Method for determining development mode of low-permeability oil reservoir and related device

Abstract

This application discloses a method and related apparatus for determining the development mode of a low-permeability reservoir, belonging to the field of oil and gas exploration. The method includes: obtaining actual parameters of factors influencing the development effectiveness of a target low-permeability reservoir; determining the reservoir classification coefficient of the target low-permeability reservoir based on the actual parameters of these factors; and determining the development mode of the target low-permeability reservoir based on the reservoir classification coefficient and the correspondence between the reservoir classification coefficient range and the development mode. This application, by determining the reservoir classification coefficient based on factors influencing the development effectiveness and establishing the correspondence between the reservoir classification coefficient range and the development mode, can quickly and accurately determine the development mode of a target low-permeability reservoir in practical applications, avoiding economic losses and low recovery rates caused by unreasonable development mode selection during reservoir development.

Description

Technical Field

[0001] This application relates to the field of oil and gas exploration, and in particular to a method and related apparatus for determining the development mode of low-permeability oil reservoirs. Background Technology

[0002] As most of my country's oilfields enter the middle and late stages of development, low-permeability and ultra-low-permeability reservoirs are gradually becoming the main body of oilfield development in my country. Low-permeability reservoir resources account for nearly 60% of the total oilfield resources in the country. Therefore, it is particularly important to develop low-permeability reservoirs using effective development methods.

[0003] In my country, reservoirs with permeability less than 50 mD are generally classified as low-permeability reservoirs. Their development methods are often determined directly based on the permeability range. Conventional low-permeability reservoirs with permeability between 20-50 mD can generally be developed using waterflooding. However, reservoirs with permeability between 5-20 mD, especially those around 10 mD, show significantly different development outcomes. Some reservoirs can be waterflooded with good results, but others, due to narrow throats, are prone to deep-layer blockage when water is injected, leading to poor conventional waterflooding performance. Therefore, accurately determining the development method for low-permeability reservoirs is a pressing issue that needs to be addressed. Summary of the Invention

[0004] This application provides a method and related apparatus for determining the development mode of low-permeability reservoirs, which can accurately identify the development mode of low-permeability reservoirs. The technical solution is as follows:

[0005] On the one hand, a method for determining the development mode of low-permeability reservoirs is provided, the method comprising:

[0006] The actual parameters of the factors affecting the development effect of the target low-permeability reservoir are obtained. These factors include average throat radius, percentage of movable fluid, formation pressure coefficient, hydrophilicity coefficient, porosity, starting pressure gradient, clay mineral content, crude oil viscosity, and reservoir depth.

[0007] Based on the actual parameters of the factors affecting the development effect, the reservoir classification coefficient of the target low-permeability reservoir is determined. The reservoir classification coefficient is used to finely classify 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 mode of the target low-permeability reservoir is determined from the correspondence between the reservoir classification coefficient range and the development mode.

[0009] Optionally, the factors affecting the development effect include a first type of influencing factor and a second type of influencing factor, wherein the first type of influencing factor is positively correlated with reservoir permeability and the second type of influencing factor is negatively correlated with reservoir permeability;

[0010] The reservoir classification coefficient of the target low-permeability reservoir is determined based on the actual parameters of the factors influencing the development effect, including:

[0011] The first classification coefficient is determined based on the actual parameters, weight coefficients, and calibration parameters of the first type of influencing factors.

[0012] The second classification coefficient is determined 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 category of influencing factors includes the average throat radius, the percentage of movable fluid, the formation pressure coefficient, the hydrophilicity coefficient, and the porosity; determining the first classification coefficient based on the actual parameters of the first category of influencing factors includes:

[0015] 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;

[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 influencing factors in the first category, and c i The k represents the actual parameter of the i-th influencing factor. i The c represents the weight coefficient of the i-th influencing factor. istd This represents the calibration parameter of the i-th influencing factor.

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

[0019] Based on the actual parameters, weighting coefficients, and calibration parameters of the second category 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 j-th influencing factor in the second category of influencing factors, n represents the number of influencing factors in the second category, and d j J represents the actual parameter of the j-th influencing factor. jThe d represents the weight coefficient of the j-th influencing factor. jstd This represents the calibration parameter of the j-th influencing factor.

[0022] Optionally, the weighting coefficients of the average throat radius, the porosity, and the starting pressure gradient are first-level weighting coefficients; the weighting coefficients of the percentage of movable fluid, the hydrophilicity coefficient, and the clay mineral content are second-level weighting coefficients; and the weighting coefficients of the formation pressure coefficient, the crude oil viscosity, and the reservoir burial depth are third-level weighting coefficients.

[0023] Wherein, 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, determining the development mode of the target low-permeability reservoir based on the reservoir classification coefficient and the correspondence between the reservoir classification coefficient range and the development mode includes:

[0025] From the correspondence between the reservoir classification coefficient range and the development method, the development method corresponding to the reservoir classification coefficient of the target low-permeability reservoir is obtained;

[0026] If the obtained development methods include the fracture-mesh matching synchronous water injection method and the fracture-mesh matching advanced water injection method, then determine whether the formation pressure coefficient is lower than the pressure threshold.

[0027] If the formation pressure coefficient is lower than the pressure threshold, the development method for the target low-permeability reservoir is determined to be the fracture-network matched advance water injection method; otherwise, the development method for the target low-permeability reservoir is determined to be the fracture-network matched synchronous water injection method.

