A management method and device for efficient development of oil fields

Abstract

The present application discloses a management method and device for efficient development of oil fields, which relates to the field of petroleum and natural gas engineering technology. According to the geographical location of the platform in the target block of oil field development, the distribution of production wells and geological conditions, the target block is divided into multiple management units; the target production well is selected, the sampling location and depth are determined, the core is drilled from the target production well, and the basic parameters of the core are obtained; the key index is calculated according to the basic parameters of the core, and the reservoir development index is calculated according to the key index; the decline index is calculated by combining the total decline degree and the weekly decline degree; the efficient management index is calculated by combining the reservoir development index and the decline index; the interval is divided according to the specific value of the efficient management index, the management strategy of the corresponding production well is formulated, and the production well is uniformly managed in the management unit. The problem that the existing management method is difficult to fully reflect the complexity and dynamics in the process of oil field development and its practicality is not strong is solved.

Description

Technical Field

[0001] The present application relates to the field of petroleum and natural gas engineering technology, and in particular to a management method and device for efficient development of oil fields. Background Art

[0002] As global energy demand continues to grow, the exploration and development of oil and gas resources has become the key to energy security and stable economic development.

[0003] Existing methods mostly focus on the analysis of static geological engineering data, lack the ability to track and respond to the dynamic changes of oilfield production in real time, and are difficult to fully reflect the complexity and dynamics of oilfield development. Decision-making systems based on static data may affect the accuracy of decisions due to data reliability issues; at the same time, due to the lack of full consideration of actual production dynamics, the practicality of management methods is not strong. Although reservoir numerical simulation can simulate the oilfield production process, its assumptions are often quite different from the actual reservoir characteristics, which makes it difficult for simulation results to accurately reflect the actual production situation, limiting its promotion and application.

[0004] How to build a set of management methods for efficient development covering the entire life cycle of an oil field based on the core factors affecting efficient development, namely, accurate analysis of reservoir geological characteristics and real-time monitoring of production dynamic characteristics, has become a problem to be solved. Summary of the invention

[0005] In the embodiments of the present application, by providing a management method for efficient oil field development, the problem that the existing management methods are difficult to fully reflect the complexity and dynamics of the oil field development process and are not very practical is solved.

[0006] In a first aspect, an embodiment of the present application provides a management method for efficient development of an oil field, the method comprising: dividing the target block into a plurality of management units according to the geographical location of the platform in the target block of the oil field development, the distribution of production wells and geological conditions; wherein each management unit comprises a plurality of production wells; selecting a target production well, determining the sampling location and depth, drilling a core from the target production well, and obtaining basic parameters of the core; calculating a key index according to the basic parameters of the core, and calculating a reservoir development index according to the key index; wherein the key index comprises a storage index, a movable index and a transformation index; using a preset number of weeks of production data, calculating the total decline and the weekly decline, and calculating the decline index in combination with the total decline and the weekly decline; the calculation formula for the total decline is: ;in, is the total decreasing degree, The data value of the weekly production data for the first week, is the data value of the weekly production data of the mth week, where m is the total number of weeks; the calculation formula for the weekly decrease is: ;in, is the weekly decreasing degree, is the data value of the week number of the jth week, is the data value of the weekly production data of the jth week, and m is the total number of weeks; the calculation formula for calculating the decline index by combining the total decline degree and the weekly decline degree is: .in, is a decreasing index, is the total decreasing degree, The weekly decline degree is calculated by combining the reservoir development index and the decline index. The efficient management index is divided into intervals according to the specific value of the efficient management index, and the management strategies for corresponding production wells are formulated according to different intervals, so that the production wells are managed uniformly in the management unit.

[0007] In a possible implementation, before selecting the target production well, the method includes: collecting the mine production data of all the production wells in each management unit.

[0008] In a possible implementation, the basic parameters of the core include single mineral percentage, porosity, permeability and mechanical parameters.

[0009] In a possible implementation, the mineral percentage is obtained by using an X-ray diffractometer to test the percentage of a single mineral in a core; the porosity is obtained by using a helium porosimeter to measure the effective porosity and the absolute porosity of the core; the permeability is obtained by using a mercury injection method to measure the permeability of the core; and the mechanical parameters are obtained by using a triaxial rock mechanics testing system to measure the Young's modulus of the core.

[0010] In one possible implementation, the storage index is calculated by multiplying the ratio of the absolute porosity of the current core to the maximum absolute porosity of the core in the same rock reservoir by the ratio of the permeability of the current core to the maximum permeability of the core in the same rock reservoir.

[0011] In a possible implementation, the calculation formula of the movable index is: ;in, is the movable index, is the effective porosity of the current core, is the absolute porosity of the current core, is the Young's modulus of a single mineral in the current core, is the percentage content of single mineral in the current core, is the Young's modulus of the current core, i is the index variable, which is used to traverse all the single minerals in the current core in the summation operation. is the total number of single minerals in the current core.

