by limiting the parameter values ​​to the range of 0-1, resulting in normalized sonic and induction logging curves. The envelope area of ​​the normalized sonic and induction logging curves is then determined by subtracting the parameter values ​​from the two curves. A larger envelope area indicates better oil-bearing properties in the formation, meaning higher oil saturation; a smaller envelope area indicates poorer oil-bearing properties, meaning lower oil saturation.

[0078] In some embodiments, intrusion parameters are determined using first information. Accordingly, based on the first information, a computer device determines multiple ratios of a first resistivity to multiple second resistivityes, where 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 with any other radial detection depth; the multiple ratios are multiplied to obtain the intrusion parameters.

[0079] In particular, the evaluation of oil production capacity in the medium-deep saline slurry completion area of ​​low-porosity and low-permeability tight sandstone reservoir is difficult due to factors such as lithology, complex pore structure and saline slurry invasion. Therefore, the invasion parameter can simultaneously characterize the lithology, pore structure and degree of invasion of the area, and is an important parameter.

[0080] Intrusion parameters can be used to amplify the characteristic differences between oil and water layers. The degree of impact of liquid intrusion into water layers and oil layers differs; that is, the magnitude of resistivity reduction caused by liquid intrusion into water layers and oil layers is different. The impact of liquid intrusion into water layers is smaller than that into oil layers. The deeper the liquid intrudes into water layers and oil layers, the greater the impact, that is, the greater the reduction in resistivity.

[0081] The array induced resistivity can be obtained based on the array induction curve. The first resistivity can be an array induced resistivity of 120 in (inch), and the second resistivity can be an array induced 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 reservoir information, determine the index value of the first index of the reservoir. The index value of the first index is positively correlated with the enrichment degree of oil in the reservoir.

[0084] In this embodiment, the first index comprehensively characterizes various parameters in the reservoir information. Compared to using a single parameter, the first index can more comprehensively represent the characteristics of the reservoir, thereby making the determination of the oil production capacity of the target block more accurate. Specifically, the first index indicates the reservoir's ability to store oil; the higher the enrichment of oil in the reservoir, the better its oil storage performance. The value of the first index is affected by changes in various parameters in the reservoir information. Optionally, this 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 weighting coefficients of the parameters in the reservoir information. Accordingly, based on the reservoir information, the computer device determines the weighting coefficients of each parameter in the reservoir information, the weighting coefficients being used to represent the degree of influence of the parameters on the first index; based on the weighting coefficients, the computer device performs a weighted summation of the parameters to obtain the index value of the first index.

[0086] Among them, the parameters in the reservoir information refer to porosity, fluidity parameters, intrusion parameters, and source-reservoir matching parameters. The first index is shown in the following formula (2).

[0087] First index = F(porosity, flowability parameter, intrusion parameter, source-storage matching parameter) (2) where F represents the weighted summation of the parameters in parentheses.

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

[0089] In this embodiment, the target block may have multiple test wells, and different test wells can reflect the exploitation characteristics of different parts of the oil and gas deposit. Well test data refers to the data obtained during the development of underground oil and gas deposits by periodically measuring pressure, oil production, gas volume, water content, temperature, and operating conditions using various instruments. During the well testing process, both stable and unstable testing methods can be used; this embodiment does not impose any restrictions on this. The oil production index is used to indicate the oil production capacity of the reservoir; the higher the oil production index value, 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 reservoir thickness. Accordingly, based on the test well data of the target block, computer equipment determines the oil production of the test well and the reservoir thickness; the ratio of oil production to thickness is determined as 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 a test well or the oil production over multiple days. The unit of oil production can be "liters" or "tons," and this application embodiment does not impose any limitation on this. The reservoir thickness can be classified into blocky layers, thick layers, medium-thick layers, thin layers, shale layers, and microlayers, etc. The unit of reservoir layer thickness can be "meters" or "centimeters," and this application embodiment does not impose any limitation on this.

