Development mode determination method of low-permeability reservoir and related device

Abstract

The invention discloses a low-permeability reservoir development mode determination method and a related device, and belongs to the field of oil-gas exploration. The method comprises the steps that actual parameters of development effect influence factors of a target low-permeability reservoir are obtained; based on the actual parameters of the development effect influence factors, determining an oil reservoir classification coefficient of the target low-permeability oil reservoir; and based on the oil reservoir classification coefficient of the target low-permeability oil reservoir, determining the development mode of the target low-permeability oil reservoir from the corresponding relation between the oil reservoir classification coefficient range and the development mode. According to the method, the reservoir classification coefficient and the corresponding relation between the reservoir classification coefficient range and the development mode are determined based on the development effect influence factors, so that the development mode of the target low-permeability reservoir can be quickly and accurately determined in practical application; and the problems of economic loss and low recovery rate caused by unreasonable selection of the development mode in the oil reservoir development process are avoided.

Description

Technical Field

[0001] The present application relates to the field of oil and gas exploration, and in particular to a method for determining a development mode of a low-permeability oil reservoir and a related device. Background Art

[0002] As the development of most oil fields in my country has entered the middle and late stages, low-permeability and ultra-low-permeability reservoirs have gradually become the main body of my country's oil field development. Low-permeability reservoir resources account for nearly 60% of the country's total oil reservoir resources. Therefore, it is particularly important to use effective development methods to develop low-permeability reservoirs.

[0003] In my country, oil reservoirs with a permeability of less than 50mD are usually called low-permeability oil reservoirs. Their development methods are often directly determined according to the range of their permeability. Conventional low-permeability oil reservoirs with a permeability of 20-50mD can be developed by water drive, but the development effects of oil reservoirs with a permeability of 5-20mD, especially those with a permeability of about 10mD, vary greatly. Some oil reservoirs can be injected with water to achieve water drive, and the conventional water drive development effect is good, but some oil reservoirs have small throats, and water injection easily causes deep blockage of the oil layer, resulting in poor conventional water drive development effects. Therefore, how to accurately identify the development method of low-permeability oil reservoirs has become a problem that needs to be solved urgently. Summary of the invention

[0004] The present application provides a method and a related device for determining the development mode of a low permeability oil reservoir, which can accurately determine the development mode of a low permeability oil reservoir. The technical solution is as follows:

[0005] In one aspect, a method for determining a development mode of a low permeability oil reservoir is provided, the method comprising:

[0006] Obtaining actual parameters of factors influencing the development effect of the target low-permeability oil reservoir, wherein the factors influencing the development effect include average throat radius, movable fluid percentage, formation pressure coefficient, hydrophilicity coefficient, porosity, start-up pressure gradient, clay mineral content, crude oil viscosity and reservoir burial depth;

[0007] Based on the actual parameters of the development effect influencing factors, determining the reservoir classification coefficient of the target low permeability reservoir, the reservoir classification coefficient is used to finely divide the coarse-grained permeability of the target low permeability reservoir;

[0008] Based on the reservoir classification coefficient of the target low permeability reservoir, the development method of the target low permeability reservoir is determined from the corresponding relationship between the reservoir classification coefficient range and the development method.

[0009] Optionally, the development effect influencing factors include first-type influencing factors and second-type influencing factors, the first-type influencing factors are positively correlated with reservoir permeability, and the second-type influencing factors are negatively correlated with reservoir permeability;

[0010] The determining of the reservoir classification coefficient of the target low permeability reservoir based on the actual parameters of the development effect influencing factors includes:

[0011] Determining a first classification coefficient based on actual parameters, weight coefficients and calibration parameters of the first category of influencing factors;

[0012] Determining a second classification coefficient based on the actual parameters, weight coefficients and calibration parameters of the second type of influencing factors;

[0013] The reservoir classification coefficient is determined based on the first classification coefficient and the second classification coefficient.

[0014] Optionally, the first type of influencing factors includes the average throat radius, the movable fluid percentage, the formation pressure coefficient, the hydrophilicity coefficient and the porosity; and determining the first classification coefficient based on the actual parameters of the first type of influencing factors includes:

[0015] Based on the actual parameters, weight coefficients and calibration parameters of the first category of influencing factors, the first classification coefficient is determined according to the following formula;

[0016]

[0017] Wherein, F1 represents the first classification coefficient, i represents the i-th influencing factor in the first category of influencing factors, m represents the number of the first category of influencing factors, and c i represents the actual parameter of the i-th influencing factor, the k i represents the weight coefficient of the i-th influencing factor, the c istd represents the calibration parameter of the i-th influencing factor.

[0018] Optionally, the second type of influencing factors include the starting pressure gradient, the clay mineral content, the crude oil viscosity and the reservoir burial depth; and determining the second classification coefficient based on the actual parameters of the second type of influencing factors includes:

[0019] Based on the actual parameters, weight coefficients and calibration parameters of the second type of influencing factors, the second classification coefficient is determined according to the following formula;

[0020]

[0021] Wherein, F2 represents the second classification coefficient, j represents the jth influencing factor in the second category of influencing factors, n represents the number of the second category of influencing factors, and d j represents the actual parameter of the jth influencing factor, the J jrepresents the weight coefficient of the jth influencing factor, and the d jstd represents the calibration parameter of the j-th influencing factor.

[0022] Optionally, the weight coefficients of the average throat radius, the porosity and the starting pressure gradient are primary weight coefficients, the weight coefficients of the movable fluid percentage, the hydrophilicity coefficient and the clay mineral content are secondary weight coefficients, and the weight coefficients of the formation pressure coefficient, the crude oil viscosity and the reservoir burial depth are tertiary weight coefficients;

[0023] Among them, the first-level weight coefficient is greater than the second-level weight coefficient, and the second-level weight coefficient is greater than the third-level weight coefficient.

[0024] Optionally, the determining the development mode of the target low permeability oil reservoir from the corresponding relationship between the reservoir classification coefficient range and the development mode based on the reservoir classification coefficient of the target low permeability oil reservoir includes:

[0025] Obtaining the development method corresponding to the reservoir classification coefficient of the target low permeability reservoir from the corresponding relationship between the reservoir classification coefficient range and the development method;

[0026] If the acquired development mode includes a fracture network matching synchronous water injection mode and a fracture network matching advanced water injection mode, determining whether the formation pressure coefficient is lower than a pressure threshold;

[0027] If the formation pressure coefficient is lower than the pressure threshold, the development mode of the target low permeability oil reservoir is determined to be the fracture network matching advance water injection mode; otherwise, the development mode of the target low permeability oil reservoir is determined to be the fracture network matching synchronous water injection mode.

[0028] Optionally, if the acquired development methods include a gas drive method and an energy storage imbibition method, determining whether the target low permeability oil reservoir has a gas source;

[0029] If the target low permeability oil reservoir has a gas source, the development mode of the target low permeability oil reservoir is determined to be the gas drive mode; otherwise, the development mode of the target low permeability oil reservoir is determined to be the energy storage imbibition mode.

[0030] Optionally, the energy storage imbibition mode includes an energy storage displacement mode and an energy storage throughput mode; the step of determining that the development mode of the target low permeability reservoir is the energy storage imbibition mode includes:

[0031] If the actual parameter of the average throat radius is greater than the throat radius threshold, the actual parameter of the starting pressure gradient is greater than the gradient threshold, and the actual parameter of the porosity is greater than the porosity threshold, then the development mode of the target low permeability oil reservoir is determined to be the energy storage displacement mode; otherwise, the development mode of the target low permeability oil reservoir is determined to be the energy storage throughput mode.

[0032] Optionally, if the acquired development methods include gas drive, energy storage and imbibition, and volume fracturing asynchronous injection and production and imbibition oil production, then determining whether the gas source of the target low permeability oil reservoir is sufficient;

[0033] If the gas source of the target low permeability oil reservoir is sufficient, determining that the development method of the target low permeability oil reservoir is the gas drive method;

[0034] If the gas source of the target low permeability oil reservoir is insufficient, the development mode of the target low permeability oil reservoir is determined to be the energy storage imbibition mode or the volume fracturing asynchronous injection and production imbibition oil production mode.