[0012] In a possible implementation, the transformation index is calculated as follows: ;in, is the transformation index, is the percentage content of single mineral in the current core, is the Young's modulus of a single mineral in the current core, is the Young's modulus of the current core, i is the index variable, which is used to traverse all the single minerals in the current core in the summation operation. is the total number of single minerals in the current core.

[0013] In a possible implementation, the interval is divided according to the specific value of the high-efficiency management index, and the management strategy of the corresponding production well is formulated according to different intervals, and the production wells are uniformly managed in the management unit, including: if the specific value of the high-efficiency management index is less than or equal to the first preset threshold, the production well corresponding to this interval is a high-efficiency development well, and its management strategy is to maintain and optimize the existing production conditions to ensure long-term efficient production; wherein, the value of the first preset threshold is 0.35; if the high-efficiency management index is greater than the first preset threshold and less than or equal to the second preset threshold, the production well corresponding to this interval is a well that needs to be optimized, and its management strategy is to identify and optimize the key factors affecting production; wherein, the value of the second preset threshold is 0.50; if the high-efficiency management index is greater than the second preset threshold and less than or equal to the third preset threshold, the production well corresponding to this interval is a well that needs efficiency improvement, and its management strategy is to deeply analyze the reasons for inefficiency and take targeted measures; wherein, the value of the third preset threshold is 1.0.

[0014] In a second aspect, an embodiment of the present application provides a management device for efficient development of an oil field, the device comprising: a division module, for dividing the target block into a plurality of management units according to the geographical location of the platform in the target block of the oil field development, the distribution of production wells and geological conditions; wherein each management unit comprises a plurality of production wells; a selection module, for selecting the target production well, determining the sampling location and depth, drilling the core from the target production well, and obtaining the basic parameters of the core; a first calculation module, for calculating the key index according to the basic parameters of the core, and calculating the reservoir development index according to the key index; wherein the key index comprises a storage index, a movable index and a transformation index; a second calculation module, for calculating the total decline rate and the weekly decline rate using the production data of a preset number of weeks, and calculating the decline index in combination with the total decline rate and the weekly decline rate; the calculation formula of the total decline rate is: ;in, is the total decreasing degree, The data value of the weekly production data for the first week, is the data value of the weekly production data of the mth week, where m is the total number of weeks; the calculation formula for the weekly decrease is: ;in, is the weekly decreasing degree, is the data value of the week number of the jth week, is the data value of the weekly production data of the jth week, and m is the total number of weeks; the calculation formula for calculating the decline index by combining the total decline degree and the weekly decline degree is: ;in, is a decreasing index, is the total decreasing degree, The third calculation module is used to calculate the efficient management index by combining the reservoir development index and the decline index; the management module is used to divide the intervals according to the specific values ​​of the efficient management index, and formulate management strategies for corresponding production wells according to different intervals, so as to uniformly manage the production wells in the management unit.

[0015] One or more technical solutions provided in the embodiments of the present application have at least the following technical effects:

[0016] The embodiment of the present application provides a management method for efficient development of oil fields. By dividing the target block into multiple management units and performing refined management, the resource potential and development potential of each region can be more accurately evaluated, so as to formulate a more scientific and reasonable mining plan and improve the overall resource utilization efficiency. By drilling cores and obtaining basic parameters, key indexes and reservoir development indexes are calculated, providing detailed data support for oil field development. These data can directly reflect the physical properties, fluid flow capacity and transformation potential of the reservoir, provide a scientific basis for production decisions, help optimize mining plans, and reduce blindness and uncertainty. The total decline and weekly decline are calculated using production data, and the decline index is obtained based on this, which can accurately predict the changing trend of oil field production. This is of great significance for formulating long-term production plans, adjusting mining intensity, and extending the stable production period of oil fields, and helps to achieve sustainable development of oil fields. The efficient management index is calculated in combination with the reservoir development index and the decline index, and the interval is divided according to the specific value of the efficient management index, and targeted management strategies are formulated for production wells in different intervals. This differentiated and refined management method can significantly improve management efficiency, reduce resource waste, and ensure the safety and stability of oil field production. This application starts from the core factors affecting efficient development, namely the accurate analysis of reservoir geological characteristics and real-time monitoring of production dynamic characteristics, and solves the problem that existing management is difficult to fully reflect the complexity and dynamics of the oil field development process and its practicality is not strong. BRIEF DESCRIPTION OF THE DRAWINGS

[0017] In order to more clearly illustrate the embodiments of the present application or the technical solutions in the prior art, the drawings required for use in the embodiments of the present application or the description of the prior art will be briefly introduced below. Obviously, the drawings described below are some embodiments of the present application. For ordinary technicians in this field, other drawings can be obtained based on these drawings without paying any creative work.