[0093] Based on well logging and well test data from the target block, a graph representing the relationship between parameters and the oil production index can be obtained. See also... Figure 6 As shown, Figure 6This is a schematic diagram illustrating the relationship between parameters and oil production index according to an embodiment of this application. The horizontal axis of the image represents the parameters in the reservoir information, namely porosity, fluidity parameters, intrusion parameters, and source-reservoir matching parameters. The unit of porosity is "%". The vertical axis of the image represents the oil production index, also known as the liquid production index, with the unit being "liters / meter". Different shaped coordinate points in the image indicate data with different meanings. The diagrams in the image illustrate the specific meanings of the different shaped coordinate points, including the liquid production index (self), oil production index (self), liquid production index (pressure), and oil production index (pressure). The oil production index and liquid production index show a positive correlation with the parameters in the reservoir information. Referring to the arrows in the image, this indicates that the parameters in the reservoir information can be used to characterize the oil production capacity of the reservoir, and thus the oil production capacity of the block. The coordinate point distribution bands for each parameter are relatively wide, indicating that the correlation between a single parameter and the oil production capacity of the reservoir is weak, meaning that the accuracy of characterizing the oil production capacity of a single parameter is low.

[0094] The production index indicates the reservoir's production capacity; a higher production index value indicates better production capacity. Similarly, the oil production index indicates the reservoir's oil production capacity; a higher oil production index value indicates better oil production capacity. Oil production indices can be categorized into two types: those for natural production and those for fracturing (i.e., natural production index and fracturing index). The production index can also be categorized into two types: those for natural production and those for fracturing (i.e., natural production index and fracturing index).

[0095] Fracturing, in this context, refers to the process of creating fractures in oil and gas reservoirs using hydraulic action during oil and gas extraction. In other words, by creating fractures in the formation, the flow environment of fluids underground is improved, the flow area of ​​fluids underground is increased, and the flow resistance is reduced, thereby increasing oil well production and improving the well's productivity. Fracturing methods are broadly classified into hydraulic fracturing and high-energy gas fracturing, including methods such as layered fracturing, selective fracturing, open-slit high-pressure fracturing, and test fracturing. This application does not limit the specific methods used in this embodiment. Fracturing fluids include water-based fracturing fluids, oil-based fracturing fluids, foam fracturing fluids, clean fracturing fluids, and emulsion fracturing fluids, etc., and this application does not limit the specific types of fracturing fluids used in this embodiment.

[0096] 304. Based on the index values ​​of the first index and the oil production index, determine the target point in the oil production capacity relationship diagram. The horizontal axis of the target point is equal to the index value of the first index, and the vertical axis of the target point is equal to the index value of the oil production index.

[0097] In this embodiment of the application, based on the index values ​​of a first index and an oil production index, a computer device determines the location of a target point in an oil production capacity relationship map. The oil production capacity relationship map can be divided into multiple regions, with different regions indicating different oil production capacities.

[0098] For example, see Figure 7 As shown, Figure 7 This is a schematic diagram of an oil production capacity relationship diagram provided according to an embodiment of this application. The oil production capacity relationship diagram is divided into four regions: a first-class sweet spot region, a second-class sweet spot region, a third-class sweet spot region, and a dry layer region. The first-class sweet spot region indicates that the test well has oil production capacity under natural conditions, and the oil production capacity can reach the industrial oil flow standard; the second-class sweet spot region indicates that the test well has oil production capacity after fracturing, and the oil production capacity can reach the industrial oil flow standard; the third-class sweet spot region indicates that the test well has oil production capacity after fracturing, but the oil production capacity does not reach the industrial oil flow standard; the dry layer region indicates that the test well does not have oil production capacity after fracturing. The indicated oil production capacity, from highest to lowest, is as follows: first-class sweet spot region, second-class sweet spot region, third-class sweet spot region, and dry layer region. The industrial oil flow standard refers to the minimum stable daily production of a single well with exploitable value under existing economic and technological conditions.

[0099] In this image, the horizontal axis represents the first index, and the vertical axis represents the oil production index, with units of "liters per meter". Different types of coordinate points in the image indicate different meanings of data, and the illustrations in the image are used to explain 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 production wells, a computer device divides the region in the oil production capacity relationship diagram, with the reference production wells located in the target block.