[0035] On the other hand, a device for determining a development mode of a low permeability oil reservoir is provided, the device comprising:

[0036] An acquisition module is used to acquire actual parameters of development effect influencing factors of a target low permeability oil reservoir, wherein the development effect influencing factors include average throat radius, movable fluid percentage, formation pressure coefficient, hydrophilicity coefficient, porosity, start-up pressure gradient, clay mineral content, crude oil viscosity and reservoir burial depth;

[0037] A first determination module is used to determine the reservoir classification coefficient of the target low permeability reservoir based on the actual parameters of the development effect influencing factors, and the reservoir classification coefficient is used to finely divide the coarse-grained permeability of the target low permeability reservoir;

[0038] The second determination module is used to determine the development mode of the target low permeability oil reservoir based on the reservoir classification coefficient of the target low permeability oil reservoir and from the corresponding relationship between the reservoir classification coefficient range and the development mode.

[0039] On the other hand, a computer device is provided, which includes a memory and a processor, wherein the memory is used to store computer programs, and the processor is used to execute the computer programs stored in the memory to implement the steps of the method for determining the development mode of a low permeability oil reservoir as described above.

[0040] On the other hand, a computer-readable storage medium is provided, wherein a computer program is stored in the storage medium, and when the computer program is executed by a processor, the steps of the method for determining the development mode of a low permeability oil reservoir described above are implemented.

[0041] On the other hand, a computer program product comprising instructions is provided. When the instructions are executed on a computer, the computer is caused to execute the steps of the method for determining the development mode of a low permeability oil reservoir as described above.

[0042] The technical solution provided by this application can at least bring the following beneficial effects:

[0043] By comprehensively considering a series of factors that affect the development effect of low permeability reservoirs, the reservoir classification coefficient of the target low permeability reservoir is determined, and then the corresponding development method is determined. Compared with the previous method of determining the development method only by permeability, this method is more reasonable and in line with actual application needs. It can quickly and accurately determine the development method of the target low permeability reservoir, avoiding economic losses and low recovery rates caused by unreasonable selection of development methods during reservoir development. BRIEF DESCRIPTION OF THE DRAWINGS

[0044] In order to more clearly illustrate the technical solutions in the embodiments of the present application, the drawings required for use in the description of the embodiments will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present application. For ordinary technicians in this field, other drawings can be obtained based on these drawings without creative work.

[0045] Figure 1 It is a flow chart of a method for determining a development mode of a low permeability oil reservoir provided in an embodiment of the present application;

[0046] Figure 2 It is a schematic diagram of the relationship between the recovery rate obtained by performing fracture network matching water injection development on 52 development units and their respective permeabilities provided in an embodiment of the present application;

[0047] Figure 3 is a schematic diagram of the relationship between the starting pressure gradient and the permeability provided in the embodiment of the present application;

[0048] Figure 4 is a fitting curve diagram of a reservoir classification coefficient and permeability provided in an embodiment of the present application;

[0049] Figure 5 It is a structural schematic diagram of a device for determining a development method of a low permeability oil reservoir provided in an embodiment of the present application;

[0050] Figure 6 It is a structural diagram of a terminal provided in an embodiment of the present application. DETAILED DESCRIPTION

[0051] In order to make the objectives, technical solutions and advantages of the embodiments of the present application clearer, the implementation methods of the present application will be further described in detail below in conjunction with the accompanying drawings.

[0052] Before explaining in detail the method for determining the development mode of a low permeability oil reservoir provided in the embodiment of the present application, the application scenario and implementation environment involved in the embodiment of the present application are first introduced.

[0053] As the development of most oil fields in my country has entered the middle and late stages, low-permeability and ultra-low-permeability reservoirs have gradually become the main body of my country's oil field development. Low-permeability reservoir resources account for nearly 60% of the country's total oil reservoir resources. Therefore, it is particularly important to use effective development methods and formulate reasonable development plans for the development of low-permeability reservoirs.

[0054] In my country, reservoirs with a permeability of less than 50mD are usually called low permeability reservoirs. Low permeability reservoirs are further divided into three categories: conventional low permeability reservoirs with a permeability between 10-50mD, ultra-low permeability reservoirs with a permeability between 1-10mD, and ultra-low permeability reservoirs with a permeability between 0.1-1. Permeability is an important indicator of groundwater, oil and gas resources. In the past, the development of low permeability reservoirs was mainly based on permeability as the main evaluation parameter, and the development method of low permeability reservoirs was often directly determined according to the permeability range. Conventional low permeability reservoirs with a general permeability of 20-50mD can be developed by water drive, but the development effects of reservoirs with a permeability between 5-20mD, especially those with a permeability of about 10mD, vary greatly. Some reservoirs can be injected with water to achieve water drive, and the conventional water drive development effect is good. However, some reservoirs have small throats, and water injection can easily cause deep blockage of the oil layer, resulting in poor conventional water drive development effects. This situation sometimes causes waste of resources, reduced economic benefits, and too low oil field production rates.

[0055] Based on this, the embodiment of the present application provides a method for determining the development mode of low permeability oil reservoirs, which finely classifies low permeability oil reservoirs through parameters such as average throat radius, movable fluid percentage, formation pressure coefficient, hydrophilicity, porosity, starting pressure gradient, clay mineral content, crude oil viscosity and reservoir burial depth, thereby achieving a clearer understanding of the reservoir, making it possible to conveniently and quickly determine reasonable development methods for different low permeability oil reservoirs, thereby improving the development effect of low permeability oil reservoirs and enhancing the benefits of oil field development.

[0056] The executor of the method for determining the development mode of a low permeability oil reservoir provided in the embodiment of the present application is a computer device, such as a PC (Personal Computer), a mobile phone, a smart phone, a PDA (Personal Digital Assistant), a Pocket PC (PPC), a tablet computer, a smart car computer, etc.

[0057] Those skilled in the art should understand that the above-mentioned computer devices are only examples, and other existing or future computer devices, if applicable to the embodiments of the present application, should also be included in the protection scope of the embodiments of the present application and are included here by reference.

[0058] It should be noted that the application scenarios and implementation environments described in the embodiments of the present application are intended to more clearly illustrate the technical solutions of the embodiments of the present application, and do not constitute a limitation on the technical solutions provided in the embodiments of the present application. Ordinary technicians in this field can know that with the emergence of new application scenarios and the evolution of the implementation environment, the technical solutions provided in the embodiments of the present application are also applicable to similar technical problems.

[0059] Next, the method for determining the development mode of a low permeability oil reservoir provided in the embodiment of the present application is explained in detail.

[0060] Please refer to Figure 1 , Figure 1 It is a flow chart of a method for determining a development mode of a low permeability oil reservoir provided in an embodiment of the present application, and the method includes the following steps.

[0061] Step 101: Obtain actual parameters of factors influencing the development effect of the target low permeability oil reservoir, wherein the factors influencing the development effect include average throat radius, movable fluid percentage, formation pressure coefficient, hydrophilicity coefficient, porosity, start-up pressure gradient, clay mineral content, crude oil viscosity and reservoir burial depth.

[0062] The target low permeability reservoir refers to the reservoir with a permeability of less than 50mD, among which the permeability between 10-50mD is a conventional low permeability reservoir, the permeability between 1-10mD is an extra-low permeability reservoir, and the permeability between 0.1-1 is an ultra-low permeability reservoir.

[0063] Among the above factors affecting the development effect, the average throat radius is an important parameter to characterize the pore structure of the reservoir. The pore is the expanded part surrounded by skeleton particles in the reservoir and has a greater effect on fluid storage. The throat refers to the channel between pores, and the average throat radius is the average value of the radii of these channels; the percentage of movable fluid is the ratio of the amount of fluid with good fluidity under the action of external driving force to the total amount of oil, gas and water in the reservoir; the formation pressure coefficient is the ratio of the measured formation pressure to the hydrostatic pressure at the same depth; the hydrophilicity coefficient is the ratio of the volume of mineral powder expanded in water to the volume expanded in oil; the porosity is the ratio of the sum of the volumes of all pore spaces in the rock sample to the volume of the rock sample; the starting pressure gradient refers to the pressure gradient when the fluid can overcome the resistance caused by the adsorption film or hydration film on the rock surface when it seeps in a low permeability oil reservoir; the viscosity of crude oil refers to the measure of the friction resistance when a part of the crude oil flows relative to another part; the reservoir burial depth is the vertical distance of the reservoir to the natural ground.