[0018] Figure 1 A flow chart of a management method for efficient development of an oil field provided in an embodiment of the present application;

[0019] Figure 2 A specific flow chart for uniformly managing production wells in a management unit by dividing the production wells into intervals according to the specific values ​​of the efficient management index provided in the embodiment of the present application, and formulating management strategies for corresponding production wells according to different intervals;

[0020] Figure 3 A schematic diagram of a management device for efficient development of an oil field provided in an embodiment of the present application;

[0021] Figure 4 A schematic diagram of a management server for efficient oil field development provided in an embodiment of the present application. DETAILED DESCRIPTION

[0022] The technical solutions in the embodiments of the present application will be described clearly and completely below in conjunction with the drawings in the embodiments of the present application. Obviously, the described embodiments are part of the embodiments of the present application, rather than all of the embodiments. Based on the embodiments in the present application, all other embodiments obtained by ordinary technicians in this field without creative work are within the scope of protection of this application.

[0023] The following describes some of the techniques involved in the embodiments of the present application to facilitate understanding, and they should be considered as merely exemplary. Therefore, it should be appreciated by those of ordinary skill in the art that various changes and modifications may be made to the embodiments described herein without departing from the scope and spirit of the present application. Similarly, for the sake of clarity and conciseness, some descriptions of well-known functions and structures are omitted in the following description.

[0024] The present application embodiment provides a management method for efficient development of oil fields, such as Figure 1 As shown, the method includes steps S101 to S106. Among them, Figure 1 This is only an execution order shown in the embodiment of the present application, and does not represent the only execution order of a management method for efficient oil field development. Figure 1 The steps shown may be performed in parallel or reversed.

[0025] S101: Divide the target block into multiple management units according to the geographical location of the platform, the distribution of production wells and geological conditions in the target block of oilfield development, wherein each management unit includes multiple production wells.

[0026] Specifically, GIS (Geographic Information System) technology can be used to accurately mark the latitude and longitude positions of all platforms in the target block, analyze their relative positional relationships, and collect the distribution of production wells in the target block. Through geological exploration data, the stratigraphic structure, lithological characteristics, reservoir properties, oil and gas reservoir types and distribution patterns in the block can be analyzed to identify areas with complex or special geological conditions.

[0027] During the division process, production wells with close geographical locations and similar production conditions can be included in the same management unit for centralized management. The differences in geological conditions can also be taken into consideration and areas with similar geological characteristics can be divided into the same management unit to facilitate the adoption of targeted management strategies.

[0028] S102: Select a target production well, determine the sampling location and depth, drill a core from the target production well, and obtain basic parameters of the core.

[0029] Before selecting the target production well, it includes: collecting the mine production data of all production wells in each management unit. Specifically, the selection range of the target production well is not limited to the same management unit, but can be flexibly adjusted according to the actual situation and research needs.

[0030] When the research or management goal is focused on a specific management unit, it is preferred to select target production wells within the management unit. The advantage of this is that it ensures that the selected target production wells have a high degree of geological and production similarity, which is convenient for comparison and in-depth analysis.

[0031] If research or management needs require a broader understanding of the geological and production changes of the entire oil field, or if there is a need to compare the differences between different management units, you can consider selecting target production wells across management units. This selection method can provide more comprehensive oil field information, help identify commonalities and differences in oil field development, and provide a basis for formulating global management strategies.

[0032] Table 1 is a production data table provided in an embodiment of the present application, which collects the well numbers and oil production of all production wells in each management unit.

[0033] During the oil field development process, in order to more effectively manage and optimize production, the target blocks were carefully divided into platforms to form multiple management units.

[0034] For each management unit, the mine production data of all production wells within it were collected to obtain detailed production information.

[0035] Specifically, within a certain management unit of the target block, 5 production wells were selected and labeled according to numbers W1 to W5.

[0036] In order to analyze the production dynamics and performance of these wells, production data of these wells at the same time node (i.e., 7 consecutive weeks) were further collected.

[0037] Table 1

[0038]

[0039] S103: Calculate key indexes based on the basic parameters of the core, and calculate reservoir development index based on the key indexes. The key indexes include storage index, mobility index and transformation index. The basic parameters of the core include single mineral percentage, porosity, permeability and mechanical parameters.

[0040] Specifically, the mineral percentage is obtained by using an X-ray diffractometer to test the percentage of a single mineral in the core. X-rays interact with the mineral crystals in the core to produce a diffraction pattern of a specific wavelength. By comparing the standard pattern, the percentage and type of the single mineral in the current core can be identified.

[0041] Specifically, the porosity is obtained by measuring the effective porosity and absolute porosity of the core using a helium porosimeter. The effective porosity of the core refers to the proportion of interconnected pore spaces in the core that allow fluid to flow freely. The effective porosity directly affects the storage capacity of the reservoir and the flow performance of the fluid. The absolute porosity of the core refers to the proportion of all pore spaces in the core (whether connected or not), including connected pores and pores that may not be connected but are formed due to tiny cracks or gaps between mineral particles.