[0101] Accordingly, computer equipment determines the index values ​​of the reference index and the reference production index for the reference test well. The reference index indicates the oil storage capacity of the reference reservoir where the reference test well is located; a higher degree of oil enrichment in the reference reservoir indicates better oil storage capacity. The index value is positively correlated with the degree of oil enrichment in the reference reservoir. The reference production index indicates the oil production capacity of the reference reservoir; a higher index value indicates better oil production capacity. 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 production index.

[0102] Accordingly, reference coordinate points are determined in the oil production capacity relationship diagram to correspond to the reference test wells. The horizontal axis of the reference coordinate point represents the index value of the reference index, and the vertical axis of the reference coordinate point represents the index value of the reference oil production index.

[0103] Accordingly, based on the distribution of reference coordinate points corresponding to the reference production wells in the oil production capacity relationship diagram, the oil production capacity relationship diagram is divided into three types: sweet spot region, second-class sweet spot region, third-class sweet spot region, and dry layer region. Specifically, when the unit of oil production index is "tons / meter," under natural conditions, the reference oil production index value of the reference production wells in the first-class sweet spot region is not less than 1; after fracturing, the reference oil production index value of the reference production wells in the second-class sweet spot region is in the range of 0.5 to 1; after fracturing, the reference oil production index value of the reference production wells in the third-class sweet spot region is in the range of 0.05 to 0.5; and after fracturing, the reference oil production index value of the reference production wells in the dry layer region is not greater than 0.05. It should be noted that the method for determining the division of the oil production capacity relationship diagram is not unique, and this application embodiment does not impose any limitations on it.

[0104] 305. Based on the location 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 this embodiment, based on the location of the target point in the oil production capacity relationship diagram, the computer device determines the region where the target point is located in the oil production capacity relationship diagram, and then determines the target layer to which the test well corresponding to the target point belongs. Corresponding to the regional division in the oil production capacity relationship diagram, the layers to which the test well belongs include Class I sweet spots, Class II sweet spots, Class III sweet spots, and dry layers.

[0106] See Figure 8 As shown, Figure 8 This is a schematic diagram of a hierarchical classification according to an embodiment of this application. The oil production capacity of a block can be characterized by the index value of a first index, but this varies across different regions. See also... Figure 8As shown, when the index value of the first index in the first block is greater than 10, the index value of the first index in the second block is greater than 6, and the index value of the first index in the third block is greater than 5, the reservoir has oil production capacity under natural conditions, and the oil production capacity can reach the industrial oil flow standard, belonging to the first sweet spot. When the index value of the first index in the first block is in the range of 2-10, the index value of the first index in the second block is in the range of 2-6, and the index value of the first index in the third block is in the range of 2-5, the reservoir has oil production capacity after fracturing, and the oil production capacity can reach the industrial oil flow standard, belonging to the second sweet spot. When the index value of the first index is in the range of 1-2, the reservoir has oil production capacity after fracturing, but the oil production capacity does not reach the industrial oil flow standard, belonging to the third sweet spot. When the index value of the first index is less than 1, the reservoir does not have oil production capacity after fracturing, belonging to the dry reservoir.

[0107] In some embodiments, reference coordinate points 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 layer to which the reference test well belongs, the computer equipment can determine the target layer to which the test well corresponding to the target point belongs. Specifically, the reference test well corresponding to the reference coordinate point closest to the target point is determined as the first test well, and the layer to which the first test well belongs is determined as the target layer 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 this embodiment, the computer equipment determines the oil production capacity of the target block to which the test well belongs, based on the target layer to which the test well belongs. When multiple test wells in a target block are at different layers, the target block can be further divided into multiple sub-blocks, and the oil production capacity of each sub-block is determined based on the layer to which the test wells in the sub-blocks belong.

[0110] To make the process of determining oil production capacity clearer, see [link to relevant documentation]. Figure 9 As shown, Figure 9This is a schematic diagram of an oil production capacity determination process according to an embodiment of this application. Based on pilot production data, computer equipment determines oil production, layer thickness, crude oil viscosity, etc.; based on logging and well logging data, computer equipment determines basic sensitive parameters and performs source-reservoir matching analysis. The computer equipment determines key parameters of reservoir oil production capacity. Specifically, based on conventional well logging data, the computer equipment determines porosity and permeability; based on array inductive resistivity at different radial depths, the computer equipment determines invasion parameters; based on invasion parameters, permeability, and porosity, the computer equipment determines flowability parameters; based on the envelope area of ​​the sonic logging curve and the array inductive curve, the computer equipment determines source-reservoir matching parameters. Based on oil production and layer thickness, the computer equipment determines the index value of the oil production index; based on porosity, invasion parameters, flowability 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 region.