[0064] According to the above description, the method of directly determining the development mode of a low permeability reservoir based on its permeability may result in the selected development mode not actually being applicable to the low permeability reservoir. In fact, the development effect of a low permeability reservoir is closely related to the reservoir physical properties. When the same development mode is used to develop low permeability reservoirs with different reservoir physical properties, the resulting crude oil recoveries vary greatly. The parameters that characterize the reservoir physical properties of low permeability reservoirs are also the factors that affect the development effect of low permeability reservoirs. Therefore, by obtaining the actual parameters of the factors affecting the development effect, such as the average throat radius, movable fluid percentage, formation pressure coefficient, hydrophilicity, porosity, start-up pressure gradient, clay mineral content, crude oil viscosity and reservoir burial depth of the target low permeability reservoir, we can have a clearer understanding of the target low permeability reservoir, which is helpful for the subsequent selection of development modes on this basis, so that the development mode of the low permeability reservoir determined in this way will be more reasonable.

[0065] Step 102: Based on the actual parameters of the factors influencing the development effect, determine the reservoir classification coefficient of the target low permeability reservoir, and the reservoir classification coefficient is used to finely divide the coarse-grained permeability of the target low permeability reservoir.

[0066] In some embodiments, the development effect influencing factors include first-type influencing factors and second-type influencing factors, the first-type influencing factors are positively correlated with the reservoir permeability, and the second-type influencing factors are negatively correlated with the reservoir permeability. In this case, based on the actual parameters of the development effect influencing factors, determining the reservoir classification coefficient of the target low permeability reservoir includes the following steps (1)-(3):

[0067] (1) Determine the first classification coefficient based on the actual parameters, weight coefficients and calibration parameters of the first category influencing factors.

[0068] As an example, the first type of influencing factors include average throat radius, movable fluid percentage, formation pressure coefficient, hydrophilicity coefficient and porosity; at this time, based on the actual parameters, weight coefficients and calibration parameters of the first type of influencing factors, the first classification coefficient is determined according to the following formula (1);

[0069]

[0070] In the above formula (1), F1 represents the first classification coefficient, i represents the i-th influencing factor in the first category of influencing factors, m represents the number of influencing factors in the first category, and c i represents the actual parameter of the i-th influencing factor, k i represents the weight coefficient of the i-th influencing factor, c istd Represents the calibration parameter of the i-th influencing factor.

[0071] (2) Determine the second classification coefficient based on the actual parameters, weight coefficients and calibration parameters of the second category influencing factors.

[0072] As an example, the second type of influencing factors include starting pressure gradient, clay mineral content, crude oil viscosity and reservoir burial depth; at this time, based on the actual parameters, weight coefficients and calibration parameters of the second type of influencing factors, the second classification coefficient is determined according to the following formula (2);

[0073]

[0074] In the above formula (2), F2 represents the second classification coefficient, j represents the jth influencing factor in the second category of influencing factors, n represents the number of influencing factors in the second category, and d j represents the actual parameter of the jth influencing factor, J j represents the weight coefficient of the jth influencing factor, d jstd Represents the calibration parameter of the jth influencing factor.

[0075] The calibration parameters in the above steps (1) and (2) can be the limit value of the fifth category in the single factor classification standard, or the middle value of the third category in the single factor classification standard, or the left / right limit value or middle value of other categories, and the embodiments of the present application do not limit this.

[0076] The single factor classification standard is the classification standard for the size of each development influencing factor of low permeability reservoirs, among which the classification standards for the size of average throat radius, movable fluid percentage, formation pressure coefficient, hydrophilicity coefficient, porosity, start-up pressure gradient, clay mineral content, crude oil viscosity and reservoir burial depth are shown in Table 1 below:

[0077] Table 1

[0078] Factors affecting development results Category I Category II Three categories Four categories Five categories Average throat radius (μm) ≥4.5 3.9-4.5 2-3.9 0.9-2 ≤0.9 Movable fluid percentage (%) ≥65 50-65 40-50 25-40 ≤25 Starting pressure gradient (MPa / m) ≤0.01 0.01-0.1 0.1-0.3 0.3-0.5 ≥0.5 Crude oil viscosity (mPa·s) ≤2 2-5 5-8 8-15 ≥15 Clay mineral content (%) ≤5 5-10 10-12 12-15 ≥15 Formation pressure coefficient ≥1.5 1.2-1.5 1.0-1.2 0.9-1.0 ≤0.9 Hydrophilicity coefficient (%) ≥65 65-50 50-40 40-35 ≤35 Porosity(%) ≥20 15-20 15-13 13-8 ≤8 Reservoir depth (m) 2000-2500 2500-3000 3000-3500 3500-4000 ≥4000

[0079] In some embodiments, the weight coefficients of the average throat radius, porosity and starting pressure gradient in the above steps (1) and (2) are primary weight coefficients, the weight coefficients of the movable fluid percentage, hydrophilicity coefficient and clay mineral content are secondary weight coefficients, and the weight coefficients of the formation pressure coefficient, crude oil viscosity and reservoir burial depth are tertiary weight coefficients; wherein the primary weight coefficient is greater than the secondary weight coefficient, and the secondary weight coefficient is greater than the tertiary weight coefficient. For example, the primary weight coefficient is 1.2, the secondary weight coefficient is 1.0, and the tertiary weight coefficient is 0.8. In practical applications, the specific sizes of the primary, secondary and tertiary weight coefficients can also be adjusted according to the characteristics of the oil reservoir, and the embodiments of the present application do not limit this.

[0080] Since the average throat radius determines the flow properties of low permeability reservoirs, the starting pressure gradient is an important parameter of reservoir seepage capacity, and the porosity has a greater contribution to the reservoir seepage capacity, that is, these three development influencing factors have the greatest impact on the development of low permeability reservoirs. Therefore, the weight coefficients of these three development influencing factors are set to be the largest, that is, the weight coefficients of these three development effect influencing factors are the first-level weight coefficients. Since the movable fluid percentage is an important parameter representing the characteristics of the occurrence of porous fluids, the clay mineral content has a greater impact on the seepage capacity, and the hydrophilic coefficient reflects the wettability and also has a greater impact on the seepage capacity, that is, these three development influencing factors have a greater impact on the development of low permeability reservoirs. Therefore, the weight coefficients of these three development influencing factors are set to be larger, that is, the weight coefficients of these three development effect influencing factors are the second-level weight coefficients. Since reservoir burial depth, crude oil viscosity, and formation pressure coefficient are basic physical properties of oil reservoirs, they have a certain influence on the reservoir seepage capacity, that is, these three development influencing factors have an influence on the development of low permeability oil reservoirs, but the influence is not very large compared with the previous two. Therefore, the weight coefficients of these three development influencing factors are set to be smaller, that is, the weight coefficients of these three development effect influencing factors are three-level weight coefficients. Of course, in practical applications, the weight coefficients of each development effect influencing factor can also be selected accordingly according to the characteristics of the oil reservoir, and the embodiments of this application do not limit this.

[0081] (3) Determine the reservoir classification coefficient based on the first classification coefficient and the second classification coefficient.

[0082] In some embodiments, the first classification coefficient and the second classification coefficient are added to obtain the reservoir classification coefficient.

[0083] The above method of determining the reservoir classification coefficient of the target low permeability reservoir based on the actual parameters of the development effect influencing factors is only an example. In actual applications, the reservoir classification coefficient of the target low permeability reservoir can also be determined by other methods. For example, the development effect influencing factors include the first type of influencing factors and the second type of influencing factors. The first type of influencing factors are positively correlated with the reservoir permeability, and the second type of influencing factors are negatively correlated with the reservoir permeability. The first type of influencing factors include the average throat radius, the percentage of movable fluid, the formation pressure coefficient, the hydrophilicity coefficient and the porosity. The second type of influencing factors include the starting pressure gradient, the clay mineral content, the crude oil viscosity and the reservoir burial depth. In this case, based on the actual parameters of the first type of influencing factors, the actual parameters of the second type of influencing factors, the weight coefficient of each influencing factor and the calibration parameters, the reservoir classification coefficient is determined according to the following formula (3);

[0084]

[0085] In the above formula (3), F represents the reservoir classification coefficient, i represents the i-th influencing factor in the first category of influencing factors, m represents the number of influencing factors in the first category, and c i represents the actual parameter of the i-th influencing factor, k i represents the weight coefficient of the i-th influencing factor, c istd represents the calibration parameter of the i-th influencing factor; j represents the j-th influencing factor in the second category of influencing factors, n represents the number of the second category of influencing factors, d j represents the actual parameter of the jth influencing factor, J j represents the weight coefficient of the jth influencing factor, d jstd The weight coefficient and the calibration parameter are determined according to the method in the above example.