[0042] Specifically, the permeability is obtained by measuring the permeability of the core using the mercury injection method.

[0043] The mechanical parameters are obtained by measuring the Young's modulus of the core using a triaxial rock mechanics testing system. The Young's modulus of the core reflects the linear relationship between the internal stress and strain of the core when it is subjected to external forces.

[0044] During the measurement, the core sample is placed in a pressure chamber and subjected to confining pressure and axial pressure. By recording the stress-strain relationship data of the core during loading, a stress-strain curve can be drawn. In the elastic stage of the curve, stress and strain are linearly related, and the slope of this stage is the Young's modulus of the core.

[0045] Table 2 is a basic parameter table of the core provided in the embodiment of the present application. The basic parameters of the core in Table 2 include the percentage of single minerals, the effective porosity of the core, the absolute porosity of the core, the permeability of the core and the Young's modulus of the core. Among them, the single minerals include dolomite, quartz, feldspar, calcite and clay minerals.

[0046] Table 2

[0047]

[0048] Table 3 is a table of various indexes provided in the embodiments of the present application. The key indexes include storage index, mobility index and transformation index, which are used to evaluate the material basis of reservoir resources, fluidity and reservoir transformation potential respectively. The reservoir development index is used to characterize the ability of the reservoir to be efficiently developed. The total decline rate and weekly decline rate are calculated using the production data of a preset number of weeks, and the decline index is calculated in combination with the total decline rate and weekly decline rate to evaluate the development status of the production well.

[0049] Table 3

[0050]

[0051] Specifically, the storage index is calculated by multiplying the ratio of the current core's absolute porosity to the maximum absolute porosity of the core in the same rock reservoir by the ratio of the current core's permeability to the maximum permeability of the core in the same rock reservoir. The storage index is used to reflect the reservoir material basis and the upper limit of recoverable capacity.

[0052] Furthermore, the calculation formula of the storage index is: .in, To store the index, is the absolute porosity of the current core, is the current core permeability, is the maximum absolute porosity of the core in the same rock reservoir, It is the maximum permeability of the core in the same rock reservoir.

[0053] Assuming that the maximum absolute porosity of the core in the target block, i.e., the same type of rock reservoir, is 10%, and the maximum permeability of the core in the target block, i.e., the same type of rock reservoir, is 1.5 mD, the storage index calculation results of each production well in the embodiment of the present application are shown in Table 3.

[0054] Specifically, the movable index is calculated by comprehensively considering the effective porosity of the current core, the mineral composition of the current core, and the Young's modulus of the current core. The mineral composition of the current core includes the percentage content of a single mineral in the current core and the Young's modulus of a single mineral in the current core.

[0055] Furthermore, the calculation formula of the movable index is: .in, is the movable index, is the effective porosity of the current core, is the absolute porosity of the current core, is the Young's modulus of a single mineral in the current core, is the percentage content of single mineral in the current core, is the Young's modulus of the current core, i is the index variable, which is used to traverse all the single minerals in the current core in the summation operation. is the total number of single minerals in the current core.

[0056] Specifically, for each mineral, there is a corresponding Young's modulus and a percentage By changing the value of i (starting from 1 to n), the Young's modulus and percentage content of each mineral in the current core can be accessed and calculated in turn.

[0057] Specifically, according to the Handbook of Rock Physics, the Young's modulus of feldspar is 64839 MPa, the Young's modulus of dolomite is 105309 MPa, the Young's modulus of quartz is 95943 MPa, the Young's modulus of calcite is 78011 MPa, and the Young's modulus of clay minerals is 21914 MPa. The calculation results of the movable index of each production well in the embodiment of the present application are shown in Table 3.

[0058] It should be noted that the Young's modulus of the current core refers to the ability of the entire core as a whole material to resist elastic deformation when subjected to external forces. It is the result of the combined effect of all mineral components, pore structure, microcracks and other factors in the core. The Young's modulus of a single mineral in the current core refers to the ability of a specific mineral component in the core to resist elastic deformation when subjected to external forces. It is one of the inherent physical properties of the mineral itself and is related to factors such as the crystal structure, chemical composition and temperature of the mineral. In the calculation of the movable index, the Young's modulus of a single mineral is obtained by experimental measurement or querying relevant data. Since the core contains multiple mineral components, each mineral needs to be measured or queried separately.

[0059] Specifically, the transformation index is calculated as follows: Calculate the percentage of minerals in the current core multiplied by the sum of the Young's modulus of the single minerals in the current core to obtain the denominator. Divide the Young's modulus of the current core by the denominator to obtain the intermediate term. Calculate the absolute value of the difference between the percentage of minerals in the current core and the intermediate term to obtain the difference term. Add all the difference terms to obtain the transformation index.