[0111] See Figure 10 As shown, Figure 10 This is a schematic diagram illustrating the effect of determining oil production capacity according to an embodiment of this application. Figure 10 The upper-middle image is a comprehensive logging curve diagram of the fourth block, including lithology curves, logging data, electrical properties curves, porosity curves, physical property calculations, fluid evaluation, source rocks and oil-bearing properties, sweet spot evaluation, and lithological profile data. Figure 10 The lower middle image shows the oil production capacity relationship of Block 4. The first test well in Block 4 is classified as a Class II sweet spot. After actual production, the sub-block described by the first test well, with 4 layers / 22m, produced 56.07 tons of oil and a small amount of gas per day after pressure release, meeting industrial oil flow standards and verifying the accuracy of the oil production capacity determination method.

[0112] This application provides a method for determining oil production capacity. By using well logging and well test data of a target block under saline slurry conditions, basic parameters such as porosity and permeability are determined. Relevant parameters that can indicate the oil production capacity of the target block, such as fluidity parameters, invasion parameters, and source-reservoir matching parameters, are introduced to comprehensively reflect the characteristics of low-porosity and low-permeability tight sandstone reservoirs under saline slurry conditions, thus ensuring the accuracy of the oil production capacity determination method.

[0113] Figure 11 This is a block diagram of an oil production capacity determination apparatus according to an embodiment of this application. The apparatus is used to perform the steps of the above-described oil production capacity determination method, see [link to relevant documentation]. Figure 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 determining module 1101 is used to determine the reservoir information of the reservoir in the target block based on the logging data of the target block. The reservoir information includes porosity, permeability, flow parameters, invasion parameters and source-reservoir matching parameters. The flow parameters are used to indicate the flowability of fluids in the reservoir, and the invasion parameters are used to indicate the degree of invasion of saline slurry in the reservoir.

[0115] The second determining module 1102 is used to determine the index value of the first index of the reservoir based on the reservoir information. 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 reservoir-related test wells based on the well test data of the target block.

[0117] The fourth determining 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. 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, Figure 11 This is a block diagram of another oil production capacity determining device according to an embodiment of this application. See also... Figure 12 As shown, the device also includes:

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

[0120] The first determining 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 includes the array induced resistivity at different radial detection depths, and the second information includes the envelope area between the sonic logging curve and the array induced curve.

[0121] The second determining unit 1202 is used to determine the intrusion parameters based on the first information;

[0122] The third determining unit 1203 is used to determine the source-storage matching parameters based on the second information;

[0123] The fourth determining unit 1204 is used to determine the flow parameters based on porosity, permeability and intrusion parameters.

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

[0125] In some embodiments, the second determining unit 1202 is configured to determine, based on first information, multiple ratios of a first resistivity to multiple second resistivitys, wherein 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 with any other radial detection depth; and multiply the multiple ratios to obtain an intrusion parameter.

[0126] In some embodiments, the second determining module 1102 is used to determine the weight coefficients of each parameter in the reservoir information based on the reservoir information, wherein the weight coefficients are used to represent the degree of influence of the parameters on the first index; and to perform a weighted summation of each parameter based on the weight coefficients to obtain the index value of the first index.

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

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

[0129] This application provides a method for determining oil production capacity. By using well logging and well test data of a target block under saline slurry conditions, basic parameters such as porosity and permeability are determined. Relevant parameters that can indicate the oil production capacity of the target block, such as fluidity parameters, invasion parameters, and source-reservoir matching parameters, are introduced to comprehensively reflect the characteristics of low-porosity and low-permeability tight sandstone reservoirs under saline slurry conditions, thus ensuring the accuracy of the oil production capacity determination method.