[0086] Step 103: Based on the reservoir classification coefficient of the target low permeability reservoir, the development method of the target low permeability reservoir is determined from the corresponding relationship between the reservoir classification coefficient range and the development method.

[0087] In some embodiments, the development mode corresponding to the reservoir classification coefficient of the target low permeability reservoir is obtained from the correspondence between the reservoir classification coefficient range and the development mode; if the obtained development mode includes the fracture network matching synchronous water injection mode and the fracture network matching advanced water injection mode, it is determined whether the formation pressure coefficient is lower than the pressure threshold; if the formation pressure coefficient is lower than the pressure threshold, it is determined that the development mode of the target low permeability reservoir is the fracture network matching advanced water injection mode, otherwise, it is determined that the development mode of the target low permeability reservoir is the fracture network matching synchronous water injection mode.

[0088] The pressure threshold refers to the critical value of the formation pressure coefficient of the low permeability reservoir that can ensure that the formation energy can ensure a high recovery rate using the fracture network matching synchronous injection and production method. The pressure threshold can also be adjusted according to the reservoir properties of the target low permeability reservoir, which is not limited in the embodiments of the present application.

[0089] Synchronous water injection refers to the simultaneous injection and production of water injection wells and oil production wells, while advanced water injection refers to the injection of water injection wells before the production of oil production wells. By injecting water into production wells before the production of low permeability reservoirs with formation pressure below the pressure threshold, the formation pressure can be increased, so that when the subsequent oil production wells are put into production, the formation has higher energy to drive the flow of oil, thereby achieving a better recovery rate for low permeability reservoirs.

[0090] In addition, through the fracture network matching technology, the injection and production well network can be matched with the direction of the fracture, avoiding the occurrence of ineffective water injection and explosive flooding.

[0091] In other embodiments, if the acquired development methods include gas drive method and energy storage imbibition method, in this case, it is necessary to determine whether the target low permeability oil reservoir has a gas source; if the target low permeability oil reservoir has a gas source, then the development method of the target low permeability oil reservoir is determined to be gas drive method, otherwise, the development method of the target low permeability oil reservoir is determined to be energy storage imbibition method.

[0092] Since the viscosity of gas to oil is lower than that of water to oil, the development effect of gas drive is better than that of water drive energy storage and absorption development. Therefore, if the target low permeability reservoir has a gas source, gas drive is the preferred development method.

[0093] The gases that can be used in the gas drive method mainly include carbon dioxide, natural gas, nitrogen, air, flue gas, etc. In practical applications, different gases can be selected according to the gas source conditions of each oil reservoir, and the embodiments of the present application do not limit this. For example, there is a low permeability oil reservoir in an oil field with a carbon dioxide gas source. If the development method of the low permeability oil reservoir includes a gas drive method, carbon dioxide can be used for gas drive development, and there is no need to find other gases to avoid excessive economic costs.

[0094] In addition, in actual development, on the basis of ensuring the gas source, miscible drive should be achieved as much as possible so that the gas and crude oil form a uniform phase, ensuring that the capillary force of the oil retained in the pores is reduced or disappears, thereby allowing the crude oil to be better driven to the oil wells.

[0095] In other embodiments, the energy storage imbibition mode includes an energy storage displacement mode and an energy storage throughput mode; in this case, determining that the development mode of the target low permeability oil reservoir is the energy storage imbibition mode includes: if the actual parameter of the average throat radius is greater than the throat radius threshold, the actual parameter of the starting pressure gradient is greater than the gradient threshold and the actual parameter of the porosity is greater than the porosity threshold, then determining that the development mode of the target low permeability oil reservoir is the energy storage displacement mode; otherwise, determining that the development mode of the target low permeability oil reservoir is the energy storage throughput mode.

[0096] Among them, the throat radius threshold, gradient threshold and porosity threshold are respectively the critical values ​​of the average throat radius, starting pressure gradient and porosity for successfully establishing the displacement system. These three thresholds can be adjusted according to the reservoir properties of the target low permeability reservoir in actual applications, and the embodiments of the present application do not limit this.

[0097] Judging whether the actual parameters of the average throat radius, starting pressure gradient and porosity of the target low permeability reservoir are all greater than their corresponding thresholds is actually judging the reservoir connectivity of the target low permeability reservoir. If the actual parameters of the average throat radius, starting pressure gradient and porosity of the target low permeability reservoir are all greater than their corresponding thresholds, it means that the reservoir connectivity of the target low permeability reservoir is good. If at least one of the actual parameters of the average throat radius, starting pressure gradient and porosity of the target low permeability reservoir is less than its corresponding threshold, it means that the reservoir connectivity of the target low permeability reservoir is poor.

[0098] Since the development effect of the energy storage displacement method is better than that of the energy storage throughput method, but the energy storage displacement development requires the reservoir to have good connectivity, therefore, when the development method of the target low permeability oil reservoir is the energy storage imbibition method, for the target low permeability oil reservoir with good reservoir connectivity, the energy storage displacement method can be selected to establish a displacement system, and for the target low permeability oil reservoir with poor reservoir connectivity, the energy storage throughput method can be selected to achieve local imbibition replacement. In this way, the reservoir properties of the target low permeability oil reservoir can be better utilized to achieve an increase in the reservoir recovery rate.

[0099] In other embodiments, if the development methods obtained include gas drive method, energy storage imbibition method and volume fracturing asynchronous injection and production imbibition oil production method, in this case, it is necessary to determine whether the gas source of the target low permeability oil reservoir is sufficient; if the gas source of the target low permeability oil reservoir is sufficient, then the development method of the target low permeability oil reservoir is determined to be gas drive method; if the gas source of the target low permeability oil reservoir is insufficient, then the development method of the target low permeability oil reservoir is determined to be energy storage imbibition method or volume fracturing asynchronous injection and production imbibition oil production method.

[0100] Among them, in the volume fracturing asynchronous injection and production percolation oil production method, the deployment of the injection and production well network must match the anisotropy of the reservoir, natural micro-fracture characteristics, artificial fracture characteristics, etc. of the target low-permeability oil reservoir, and the direction of the injection well row and the oil production well row should be kept consistent with the direction of the maximum principal stress of the formation as much as possible. At the same time, the well network is selected as a rectangular five-point well network.

[0101] If the development method of the target low permeability reservoir is determined to be the energy storage and imbibition method or the volume fracturing asynchronous injection and production and imbibition oil production method, since the volume fracturing asynchronous injection and production and imbibition oil production method has the highest cost but the best development effect, if the cost is not considered, the volume fracturing asynchronous injection and production and imbibition oil production method should be selected at this time, otherwise the energy storage and imbibition method should be selected; if the energy storage and imbibition method is selected, and the energy storage and imbibition method includes the energy storage displacement method and the energy storage throughput method, then the reservoir connectivity of the target low permeability reservoir must be judged. If the connectivity is good, the energy storage displacement method should be selected, and if the connectivity is not good, the energy storage throughput method should be selected. In this way, the effective exploitation of the target low permeability reservoir can be achieved while considering the economic benefits.

[0102] In other embodiments, if the development methods obtained include gas drive method and volume fracturing asynchronous injection and production permeation and imbibition oil production method, in this case, it is also necessary to determine whether the gas source of the target low permeability oil reservoir is sufficient; if the gas source of the target low permeability oil reservoir is sufficient, then the development method of the target low permeability oil reservoir is determined to be gas drive method; if the gas source of the target low permeability oil reservoir is insufficient, then the development method of the target low permeability oil reservoir is determined to be volume fracturing asynchronous injection and production permeation and imbibition oil production method.

[0103] For example, assuming that the corresponding relationship between the reservoir classification coefficient range and the development mode is shown in Table 2, Table 2 also shows the low permeability reservoir categories and corresponding permeability ranges corresponding to different reservoir classification coefficient ranges. Assuming that the reservoir classification coefficient of the target low permeability reservoir is 14.7, and the reservoir classification coefficient range is 14.0<F≤15.3, the development modes obtained at this time include gas drive mode and energy storage imbibition mode.

[0104] Table 2

[0105]

[0106] The correspondence between the above-mentioned reservoir classification coefficient range and the development mode can be obtained by field detection, processing and analysis of multiple low permeability reservoirs, or by other methods, which is not limited in the embodiments of the present application.