[0060] Furthermore, the transformation index is calculated as follows: .in, is the transformation index, is the percentage content of single mineral in the current core, is the Young's modulus of a single mineral in the current core, is the Young's modulus of the current core, i is the index variable, which is used to traverse all the single minerals in the current core in the summation operation. is the total number of single minerals in the current core.

[0061] Specifically, the calculation results of the transformation index of each production well in the embodiment of the present application are shown in Table 3.

[0062] It should be noted that the absolute porosity of the current core, the maximum absolute porosity of the core in the same rock reservoir, the effective porosity of the current core, and the percentage of a single mineral in the current core in this application are all expressed in % (percentage). The permeability of the current core and the maximum permeability of the core in the same rock reservoir are both expressed in mD (millidarcy). The Young's modulus of a single mineral in the current core and the Young's modulus of the current core are both expressed in MPa (megapascals).

[0063] Furthermore, the calculation formula for calculating the reservoir development index based on the key index is: .in, is the reservoir development index, To store the index, is the movable index, The transformation index.

[0064] Specifically, the calculation results of the reservoir development index of each production well in the embodiment of the present application are shown in Table 3.

[0065] S104: Using the production data of a preset number of weeks, calculate the total decrease degree and the weekly decrease degree, and calculate the decrease index in combination with the total decrease degree and the weekly decrease degree. It should be noted that the preset number of weeks in this application is 7 weeks. Of course, the specific value of the preset number can also be other values, and this application is not limited to this value.

[0066] Specifically, the calculation formula of the total decline degree is: .in, is the total decreasing degree, The data value of the weekly production data for the first week, The data value of the weekly production data for the mth week, where m is the total number of weeks.

[0067] The calculation of the total decline rate in this application is a dimensionless calculation, that is, it does not depend on the value of any specific physical unit. In the calculation of the total decline rate, since the numerator and denominator are both quantities with the same physical unit (i.e., the data value of the weekly production data), when they are divided, the physical unit is eliminated. The total decline rate only represents a ratio or rate of change, that is, the percentage of production volume reduced from the 1st week to the mth week. This ratio has no physical unit and is therefore a dimensionless calculation.

[0068] Specifically, the calculation formula for the weekly decrease is: .in, is the weekly decreasing degree, is the data value of the week number of the jth week, is the data value of the weekly production data of the jth week, and m is the total number of weeks.

[0069] The calculation of the weekly decline rate in this application is a dimensionless calculation. The weekly decline rate represents the relative decline or volatility of production data between consecutive weeks. This value does not depend on any specific physical unit.

[0070] The formula for calculating the decline index by combining the total decline rate and the weekly decline rate is: .in, is a decreasing index, is the total decreasing degree, The degree of weekly decrease.

[0071] Specifically, the calculation results of the total decline rate, weekly decline rate and decline index of each production well in the embodiment of the present application are shown in Table 3.

[0072] Specifically, the overall decreasing trend is evaluated by assigning different weights to the two decreasing degree indicators. 0.7 is assigned to the total decreasing degree, indicating that the total decreasing degree has a higher importance or influence in evaluating the overall decreasing trend. This is because the total decreasing degree provides an overall perspective from the beginning to the end of production, which can reflect long-term changes in production performance. 0.3 is assigned to the weekly decreasing degree, indicating that although the weekly decreasing degree is not as important as the total decreasing degree, it is still an important component in evaluating the decreasing trend. The weekly decreasing degree focuses on the changes in production data between weeks, which can reveal short-term fluctuations or adjustments in the production process. By adding the total decreasing degree and the weekly decreasing degree according to their respective weights, the decreasing index provides a comprehensive decreasing trend assessment that takes into account both long-term and short-term considerations. Since the total decreasing degree and the weekly decreasing degree are both dimensionless calculation results, the decreasing index is also dimensionless.

[0073] S105: Calculate the efficient management index by combining the reservoir development index and the decline index.

[0074] Specifically, the calculation formula of the efficient management index is: .in, To manage the index efficiently, is the reservoir development index, is a decreasing index.

[0075] S106: Divide the intervals according to the specific values ​​of the efficient management index, formulate management strategies for corresponding production wells according to different intervals, and manage the production wells in a unified manner in the management unit.

[0076] Figure 2 The specific flow chart of the embodiment of the present application for dividing the intervals according to the specific values ​​of the efficient management index, formulating the management strategies for the corresponding production wells according to the different intervals, and performing unified management of the production wells in the management unit is as follows: Figure 2 As shown, it includes steps S201 to S203.

[0077] S201: If the specific value of the high-efficiency management index is less than or equal to the first preset threshold, the production well corresponding to this interval is a high-efficiency development well, and its management strategy is to maintain and optimize the existing production conditions to ensure long-term high-efficiency production.