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

[0131] Figure 13 This is a schematic diagram of a terminal according to an embodiment of this application. The terminal 1300 can be a portable mobile terminal, such as a smartphone, tablet computer, MP3 player (Moving Picture Experts Group Audio Layer III), MP4 player (Moving Picture Experts Group Audio Layer IV), laptop computer, or desktop computer. The terminal 1300 may also be referred to as a user device, portable terminal, laptop terminal, desktop terminal, or other names.

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

[0133] Processor 1301 may include one or more processing cores, such as a quad-core processor, an octa-core processor, etc. Processor 1301 may be implemented using at least one hardware form selected from DSP (Digital Signal Processing), FPGA (Field-Programmable Gate Array), and PLA (Programmable Logic Array). Processor 1301 may also include a main processor and a coprocessor. The main processor, also known as a CPU (Central Processing Unit), is used to process data in the wake-up state; the coprocessor is a low-power processor used to process data in the standby state. In some embodiments, processor 1301 may integrate a GPU (Graphics Processing Unit), which is responsible for rendering and drawing the content required to be displayed on the screen. In some embodiments, processor 1301 may also include an AI (Artificial Intelligence) processor, which is used to handle computational 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 high-speed random access memory and non-volatile memory, such as one or more disk storage devices or flash memory devices. In some embodiments, the non-transitory computer-readable storage media in the memory 1302 are used to store at least one computer program, which is executed by the processor 1301 to implement the oil production capacity determination method provided in the method embodiments of this application.

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

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

[0137] The radio frequency (RF) circuit 1304 is used to receive and transmit RF (Radio Frequency) signals, also known as electromagnetic signals. The RF circuit 1304 communicates with communication networks and other communication devices via electromagnetic signals. The RF circuit 1304 converts electrical signals into electromagnetic signals for transmission, or converts received electromagnetic signals back into electrical signals. In some embodiments, the RF 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, etc. The RF circuit 1304 can communicate with other terminals through at least one wireless communication protocol. This wireless communication protocol includes, but is not limited to: the World Wide Web, metropolitan area networks, intranets, various generations of mobile communication networks (2G, 3G, 4G, and 5G), wireless local area networks, and / or WiFi (Wireless Fidelity) networks. In some embodiments, the RF circuit 1304 may also include circuitry related to NFC (Near Field Communication), which is not limited in this application.

[0138] Display screen 1305 is used to display a UI (User Interface). This UI may include graphics, text, icons, videos, and any combination thereof. When display screen 1305 is a touch display screen, it also has the ability to collect touch signals on or above its surface. These touch signals can be input as control signals to processor 1301 for processing. In this case, display screen 1305 can also be used to provide virtual buttons and / or a virtual keyboard, also known as soft buttons and / or a soft keyboard. In some embodiments, there may be one display screen 1305, disposed on the front panel of terminal 1300; in other embodiments, there may be at least two display screens, disposed on different surfaces of terminal 1300 or in a folded design; in still other embodiments, display screen 1305 may be a flexible display screen, disposed on a curved or folded surface of terminal 1300. Furthermore, display screen 1305 may be configured as a non-rectangular, irregular shape, i.e., a non-rectangular 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 acquire images or videos. In some embodiments, the camera assembly 1306 includes a front-facing camera and a rear-facing camera. Typically, the front-facing camera is located on the front panel of the terminal, and the rear-facing camera is located on the back of the terminal. In some embodiments, there are at least two rear-facing cameras, which are any one of a main camera, a depth-sensing camera, a wide-angle camera, and a telephoto camera, to achieve background blurring by fusion of the main camera and the depth-sensing camera, panoramic shooting by fusion of the main camera and the wide-angle camera, VR (Virtual Reality) shooting, or other fusion shooting functions. In some embodiments, the camera assembly 1306 may also include a flash. The flash can be a single-color temperature flash or a dual-color temperature flash. A dual-color temperature flash refers to a combination of a warm-light flash and a cool-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, converting the sound waves into electrical signals that are input to the processor 1301 for processing, or input to the radio frequency circuit 1304 for voice communication. For stereo sound acquisition or noise reduction purposes, multiple microphones may be used, each located at a different part of the terminal 1300. The microphone may also be an array microphone or an omnidirectional microphone. The speaker is used to convert electrical signals from the processor 1301 or the radio frequency circuit 1304 into sound waves. The speaker may be a conventional diaphragm speaker or a piezoelectric ceramic speaker. When the speaker is a piezoelectric ceramic speaker, it can convert electrical signals not only into audible sound waves but also into inaudible sound waves for purposes such as distance measurement. In some embodiments, the audio circuit 1307 may also include a headphone jack.