[0107] In some embodiments, the correspondence between the above-mentioned reservoir classification coefficient range and the development mode can be obtained in the following manner, that is, obtaining multiple core data corresponding to multiple low permeability reservoirs respectively, and the multiple core data include actual parameters of permeability and development effect influencing factors of low permeability reservoirs; determining the reservoir classification coefficient of the first low permeability reservoir based on the actual parameters of the development effect influencing factors of the low permeability reservoirs in the core data; the first low permeability reservoir is any one of the multiple low permeability reservoirs, and after determining the reservoir classification coefficients of other low permeability reservoirs in the multiple low permeability reservoirs in the same manner as above, generating a fitting curve of the permeability and reservoir classification coefficient of the multiple low permeability reservoirs; based on the fitting curve, dividing the reservoir classification coefficient into intervals and determining the development mode of the low permeability reservoir corresponding to each reservoir classification coefficient range, that is, obtaining the correspondence between the reservoir classification coefficient range of the low permeability reservoir and the development mode.

[0108] The method for determining the reservoir classification coefficient of the first low permeability reservoir based on the actual parameters of the factors affecting the development effect of the low permeability reservoir in the core data may be the related implementation method in the above step 102, which will not be repeated here.

[0109] Since the reservoir classification coefficient obtained in the embodiment of the present application is obtained based on the factors affecting the development effect of the low permeability reservoir, and these factors affecting the development effect are positively correlated or negatively correlated with the permeability of the reservoir, there is a correlation between the reservoir classification coefficient obtained in the embodiment of the present application and the permeability of the reservoir. In this way, according to the fitting curve of the permeability of the low permeability reservoir and the reservoir classification coefficient, when the reservoir classification coefficient of the low permeability reservoir is divided into intervals, the permeability of the low permeability reservoir is referred to. In fact, as described in step 102, the coarse-grained permeability of the target low permeability reservoir is finely divided through the reservoir classification coefficient.

[0110] For example, a series of core data of 13 low permeability reservoirs are obtained, including actual parameters of permeability, average throat radius, movable fluid percentage, formation pressure coefficient, hydrophilicity, porosity, start-up pressure gradient, clay mineral content, crude oil viscosity and reservoir burial depth, and the corresponding reservoir classification coefficient is determined. The obtained data results are shown in Table 3 below.

[0111] Table 3

[0112]

[0113] Based on the permeabilities of the 13 low permeability reservoirs and the corresponding reservoir classification coefficients in Table 3, the fitting curves of the permeability and reservoir classification coefficients of the low permeability reservoirs are obtained, as shown in Figure 4 shown.

[0114] Through field development verification of these 13 low permeability reservoirs, we have gained an understanding of the development effects of 52 development units in these 13 low permeability reservoirs. Figure 2 , Figure 2 The relationship between the recovery rate and the permeability of 52 development units of these 13 low permeability reservoirs is shown. Figure 2 It can be seen that the recovery rate of the development unit with a permeability above 10mD is average or high, but for the development unit with a permeability below 10mD, the recovery rate is low, and it is difficult to achieve conventional water drive development, and other targeted energy replenishment methods are required; at the same time, please refer to Figure 3 , Figure 3 The relationship between the starting pressure gradient and the permeability is shown. The curve has an inflection point at 3mD. When the permeability is less than 3mD, the starting pressure gradient rises rapidly, indicating that for low permeability reservoirs with a permeability less than 3mD, water drive development is more difficult and requires gas drive or volume fracturing asynchronous injection and production permeation oil production development methods.

[0115] Based on the above fitting curve and the understanding of the development effects of the 13 low permeability reservoirs, the reservoir classification coefficient is divided into five intervals, namely: F>15.9, 15.3<F≤15.9, 14.0<F≤15.3, 13<F≤14 and F≤13. The low permeability reservoirs with reservoir classification coefficients in these five intervals can be respectively called low permeability type I (F>15.9), low permeability type II (15.3<F≤15.9), low permeability type III (14.0<F≤15.3), low permeability type IV (13<F≤14) and low permeability type V (F≤13) reservoirs. The selectable development methods for the low permeability reservoirs in each interval are determined, and the corresponding relationship between the reservoir classification coefficient range and the development method can be obtained as shown in Table 2 above.

[0116] The following is an example of a practical application of the method provided in the embodiment of the present application:

[0117] Assume that a low permeability reservoir in a certain oil field is to be developed. First, the actual parameters of the factors affecting the development effect of the low permeability reservoir are obtained, which are: the average throat radius is 3.77μm, the percentage of movable fluid is 63.16%, the formation pressure coefficient is 1.33, the hydrophilicity coefficient is 0.76, the porosity is 19.66%, the starting pressure gradient is 0.08MPa / m, the clay mineral content is 7.7%, the crude oil viscosity is 7.38mPa·s, and the reservoir burial depth is 2342.97m.

[0118] Assuming that the calibration parameters select the boundary value of the fifth category in the single factor classification standard, the weight coefficients of the average throat radius, porosity and starting pressure gradient are selected as 1.2, the weight coefficients of the movable fluid percentage, hydrophilicity and clay mineral content are selected as 1.0, and the weight coefficients of the formation pressure coefficient, crude oil viscosity and reservoir burial depth are selected as 0.8.

[0119] Based on the above-mentioned first-category influencing factors, namely, the actual parameters, weight coefficients and corresponding calibration parameters of the average throat radius, movable fluid percentage, formation pressure coefficient, hydrophilicity coefficient and porosity, the first classification coefficient is determined as

[0120]

[0121] Based on the above second category influencing factors, namely, the actual parameters of starting pressure gradient, clay mineral content, crude oil viscosity and reservoir depth, weight coefficient and corresponding calibration parameters, the second classification coefficient is determined as follows:

[0122]

[0123] So the reservoir classification coefficient of the low permeability reservoir is

[0124] F=F1+F2=15.6581.

[0125] Assuming that the corresponding relationship between the reservoir classification coefficient range and the development mode in the example of step 103 is used to determine the development mode, the classification coefficient of the low permeability reservoir is in the range of 15.3<F≤15.9, that is, the low permeability reservoir is a low permeability Class II reservoir, so the development mode of the low permeability reservoir is selected from the fracture network matching synchronous water injection mode and the fracture network matching advanced water injection mode. At this time, it is necessary to compare its bottom pressure coefficient with the pressure threshold. Assuming that the pressure threshold is 1.1, and it is known that the formation pressure coefficient of the low permeability reservoir is 1.33, the formation pressure coefficient of the low permeability reservoir is greater than the pressure threshold, therefore, it is determined that the development mode of the low permeability reservoir is the fracture network matching synchronous water injection development mode.

[0126] In the embodiment of the present application, the reservoir classification coefficient and the corresponding development method of the target low permeability oil reservoir are determined by comprehensively considering a series of factors that affect the development effect of the low permeability oil reservoir. For the situation where the development method is optional, the development method is further determined by judging the relevant reservoir properties of the target low permeability oil reservoir. Compared with the previous method of determining the development method only by permeability, it is more reasonable and meets the actual application needs. It can quickly and accurately determine the development method of the target low permeability oil reservoir, avoiding the economic losses and low recovery rate caused by unreasonable selection of development methods during the reservoir development process.

[0127] Figure 5 This is a schematic diagram of a device for determining a development method of a low permeability reservoir provided in an embodiment of the present application. Please refer to Figure 5 The device includes: an acquisition module 501, a first determination module 502 and a second determination module 503.

[0128] An acquisition module 501 is used to acquire actual parameters of development effect influencing factors of a target low permeability oil reservoir, wherein the development effect influencing factors include average throat radius, movable fluid percentage, formation pressure coefficient, hydrophilicity coefficient, porosity, start-up pressure gradient, clay mineral content, crude oil viscosity and reservoir burial depth;

[0129] The first determination module 502 is used to determine the reservoir classification coefficient of the target low permeability reservoir based on the actual parameters of the development effect influencing factors, and the reservoir classification coefficient is used to finely divide the coarse-grained permeability of the target low permeability reservoir;

[0130] The second determination module 503 is used to determine the development mode of the target low permeability oil reservoir based on the reservoir classification coefficient of the target low permeability oil reservoir and from the corresponding relationship between the reservoir classification coefficient range and the development mode.