[0078] Specifically, the value of the first preset threshold may be 0.35, that is, , the corresponding production well is an efficient development well. The production equipment can be maintained and inspected regularly to ensure that all equipment is in good working condition. Production parameters such as output, pressure, temperature, fluid properties, etc. are continuously monitored to ensure that they are in the optimal or near-optimal range. Potential problems can be discovered and dealt with in a timely manner through real-time data analysis and early warning systems. According to production data and market demand, production parameters such as oil production rate, water injection pressure, gas lift, etc. are adjusted in a timely manner to optimize production efficiency and economic benefits.

[0079] S202: If the high efficiency management index is greater than the first preset threshold and less than or equal to the second preset threshold, the production well corresponding to this interval is a well that needs to be optimized, and its management strategy is to identify and optimize key factors affecting production.

[0080] Specifically, the value of the second preset threshold may be 0.50, that is, , the corresponding production well is a well that needs to be optimized. This means that although the production efficiency of the well that needs to be optimized has not yet reached the optimal state, it still has the potential to be improved through optimization measures. Conduct a detailed analysis of the historical data of the well that needs to be optimized, including the changing trends of key parameters such as production, pressure, temperature, and fluid properties. Through data analysis, identify factors that may lead to a decrease in production efficiency. Combined with the results of data analysis, conduct on-site investigations and observations. Check the operating conditions of key components such as wellhead equipment, oil production trees, and pipelines to understand the actual situation in the production process. According to the identified key factors, formulate targeted optimization measures. This may include adjusting production parameters, improving oil production processes, implementing production increase measures, repairing or replacing damaged equipment, etc.

[0081] S203: If the high efficiency management index is greater than the second preset threshold and less than or equal to the third preset threshold, the production well corresponding to this interval is a well that needs efficiency enhancement, and its management strategy is to deeply analyze the reasons for inefficiency and take targeted measures.

[0082] Specifically, the value of the third preset threshold may be 1.0, that is, , the corresponding production well is a well that needs to be enhanced. A comprehensive and integrated assessment is conducted on the wells that need to be enhanced, including geological conditions, reservoir characteristics, fluid properties, wellbore conditions, production history and other aspects. Through comprehensive assessment, the root cause of inefficiency is found. In-depth analysis of the causes of inefficiency, including poor reservoir connectivity, formation pressure drop, low fluid displacement efficiency, and serious wellbore damage. With the help of multiple data sources such as production data, logging data, and geological exploration data, strong support is provided for the analysis of inefficiency causes. Through data analysis, abnormal conditions and potential problems in the production process are discovered. According to the causes of inefficiency, specific measures to increase production are formulated. These may include water injection and pressure increase, fracturing transformation, acidizing treatment, gas lift and other production enhancement technologies. By implementing production enhancement measures, reservoir conditions are improved, fluid displacement efficiency is improved, and production is increased. If the cause of inefficiency is related to wellbore conditions, such as wellbore damage and corrosion, wellbore repair measures need to be taken. These may include replacing damaged casing, repairing corroded parts, and reinforcing well walls. Through wellbore repair, the integrity and stability of the wellbore are restored, and production safety is improved.

[0083] Table 4 is an efficient management index table provided in an embodiment of the present application. As shown in Table 4, the efficient management indexes of the production wells numbered W1 and W2 are 0.5 and 0.45 respectively. The efficient management indexes of the production wells are greater than the first preset threshold and less than or equal to the second preset threshold, and they are all wells that need to be optimized, that is, The efficient management index of the production wells numbered W3 and W4 is 0.31, and their efficient management index is less than or equal to the first preset threshold, which is an efficient development well. The efficient management index of the production well numbered W5 is 0.60. Its efficient management index is greater than the second preset threshold and less than or equal to the third preset threshold, which is a well that needs efficiency enhancement. .

[0084] Table 4

[0085]

[0086] The present application embodiment also provides a management device 300 for efficient development of oil fields, such as Figure 3 As shown, the device includes: a division module 301, a selection module 302, a first calculation module 303, a second calculation module 304, a third calculation module 305 and a management module 306.

[0087] The division module 301 is used to divide the target block into multiple management units according to the geographical location of the platform, the distribution of production wells and geological conditions in the target block of oilfield development, wherein each management unit includes multiple production wells.

[0088] The selection module 302 is used to select a target production well, determine the sampling location and depth, drill a core from the target production well, and obtain basic parameters of the core.

[0089] The first calculation module 303 is used to calculate key indexes according to the basic parameters of the core, and calculate the reservoir development index according to the key indexes, wherein the key indexes include storage index, mobility index and transformation index.

[0090] The second calculation module 304 is used to calculate the total decrease degree and the weekly decrease degree by using the production data of a preset number of weeks, and calculate the decrease index by combining the total decrease degree and the weekly decrease degree.

[0091] The third calculation module 305 is used to calculate the efficient management index by combining the reservoir development index and the decline index.