[0141] Power supply 1308 is used to power the various components in terminal 1300. Power supply 1308 can be AC ​​power, DC power, a disposable battery, or a rechargeable battery. When 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. The one or more sensors 1309 include, but are 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] Accelerometer 1310 can detect the magnitude of acceleration along the three coordinate axes of a coordinate system established by terminal 1300. For example, accelerometer 1310 can be used to detect the components of gravitational acceleration along the three coordinate axes. Processor 1301 can control display screen 1305 to display the user interface in either a landscape or portrait view based on the gravitational acceleration signal acquired by accelerometer 1310. Accelerometer 1310 can also be used for games or for acquiring user motion data.

[0144] The gyroscope sensor 1311 can detect the orientation and rotation angle of the terminal 1300. The gyroscope sensor 1311 can work in conjunction with the accelerometer sensor 1310 to acquire the user's 3D movements on the terminal 1300. Based on the data acquired by the gyroscope sensor 1311, the processor 1301 can perform the following functions: motion sensing (e.g., changing the UI based on the user's tilt), image stabilization during shooting, game control, and inertial navigation.

[0145] The pressure sensor 1312 can be disposed on the side bezel of the terminal 1300 and / or on the lower layer of the display screen 1305. When the pressure sensor 1312 is disposed on the side bezel of the terminal 1300, it can detect the user's grip signal on the terminal 1300, and the processor 1301 can perform left / right hand recognition or quick operation based on the grip signal collected by the pressure sensor 1312. When the pressure sensor 1312 is disposed on the lower layer of the display screen 1305, the processor 1301 can control the operable controls on the UI interface based on the user's pressure operation on the display screen 1305. The operable controls include at least one of button controls, scroll bar controls, icon controls, and menu controls.

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

[0147] The proximity sensor 1314, also known as the distance sensor, is installed on the front panel of the terminal 1300. The proximity sensor 1314 is used to detect 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 a screen-on state to a 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 a screen-off state to a screen-on state.

[0148] Those skilled in the art will understand that Figure 13 The structure shown does not constitute a limitation on terminal 1300 and may include more or fewer components than shown, or combine certain components, or use different component arrangements.

[0149] Figure 14 This is a schematic diagram of a server structure according to an embodiment of this application. The server 1400 can vary considerably due to different configurations or performance. It may include one or more Central Processing Units (CPUs) 1401 and one or more memories 1402. The memory 1402 stores at least one computer program, which is loaded and executed by the processor 1401 to implement the oil production capacity determination method provided in the above-described method embodiments. Of course, the server may also have wired or wireless network interfaces, a keyboard, and input / output interfaces for input and output. The server may also include other components for implementing device functions, which will not be elaborated here.

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

[0151] This application also provides a computer program product, including a computer program that is executed by a processor to implement the oil production capacity determination method in this application embodiment.

[0152] Those skilled in the art will understand that all or part of the steps of the above embodiments can be implemented by hardware or by a program instructing related hardware. The program can be stored in a computer-readable storage medium, such as a read-only memory, a disk, or an optical disk.