[0131] Optionally, the development effect influencing factors include first-type influencing factors and second-type influencing factors, the first-type influencing factors are positively correlated with reservoir permeability, and the second-type influencing factors are negatively correlated with reservoir permeability; the first determination module includes:

[0132] A first coefficient determination submodule, used to determine a first classification coefficient based on actual parameters, weight coefficients and calibration parameters of the first type of influencing factors;

[0133] A second coefficient determination submodule, used to determine a second classification coefficient based on actual parameters, weight coefficients and calibration parameters of the second type of influencing factors;

[0134] The third coefficient determination submodule is used to determine the reservoir classification coefficient based on the first classification coefficient and the second classification coefficient.

[0135] Optionally, the first type of influencing factors includes average throat radius, movable fluid percentage, formation pressure coefficient, hydrophilicity coefficient and porosity; the first coefficient determination submodule is specifically used for:

[0136] Based on the actual parameters, weight coefficients and calibration parameters of the first category influencing factors, the first classification coefficient is determined according to the following formula;

[0137]

[0138] Among them, F1 represents the first classification coefficient, i represents the i-th influencing factor in the first category of influencing factors, m represents the number of influencing factors in the first category, c i represents the actual parameter of the i-th influencing factor, k i represents the weight coefficient of the i-th influencing factor, c istd Represents the calibration parameter of the i-th influencing factor.

[0139] Optionally, the second type of influencing factors includes starting pressure gradient, clay mineral content, crude oil viscosity and reservoir depth; the second coefficient determination submodule is specifically used for:

[0140] Based on the actual parameters, weight coefficients and calibration parameters of the second category influencing factors, the second classification coefficient is determined according to the following formula;

[0141]

[0142] Among them, F2 represents the second classification coefficient, j represents the jth influencing factor in the second category of influencing factors, n represents the number of influencing factors in the second category, and d j represents the actual parameter of the jth influencing factor, J j represents the weight coefficient of the jth influencing factor, d jstd Represents the calibration parameter of the jth influencing factor.

[0143] Optionally, the weight coefficients of average throat radius, porosity and starting pressure gradient are primary weight coefficients, the weight coefficients of movable fluid percentage, hydrophilicity coefficient and clay mineral content are secondary weight coefficients, and the weight coefficients of formation pressure coefficient, crude oil viscosity and reservoir burial depth are tertiary weight coefficients;

[0144] Among them, the first-level weight coefficient is greater than the second-level weight coefficient, and the second-level weight coefficient is greater than the third-level weight coefficient.

[0145] Optionally, the second determining module is specifically configured to:

[0146] From the corresponding relationship between the reservoir classification coefficient range and the development mode, the development mode corresponding to the reservoir classification coefficient of the target low permeability reservoir is obtained;

[0147] If the obtained development methods include the fracture network matching synchronous water injection method and the fracture network matching advanced water injection method, determining whether the formation pressure coefficient is lower than the pressure threshold;

[0148] If the formation pressure coefficient is lower than the pressure threshold, the development mode of the target low permeability reservoir is determined to be the fracture network matching advance water injection mode; otherwise, the development mode of the target low permeability reservoir is determined to be the fracture network matching synchronous water injection mode.

[0149] Optionally, the second determining module is further used for:

[0150] If the development methods obtained include gas drive and energy storage and imbibition, determine whether the target low permeability reservoir has a gas source;

[0151] If the target low permeability oil reservoir has a gas source, the development mode of the target low permeability oil reservoir is determined to be a gas drive mode; otherwise, the development mode of the target low permeability oil reservoir is determined to be an energy storage imbibition mode.

[0152] Optionally, the energy storage infiltration mode includes an energy storage displacement mode and an energy storage throughput mode; the second determination module is further used for:

[0153] If the actual parameter of the average throat radius is greater than the throat radius threshold, the actual parameter of the starting pressure gradient is greater than the gradient threshold, and the actual parameter of the porosity is greater than the porosity threshold, then the development mode of the target low permeability reservoir is determined to be the energy storage displacement mode; otherwise, the development mode of the target low permeability reservoir is determined to be the energy storage throughput mode.

[0154] Optionally, the second determining module is further used for:

[0155] If the development methods obtained include gas drive, energy storage and imbibition, and volume fracturing asynchronous injection and production and imbibition production, determine whether the gas source of the target low permeability reservoir is sufficient;

[0156] If the target low permeability reservoir has sufficient gas source, the development method of the target low permeability reservoir is determined to be gas drive;

[0157] If the gas source of the target low permeability reservoir is insufficient, the development method of the target low permeability reservoir is determined to be the energy storage imbibition method or the volume fracturing asynchronous injection and production imbibition oil production method.

[0158] In the embodiments of the present application, the reservoir classification coefficient of the target low permeability oil reservoir and the corresponding development method are determined by comprehensively considering a series of factors that affect the development effect of the low permeability oil reservoir. For the situation where the development method is optional, the development method is further determined by judging the relevant reservoir properties of the target low permeability oil reservoir. In practical applications, the development method of the target low permeability oil reservoir can be determined quickly and accurately, avoiding economic losses and low recovery rates caused by unreasonable selection of development methods during the reservoir development process.

[0159] It should be noted that: the device for determining the development mode of a low permeability oil reservoir provided in the above embodiment only uses the division of the above functional modules as an example when determining the development mode of a local oil reservoir. In actual applications, the above functional distribution can be completed by different functional modules as needed, that is, the internal structure of the device is divided into different functional modules to complete all or part of the functions described above. In addition, the device for determining the development mode of a low permeability oil reservoir provided in the above embodiment and the method for determining the development mode of a low permeability oil reservoir belong to the same concept. The specific implementation process is detailed in the method embodiment and will not be repeated here.

[0160] Figure 6 6 is a block diagram of a terminal 600 provided in an embodiment of the present application. The terminal 600 may be a portable mobile terminal, such as a smart phone, a tablet computer, an MP3 player (Moving Picture Experts Group Audio Layer III), an MP4 player (Moving Picture Experts Group Audio Layer IV), a laptop computer or a desktop computer. The terminal 600 may also be referred to as a user device, a portable terminal, a laptop terminal, a desktop terminal or other names.

[0161] Typically, the terminal 600 includes a processor 601 and a memory 602 .

[0162] The processor 601 may include one or more processing cores, such as a 4-core processor, an 8-core processor, etc. The processor 601 may be implemented in at least one hardware form of DSP (Digital Signal Processing), FPGA (Field Programmable Gate Array), and PLA (Programmable Logic Array). The processor 601 may also include a main processor and a coprocessor. The main processor is a processor for processing data in an awake state, also known as a CPU (Central Processing Unit); the coprocessor is a low-power processor for processing data in a standby state. In some embodiments, the processor 601 may be integrated with a GPU (Graphics Processing Unit), which is responsible for rendering and drawing the content to be displayed on the display screen. In some embodiments, the processor 601 may also include an AI (Artificial Intelligence) processor, which is used to process computing operations related to machine learning.

[0163] The memory 602 may include one or more computer-readable storage media, which may be non-transitory. The memory 602 may also include a high-speed random access memory, and a non-volatile memory, such as one or more disk storage devices, flash memory storage devices. In some embodiments, the non-transitory computer-readable storage medium in the memory 602 is used to store at least one instruction, which is used to be executed by the processor 601 to implement the method for determining the development mode of a low permeability reservoir provided in the method embodiment of the present application.

[0164] In some embodiments, the terminal 600 may further optionally include: a peripheral device interface 603 and at least one peripheral device. The processor 601, the memory 602 and the peripheral device interface 603 may be connected via a bus or a signal line. Each peripheral device may be connected to the peripheral device interface 603 via a bus, a signal line or a circuit board. Specifically, the peripheral device includes: at least one of a radio frequency circuit 604, a display screen 605, a camera assembly 606, an audio circuit 607, a positioning assembly 608 and a power supply 609.

[0165] The peripheral device interface 603 may be used to connect at least one peripheral device related to I / O (Input / Output) to the processor 601 and the memory 602. In some embodiments, the processor 601, the memory 602, and the peripheral device interface 603 are integrated on the same chip or circuit board; in some other embodiments, any one or two of the processor 601, the memory 602, and the peripheral device interface 603 may be implemented on a separate chip or circuit board, which is not limited in this embodiment.