[0092] The management module 306 is used to divide the intervals according to the specific values ​​of the efficient management index, formulate management strategies for corresponding production wells according to different intervals, and uniformly manage the production wells in the management unit.

[0093] Some modules in the apparatus described in the present application can be described in the general context of computer executable instructions executed by a computer, such as program modules. Generally, program modules include routines, programs, objects, components, data structures, classes, etc. that perform specific tasks or implement specific abstract data types. The present application can also be practiced in distributed computing environments, in which tasks are performed by remote processing devices connected through a communication network. In a distributed computing environment, program modules can be located in local and remote computer storage media including storage devices.

[0094] The devices or modules described in the above application embodiments can be implemented by computer chips or entities, or by products with certain functions. For the convenience of description, the above devices are described in various modules according to their functions. When implementing the embodiments of the present application, the functions of each module can be implemented in the same or multiple software and / or hardware. Of course, the module that implements a certain function can also be implemented by combining multiple sub-modules or sub-units.

[0095] like Figure 4 As shown, an embodiment of the present application also provides a management server for efficient development of oil fields, including a memory 401 and a processor 402; the memory 401 is used to store computer executable instructions; the processor 402 is used to execute computer executable instructions to implement a management method for efficient development of oil fields described above in an embodiment of the present application.

[0096] The embodiment of the present application also provides a computer-readable storage medium, which stores executable instructions. When a computer executes the executable instructions, it can implement the management method for efficient development of an oil field described above in the embodiment of the present application.

[0097] It can be seen from the description of the above implementation methods that those skilled in the art can clearly understand that the present application can be implemented by means of software plus necessary hardware. Based on this understanding, the technical solution of the present application can be essentially or partly contributed to the prior art in the form of a software product, or it can be reflected in the implementation process of data migration. The computer software product can be stored in a storage medium, such as ROM / RAM, a disk, an optical disk, etc., including a number of instructions for a computer device (which can be a personal computer, a mobile terminal, a server, or a network device, etc.) to execute the method described in the embodiment of the present application.

[0098] The various embodiments in this specification are described in a progressive manner, and the same or similar parts between the various embodiments can be referred to each other, and each embodiment focuses on the differences from other embodiments. All or part of this application can be used in many general or special computer system environments or configurations.

[0099] The above embodiments are only used to illustrate the technical solutions of the present application, rather than to limit the present application. Although the present application has been described in detail with reference to the aforementioned embodiments, a person of ordinary skill in the art should understand that the technical solutions described in the aforementioned embodiments may still be modified, or some or all of the technical features thereof may be replaced by equivalents. However, these modifications or replacements do not cause the essence of the corresponding technical solutions to deviate from the scope of the technical solutions of the present application.

Claims

1. A management method for efficient development of oil fields, characterized in that: include: According to the geographical location of the platform, the distribution of production wells and geological conditions in the target block of oilfield development, the target block is divided into multiple management units; each management unit includes multiple production wells; Select the target production well, determine the sampling location and depth, drill cores from the target production well, and obtain the basic parameters of the cores; Calculating key indexes according to the basic parameters of the core, and calculating reservoir development indexes according to the key indexes; wherein the key indexes include storage index, mobility index and transformation index; The calculation formula of storage index is: ;in, To store the index, is the absolute porosity of the current core, is the current core permeability, is the maximum absolute porosity of the core in the same rock reservoir, is the maximum permeability of the core in the same rock reservoir; The calculation formula of the mobility index is: ;in, is the movable index, is the effective porosity of the current core, is the Young's modulus of a single mineral in the current core, is the percentage content of single mineral in the current core, is the Young's modulus of the current core, i is the index variable, which is used to traverse all the single minerals in the current core in the summation operation. is the total number of single minerals in the current core; The transformation index is calculated as follows: ;in, is the transformation index; The calculation formula for calculating the reservoir development index based on the key index is: ;in, Develop indices for reservoirs; Using the production data of a preset number of weeks, the total decline rate and the weekly decline rate are calculated, and the decline index is calculated by combining the total decline rate and the weekly decline rate; The total decline rate is calculated as: ;in, is the total decreasing degree, The data value of the weekly production data for the first week, is the data value of weekly production data of week m, where m is the total number of weeks; The calculation formula of weekly decline is: ;in, is the weekly decreasing degree, is the data value of the week number of the jth week, The data value of the weekly production data of the jth week; The formula for calculating the decline index by combining the total decline rate and the weekly decline rate is: ;in, is a decreasing index; The efficient management index is calculated by combining the reservoir development index and the decline index; The calculation formula of the efficient management index is: ;in, To manage the index efficiently; Divide the intervals according to the specific values ​​of the efficient management index, formulate management strategies for corresponding production wells according to different intervals, and manage the production wells in a unified manner in the management unit; The interval division is performed according to the specific value of the efficient management index, and the management strategy of the corresponding production well is formulated according to different intervals, and the production wells are uniformly managed in the management unit, including: If the specific value of the efficient management index is less than or equal to the first preset threshold, the production well corresponding to this interval is an efficient development well, and its management strategy is to maintain and optimize the existing production conditions to ensure long-term efficient production; wherein the value of the first preset threshold is 0.35; If the high-efficiency management index is greater than the first preset threshold and less than or equal to the second preset threshold, the production well corresponding to this interval is a well that needs to be optimized, and its management strategy is to identify and optimize the key factors affecting production; wherein the value of the second preset threshold is 0.50; If the high-efficiency management index is greater than the second preset threshold and less than or equal to the third preset threshold, the production well corresponding to this interval is a well that needs efficiency improvement, and its management strategy is to deeply analyze the causes of inefficiency and take targeted measures; among which, the value of the third preset threshold is 1.