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

Claims

1. A method for determining oil production capacity, characterized in that, The method includes: 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, flowability parameters, invasion parameters and source-reservoir matching parameters. The flowability parameters are used to indicate the flowability of fluids in the reservoir, and the invasion parameters are used to indicate the degree of invasion of saline slurry into the reservoir. Based on the reservoir information, the index value of a first index of the reservoir is determined, and the index value of the first index is positively correlated with the enrichment degree of oil in the reservoir. Based on the well test data of the target block, determine the index value of the oil production index of the reservoir-related test wells; 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 oil production capacity of the target block is determined, wherein the horizontal axis of the oil production capacity relationship diagram is the first index, and the vertical axis is the oil production index; The determination of reservoir information in the target block based on well logging data includes: Based on well logging data from the target block, the porosity, permeability, first information, and second information of the reservoir in the target block are determined. The first information includes array induced resistivity at different radial depths, and the second information includes the envelope area between the sonic logging curve and the array induced resistivity curve. Based on the first information, the invasion parameter is determined. Based on the second information, the source-reservoir matching parameter is determined. Based on the porosity, permeability, and invasion parameter, the flowability parameter is determined. The step of determining the intrusion parameters based on the first information includes: Based on the first information, a plurality of ratios between the first resistivity and a plurality of second resistivity are determined, wherein 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 plurality of ratios are multiplied together to obtain the intrusion parameter; Wherein, determining the index value of the first index of the reservoir based on the reservoir information includes: Based on the reservoir information, a weighting coefficient is determined for each parameter in the reservoir information. The weighting coefficient is used to represent the degree of influence of the parameter on the first index. Based on the weighting coefficient, the parameters are weighted and summed to obtain the index value of the first index.

2. The method according to claim 1, characterized in that, The well logging data based on the target block determines the porosity, permeability, first information, and second information of the reservoir in the target block, including: Obtain logging data for the target block and determine the porosity, permeability, first information, sonic logging curve, and array induction curve of the reservoir in the target block; The acoustic logging curve and the array induction curve are normalized to obtain the acoustic normalized curve and the induction normalized curve. The coordinate axes of the acoustic logging curve and the array induction curve are set opposite to each other. The envelope area of ​​the sound wave normalization curve and the induction normalization curve is determined as the second information.

3. The method according to claim 1, characterized in that, The determination of the production index value of the reservoir-related test wells based on the well test data of the target block includes: Based on the well test data of the target block, the oil production of the test well and the layer thickness of the reservoir are determined. The ratio of the oil production to the layer thickness is determined as the index value of the oil production index.

4. The method according to claim 1, characterized in that, The determination of 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, wherein 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 location of the target point in the oil production capacity relationship diagram, the target level to which the test well belongs is determined, and the target level is used to indicate the oil production capacity; Based on the target level, the oil production capacity of the target block is determined.

5. An oil production capacity determination device, characterized in that, The device includes: The first determining module is used to determine the reservoir information of the reservoir in the target block based on the logging data of the target block. The reservoir information includes porosity, permeability, flowability parameters, invasion parameters and source-reservoir matching parameters. The flowability parameters are used to indicate the flowability of fluids in the reservoir, and the invasion parameters are used to indicate the degree of invasion of saline slurry into the reservoir. The second determining module is used to determine the 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. The third determining module is used to determine the index value of the oil production index of the reservoir-related test wells based on the well test data of the target block. The fourth determining 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. The first determining module is configured to determine, based on well logging data of the target block, the porosity, permeability, first information, and second information of the reservoir in the target block, wherein the first information includes array induced resistivity at different radial depths, and the second information includes the envelope area between the sonic logging curve and the array induced resistivity curve; determine the invasion parameter based on the first information; determine the source-reservoir matching parameter based on the second information; and determine the flowability parameter based on the porosity, permeability, and invasion parameter. The first determining module is configured to determine, based on the first information, multiple ratios of a first resistivity to multiple second resistivityes, wherein 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; and multiply the multiple ratios to obtain the intrusion parameter. The second determining module is used to determine the weight coefficient of each parameter in the reservoir information based on the reservoir information, wherein the weight coefficient is used to represent the degree of influence of the parameter on the first index; and to perform a weighted summation of the parameters based on the weight coefficient to obtain the index value of the first index.

6. A computer device, characterized in that, The computer device includes a processor and a memory, the memory being used to store at least one computer program, the at least one computer program being loaded by the processor and executed as the oil production capacity determination method according to any one of claims 1 to 4.

7. A computer-readable storage medium, characterized in that, The computer-readable storage medium is used to store at least one computer program for performing the oil production capacity determination method according to any one of claims 1 to 4.

8. A computer program product, comprising a computer program, characterized in that, When the computer program is executed by the processor, it implements the oil production capacity determination method as described in any one of claims 1 to 4.

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