[0166] The radio frequency circuit 604 is used to receive and transmit RF (Radio Frequency) signals, also known as electromagnetic signals. The radio frequency circuit 604 communicates with the communication network and other communication devices through electromagnetic signals. The radio frequency circuit 604 converts the electrical signal into an electromagnetic signal for transmission, or converts the received electromagnetic signal into an electrical signal. Optionally, the radio frequency circuit 604 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 radio frequency circuit 604 can communicate with other terminals through at least one wireless communication protocol. The wireless communication protocol includes but is not limited to: the World Wide Web, a metropolitan area network, an intranet, various generations of mobile communication networks (2G, 3G, 4G and 5G), a wireless local area network and / or a WiFi (Wireless Fidelity) network. In some embodiments, the radio frequency circuit 604 may also include circuits related to NFC (Near Field Communication), which is not limited in the embodiments of the present application.

[0167] The display screen 605 is used to display the UI (User Interface). The UI may include graphics, text, icons, videos and any combination thereof. When the display screen 605 is a touch display screen, the display screen 605 also has the ability to collect touch signals on the surface or above the surface of the display screen 605. The touch signal can be input to the processor 601 as a control signal for processing. At this time, the display screen 605 can also be used to provide virtual buttons and / or virtual keyboards, also known as soft buttons and / or soft keyboards. In some embodiments, the display screen 605 can be one, and the front panel of the terminal 600 is set; in other embodiments, the display screen 605 can be at least two, which are respectively set on different surfaces of the terminal 600 or are folded; in some other embodiments, the display screen 605 can be a flexible display screen, which is set on the curved surface or folded surface of the terminal 600. Even, the display screen 605 can also be set to a non-rectangular irregular shape, that is, a special-shaped screen. The display screen 605 can be made of materials such as LCD (Liquid Crystal Display), OLED (Organic Light-Emitting Diode, organic light-emitting diode).

[0168] The camera assembly 606 is used to capture images or videos. Optionally, the camera assembly 606 includes a front camera and a rear camera. Typically, the front camera is arranged on the front panel of the terminal, and the rear camera is arranged on the back of the terminal. In some embodiments, there are at least two rear cameras, which are any one of a main camera, a depth of field camera, a wide-angle camera, and a telephoto camera, so as to realize the fusion of the main camera and the depth of field camera to realize the background blur function, the fusion of the main camera and the wide-angle camera to realize the panoramic shooting and VR (Virtual Reality) shooting function or other fusion shooting functions. In some embodiments, the camera assembly 606 may also include a flash. The flash can be a monochrome temperature flash or a dual-color temperature flash. A dual-color temperature flash refers to a combination of a warm light flash and a cold light flash, which can be used for light compensation at different color temperatures.

[0169] The audio circuit 607 may include a microphone and a speaker. The microphone is used to collect sound waves from the user and the environment, and convert the sound waves into electrical signals and input them into the processor 601 for processing, or input them into the radio frequency circuit 604 to achieve voice communication. For the purpose of stereo acquisition or noise reduction, there may be multiple microphones, which are respectively arranged at different parts of the terminal 600. The microphone may also be an array microphone or an omnidirectional acquisition microphone. The speaker is used to convert the electrical signal from the processor 601 or the radio frequency circuit 604 into sound waves. The speaker may be a traditional film speaker or a piezoelectric ceramic speaker. When the speaker is a piezoelectric ceramic speaker, it can not only convert the electrical signal into sound waves audible to humans, but also convert the electrical signal into sound waves inaudible to humans for purposes such as ranging. In some embodiments, the audio circuit 607 may also include a headphone jack.

[0170] The positioning component 608 is used to locate the current geographical location of the terminal 600 to implement navigation or LBS (Location Based Service). The positioning component 608 can be a positioning component of the GPS (Global Positioning System), Beidou system or Galileo system.

[0171] The power supply 609 is used to power various components in the terminal 600. The power supply 609 can be an alternating current, a direct current, a disposable battery, or a rechargeable battery. When the power supply 609 includes a rechargeable battery, the rechargeable battery can be a wired rechargeable battery or a wireless rechargeable battery. A wired rechargeable battery is a battery charged through a wired line, and a wireless rechargeable battery is a battery charged through a wireless coil. The rechargeable battery can also be used to support fast charging technology.

[0172] In some embodiments, the terminal 600 further includes one or more sensors 610 , including but not limited to: an acceleration sensor 611 , a gyroscope sensor 612 , a pressure sensor 613 , a fingerprint sensor 614 , an optical sensor 615 , and a proximity sensor 616 .

[0173] The acceleration sensor 611 can detect the magnitude of acceleration on the three coordinate axes of the coordinate system established by the terminal 600. For example, the acceleration sensor 611 can be used to detect the components of gravity acceleration on the three coordinate axes. The processor 601 can control the touch display screen 605 to display the user interface in a horizontal view or a vertical view according to the gravity acceleration signal collected by the acceleration sensor 611. The acceleration sensor 611 can also be used for collecting game or user motion data.

[0174] The gyro sensor 612 can detect the body direction and rotation angle of the terminal 600, and the gyro sensor 612 can cooperate with the acceleration sensor 611 to collect the user's 3D actions on the terminal 600. The processor 601 can implement the following functions based on the data collected by the gyro sensor 612: motion sensing (such as changing the UI according to the user's tilt operation), image stabilization during shooting, game control, and inertial navigation.

[0175] The pressure sensor 613 can be set on the side frame of the terminal 600 and / or the lower layer of the touch display screen 605. When the pressure sensor 613 is set on the side frame of the terminal 600, it can detect the user's holding signal of the terminal 600, and the processor 601 performs left and right hand recognition or shortcut operation according to the holding signal collected by the pressure sensor 613. When the pressure sensor 613 is set on the lower layer of the touch display screen 605, the processor 601 controls the operability controls on the UI interface according to the user's pressure operation on the touch display screen 605. The operability controls include at least one of a button control, a scroll bar control, an icon control, and a menu control.

[0176] The fingerprint sensor 614 is used to collect the user's fingerprint, and the processor 601 identifies the user's identity based on the fingerprint collected by the fingerprint sensor 614, or the fingerprint sensor 614 identifies the user's identity based on the collected fingerprint. When the user's identity is identified as a trusted identity, the processor 601 authorizes the user to perform relevant sensitive operations, including unlocking the screen, viewing encrypted information, downloading software, paying, and changing settings. The fingerprint sensor 614 can be set on the front, back, or side of the terminal 600. When a physical button or a manufacturer logo is set on the terminal 600, the fingerprint sensor 614 can be integrated with the physical button or the manufacturer logo.

[0177] The optical sensor 615 is used to collect the ambient light intensity. In one embodiment, the processor 601 can control the display brightness of the touch display screen 605 according to the ambient light intensity collected by the optical sensor 615. Specifically, when the ambient light intensity is high, the display brightness of the touch display screen 605 is increased; when the ambient light intensity is low, the display brightness of the touch display screen 605 is reduced. In another embodiment, the processor 601 can also dynamically adjust the shooting parameters of the camera assembly 606 according to the ambient light intensity collected by the optical sensor 615.

[0178] The proximity sensor 616, also called a distance sensor, is usually arranged on the front panel of the terminal 600. The proximity sensor 616 is used to collect the distance between the user and the front of the terminal 600. In one embodiment, when the proximity sensor 616 detects that the distance between the user and the front of the terminal 600 is gradually decreasing, the processor 601 controls the touch display screen 605 to switch from the screen-on state to the screen-off state; when the proximity sensor 616 detects that the distance between the user and the front of the terminal 600 is gradually increasing, the processor 601 controls the touch display screen 605 to switch from the screen-off state to the screen-on state.

[0179] Those skilled in the art will understand that Figure 6 The structure shown in the figure does not constitute a limitation on the terminal 600, and the terminal 600 may include more or less components than those shown in the figure, or combine some components, or adopt a different component arrangement.

[0180] In some embodiments, a computer-readable storage medium is also provided, in which a computer program is stored, and when the computer program is executed by a processor, the steps of the method for determining the development mode of a low permeability reservoir in the above embodiment are implemented. For example, the computer-readable storage medium can be a ROM, RAM, CD-ROM, magnetic tape, floppy disk, optical data storage device, etc.

[0181] It is worth noting that the computer-readable storage medium mentioned in the embodiments of the present application may be a non-volatile storage medium, in other words, a non-transitory storage medium.