0.

2. The management method for efficient development of oil fields according to claim 1, characterized in that: Before selecting the target production well, the method includes: collecting the mine production data of all production wells in each management unit.

3. The management method for efficient oil field development according to claim 1, characterized in that: The basic parameters of the core include single mineral percentage, porosity, permeability and mechanical parameters.

4. The management method for efficient development of oil fields according to claim 3, characterized in that: The mineral percentage is obtained by: using an X-ray diffractometer to test the percentage of a single mineral in a rock core; The porosity is obtained by measuring the effective porosity and the absolute porosity of the core using a helium porosity automatic measuring instrument; The permeability is obtained by: measuring the permeability of the core using mercury injection method; The mechanical parameters are obtained by measuring the Young's modulus of the rock core using a triaxial rock mechanics testing system.

5. A management device for efficient development of oil fields, characterized in that: include: A division module is used to divide the target block into multiple management units according to the geographical location of the platform, the distribution of production wells and geological conditions in the target block of oil field development; wherein each management unit includes multiple production wells; The selection module is used to select the target production well, determine the sampling location and depth, drill the core from the target production well, and obtain the basic parameters of the core; A first calculation module is used to calculate key indexes according to the basic parameters of the core, and calculate the reservoir development index according to the key indexes; wherein the key indexes include storage index, mobility index and transformation index; The calculation formula of storage index is: ;in, To store the index, is the absolute porosity of the current core, is the current core permeability, is the maximum absolute porosity of the core in the same rock reservoir, is the maximum permeability of the core in the same rock reservoir; The calculation formula of the mobility index is: ;in, is the movable index, is the effective porosity of the current core, is the Young's modulus of a single mineral in the current core, is the percentage content of single mineral in the current core, is the Young's modulus of the current core, i is the index variable, which is used to traverse all the single minerals in the current core in the summation operation. is the total number of single minerals in the current core; The transformation index is calculated as follows: ;in, is the transformation index; The calculation formula for calculating the reservoir development index based on the key index is: ;in, Develop indices for reservoirs; A second calculation module is used to calculate the total decrease degree and the weekly decrease degree by using the production data of a preset number of weeks, and calculate the decrease index by combining the total decrease degree and the weekly decrease degree; The total decline rate is calculated as: ;in, is the total decreasing degree, The data value of the weekly production data for the first week, is the data value of weekly production data of week m, where m is the total number of weeks; The calculation formula of weekly decline is: ;in, is the weekly decreasing degree, is the data value of the week number of the jth week, The data value of the weekly production data of the jth week; The formula for calculating the decline index by combining the total decline rate and the weekly decline rate is: ;in, is a decreasing index; A third calculation module is used to calculate an efficient management index by combining the reservoir development index and the decline index; The calculation formula of the efficient management index is: ;in, To manage the index efficiently; A management module is used to divide the intervals according to the specific values ​​of the efficient management index, formulate management strategies for corresponding production wells according to different intervals, and uniformly manage the production wells in the management unit; said dividing the intervals according to the specific values ​​of the efficient management index, formulating management strategies for corresponding production wells according to different intervals, and uniformly managing the production wells in the management unit, including: If the specific value of the efficient management index is less than or equal to the first preset threshold, the production well corresponding to this interval is an efficient development well, and its management strategy is to maintain and optimize the existing production conditions to ensure long-term efficient production; wherein the value of the first preset threshold is 0.35; If the high-efficiency management index is greater than the first preset threshold and less than or equal to the second preset threshold, the production well corresponding to this interval is a well that needs to be optimized, and its management strategy is to identify and optimize the key factors affecting production; wherein the value of the second preset threshold is 0.50; If the high-efficiency management index is greater than the second preset threshold and less than or equal to the third preset threshold, the production well corresponding to this interval is a well that needs efficiency improvement, and its management strategy is to deeply analyze the causes of inefficiency and take targeted measures; among which, the value of the third preset threshold is 1.0.

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