[0182] It should be understood that all or part of the steps to implement the above embodiments can be implemented by software, hardware, firmware or any combination thereof. When implemented using software, it can be implemented in whole or in part in the form of a computer program product. The computer program product includes one or more computer instructions. The computer instructions can be stored in the above-mentioned computer readable storage medium.

[0183] That is, in some embodiments, a computer program product comprising instructions is also provided, which, when executed on a computer, enables the computer to execute the steps of the method for determining the development mode of a low permeability oil reservoir as described above.

[0184] It should be understood that the "at least one" mentioned herein refers to one or more, and "multiple" refers to two or more. In the description of the embodiments of the present application, unless otherwise specified, " / " means or, for example, A / B can mean A or B; "and / or" in this article is only a description of the association relationship of the associated objects, indicating that there can be three relationships, for example, A and / or B can mean: A exists alone, A and B exist at the same time, and B exists alone. In addition, in order to facilitate the clear description of the technical solutions of the embodiments of the present application, in the embodiments of the present application, the words "first", "second" and the like are used to distinguish the same items or similar items with basically the same functions and effects. Those skilled in the art can understand that the words "first", "second" and the like do not limit the quantity and execution order, and the words "first", "second" and the like do not limit them to be necessarily different.

[0185] It should be noted that the information (including but not limited to user device information, user personal information, etc.), data (including but not limited to data used for analysis, stored data, displayed data, etc.) and signals involved in the embodiments of the present application are all authorized by the user or fully authorized by all parties, and the collection, use and processing of relevant data need to comply with relevant laws, regulations and standards of relevant countries and regions.

[0186] The above-mentioned embodiments are provided for the present application and are not intended to limit the present application. Any modifications, equivalent substitutions, improvements, etc. made within the spirit and principles of the present application shall be included in the protection scope of the present application.

Claims

1. A method for determining the development mode of a low permeability oil reservoir, characterized in that: The method comprises: Obtaining actual parameters of factors influencing the development effect of the target low-permeability oil reservoir, wherein the factors influencing the development effect include average throat radius, movable fluid percentage, formation pressure coefficient, hydrophilicity coefficient, porosity, start-up pressure gradient, clay mineral content, crude oil viscosity and reservoir burial depth; Based on the actual parameters of the development effect influencing factors, determining the reservoir classification coefficient of the target low permeability reservoir, the reservoir classification coefficient is used to finely divide the coarse-grained permeability of the target low permeability reservoir; Based on the reservoir classification coefficient of the target low permeability reservoir, the development method of the target low permeability reservoir is determined from the corresponding relationship between the reservoir classification coefficient range and the development method.

2. The method according to claim 1, characterized in that The development effect influencing factors include first-type influencing factors and second-type influencing factors, the first-type influencing factors are positively correlated with reservoir permeability, and the second-type influencing factors are negatively correlated with reservoir permeability; The determining of the reservoir classification coefficient of the target low permeability reservoir based on the actual parameters of the development effect influencing factors includes: Determining a first classification coefficient based on actual parameters, weight coefficients and calibration parameters of the first category of influencing factors; Determining a second classification coefficient based on the actual parameters, weight coefficients and calibration parameters of the second type of influencing factors; The reservoir classification coefficient is determined based on the first classification coefficient and the second classification coefficient.

3. The method according to claim 2, characterized in that The first type of influencing factors includes the average throat radius, the movable fluid percentage, the formation pressure coefficient, the hydrophilicity coefficient and the porosity; the first classification coefficient is determined based on the actual parameters of the first type of influencing factors, including: Based on the actual parameters, weight coefficients and calibration parameters of the first category of influencing factors, the first classification coefficient is determined according to the following formula; Wherein, F1 represents the first classification coefficient, i represents the i-th influencing factor in the first category of influencing factors, m represents the number of the first category of influencing factors, and c i represents the actual parameter of the i-th influencing factor, the k i represents the weight coefficient of the i-th influencing factor, the c istd represents the calibration parameter of the i-th influencing factor.

4. The method according to claim 2, characterized in that The second type of influencing factors include the starting pressure gradient, the clay mineral content, the crude oil viscosity and the reservoir burial depth; the second classification coefficient is determined based on the actual parameters of the second type of influencing factors, including: Based on the actual parameters, weight coefficients and calibration parameters of the second type of influencing factors, the second classification coefficient is determined according to the following formula; Wherein, F2 represents the second classification coefficient, j represents the jth influencing factor in the second category of influencing factors, n represents the number of the second category of influencing factors, and d j represents the actual parameter of the jth influencing factor, the J j represents the weight coefficient of the jth influencing factor, and the d jstd represents the calibration parameter of the j-th influencing factor.

5. The method according to any one of claims 2 to 4, characterized in that: The weight coefficients of the average throat radius, the porosity and the starting pressure gradient are primary weight coefficients, the weight coefficients of the movable fluid percentage, the hydrophilicity coefficient and the clay mineral content are secondary weight coefficients, and the weight coefficients of the formation pressure coefficient, the crude oil viscosity and the reservoir burial depth are tertiary weight coefficients; Among them, the first-level weight coefficient is greater than the second-level weight coefficient, and the second-level weight coefficient is greater than the third-level weight coefficient.

6. The method according to claim 1, characterized in that The method of determining the development method of the target low permeability oil reservoir based on the reservoir classification coefficient of the target low permeability oil reservoir and from the corresponding relationship between the reservoir classification coefficient range and the development method includes: Obtaining the development method corresponding to the reservoir classification coefficient of the target low permeability reservoir from the corresponding relationship between the reservoir classification coefficient range and the development method; If the acquired development mode includes a fracture network matching synchronous water injection mode and a fracture network matching advanced water injection mode, determining whether the formation pressure coefficient is lower than a pressure threshold; If the formation pressure coefficient is lower than the pressure threshold, the development mode of the target low permeability oil reservoir is determined to be the fracture network matching advance water injection mode; otherwise, the development mode of the target low permeability oil reservoir is determined to be the fracture network matching synchronous water injection mode.

7. The method according to claim 6, characterized in that The method further comprises: If the obtained development methods include gas drive method and energy storage imbibition method, determining whether the target low permeability oil reservoir has a gas source; If the target low permeability oil reservoir has a gas source, the development mode of the target low permeability oil reservoir is determined to be the gas drive mode; otherwise, the development mode of the target low permeability oil reservoir is determined to be the energy storage imbibition mode.

8. The method according to claim 7, characterized in that The energy storage imbibition mode includes an energy storage displacement mode and an energy storage throughput mode; the development mode of the target low permeability reservoir is determined to be the energy storage imbibition mode, including: If the actual parameter of the average throat radius is greater than the throat radius threshold, the actual parameter of the starting pressure gradient is greater than the gradient threshold, and the actual parameter of the porosity is greater than the porosity threshold, then the development mode of the target low permeability oil reservoir is determined to be the energy storage displacement mode; otherwise, the development mode of the target low permeability oil reservoir is determined to be the energy storage throughput mode.

9. The method according to claim 6, characterized in that The method further comprises: If the development methods obtained include gas drive, energy storage and imbibition, and volume fracturing asynchronous injection and production and imbibition oil production, then determine whether the gas source of the target low permeability oil reservoir is sufficient; If the gas source of the target low permeability oil reservoir is sufficient, determining that the development method of the target low permeability oil reservoir is the gas drive method; If the gas source of the target low permeability oil reservoir is insufficient, the development mode of the target low permeability oil reservoir is determined to be the energy storage imbibition mode or the volume fracturing asynchronous injection and production imbibition oil production mode.

10. A device for determining the development mode of a low permeability oil reservoir, characterized in that: The device comprises: An acquisition module is used to acquire actual parameters of development effect influencing factors of a target low permeability oil reservoir, wherein the development effect influencing factors include average throat radius, movable fluid percentage, formation pressure coefficient, hydrophilicity coefficient, porosity, start-up pressure gradient, clay mineral content, crude oil viscosity and reservoir burial depth; A first determination module is used to determine the reservoir classification coefficient of the target low permeability reservoir based on the actual parameters of the development effect influencing factors, and the reservoir classification coefficient is used to finely divide the coarse-grained permeability of the target low permeability reservoir; The second determination module is used to determine the development mode of the target low permeability oil reservoir based on the reservoir classification coefficient of the target low permeability oil reservoir and from the corresponding relationship between the reservoir classification coefficient range and the development mode.

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