[0028] Optionally, if the obtained development methods include gas drive and energy storage and infiltration, then it is determined whether the target low-permeability reservoir has a gas source;

[0029] If the target low-permeability reservoir has a gas source, then the development method of the target low-permeability reservoir is determined to be the gas drive method; otherwise, the development method of the target low-permeability reservoir is determined to be the energy storage and infiltration method.

[0030] Optionally, the energy storage and permeation method includes energy storage and displacement and energy storage and huff / puff; the determination of the development method for the target low-permeability reservoir as the energy storage and permeation method 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 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 huff and puff mode.

[0032] Optionally, if the obtained development methods include gas drive, energy storage and infiltration, and volumetric fracturing asynchronous injection and production infiltration, then it is determined whether the gas source of the target low-permeability reservoir is sufficient.

[0033] If the gas source of the target low-permeability reservoir is sufficient, then the development method of the target low-permeability reservoir is determined to be the gas drive method;

[0034] 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 either the energy storage and infiltration method or the volumetric fracturing asynchronous injection-production infiltration method.

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

[0036] The acquisition module is used to acquire actual parameters of the factors affecting the development effect of the target low-permeability reservoir. These factors include average throat radius, percentage of movable fluid, formation pressure coefficient, hydrophilicity coefficient, porosity, starting pressure gradient, clay mineral content, crude oil viscosity, and reservoir depth.

[0037] The first determining module is used to determine the reservoir classification coefficient of the target low-permeability reservoir based on the actual parameters of the factors affecting the development effect. The reservoir classification coefficient is used to finely classify the coarse-grained permeability of the target low-permeability reservoir.

[0038] The second determining module is used to determine the development method of the target low-permeability reservoir based on the reservoir classification coefficient and the correspondence between the reservoir classification coefficient range and the development method.

[0039] On the other hand, a computer device is provided, the computer device including a memory and a processor, the memory for storing computer programs, and the processor for executing the computer programs stored in the memory to implement the steps of the method for determining the development mode of low-permeability reservoirs described above.

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

[0041] On the other hand, a computer program product containing instructions is provided, which, when run on a computer, cause the computer to perform the steps of the method for determining the development mode of a low-permeability reservoir as described above.

[0042] The technical solution provided in this application can bring at least 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 solely through permeability, this method is more reasonable and meets the actual application requirements. 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 development method selection during reservoir development. Attached Figure Description

[0044] To more clearly illustrate the technical solutions in the embodiments of this application, the accompanying drawings used in the description of the embodiments will be briefly introduced below. Obviously, the accompanying drawings described below are only some embodiments of this application. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0045] Figure 1 This is a flowchart illustrating a method for determining the development mode of a low-permeability reservoir, as provided in an embodiment of this application.

[0046] Figure 2 This is a schematic diagram illustrating the relationship between the recovery rate and the permeability of 52 development units obtained from joint mesh matching water injection development provided in this application embodiment;

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

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

[0049] Figure 5 This is a schematic diagram of a device for determining the development mode of a low-permeability reservoir provided in an embodiment of this application;

[0050] Figure 6 This is a schematic diagram of the structure of a terminal provided in an embodiment of this application. Detailed Implementation

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

[0052] Before providing a detailed explanation of the method for determining the development mode of low-permeability reservoirs provided in the embodiments of this application, the application scenarios and implementation environments involved in the embodiments of this application will be introduced first.

[0053] As most of my country's oilfields enter the middle and late stages of development, low-permeability and ultra-low-permeability reservoirs are gradually becoming the main body of oilfield development in my country. Low-permeability reservoir resources account for nearly 60% of the total oilfield resources in the country. Therefore, using effective development methods and formulating reasonable development plans are particularly important for the development of low-permeability reservoirs.

[0054] In my country, reservoirs with permeability less than 50 mD are generally referred to as low-permeability reservoirs. Low-permeability reservoirs are further divided into three subcategories: conventional low-permeability reservoirs with permeability between 10 and 50 mD, ultra-low-permeability reservoirs with permeability between 1 and 10 mD, and extra-low-permeability reservoirs with permeability between 0.1 and 1 mD. Permeability is an important indicator for groundwater, oil, and gas resources. Previously, the development of low-permeability reservoirs primarily used permeability as the main evaluation parameter, and development methods were often determined directly based on the permeability range. Waterflooding can generally be achieved in conventional low-permeability reservoirs with permeability between 20-50 mD. However, the development results vary greatly in reservoirs with permeability between 5-20 mD, especially those with permeability around 10 mD. Some reservoirs can be flooded with water, and conventional waterflooding development is effective. However, in other reservoirs, due to narrow throats, water injection can easily cause deep blockage of the oil layer, resulting in poor conventional waterflooding development. This situation can sometimes lead to problems such as resource waste, reduced economic benefits, and excessively low oilfield recovery rates.

[0055] Based on this, this application provides a method for determining the development mode of low-permeability reservoirs. By using parameters such as average throat radius, percentage of mobile fluid, formation pressure coefficient, hydrophilicity coefficient, porosity, starting pressure gradient, clay mineral content, crude oil viscosity, and reservoir depth, low-permeability reservoirs are finely classified, achieving a clearer understanding of the reservoirs. This allows for the convenient and rapid determination of reasonable development modes for different low-permeability reservoirs, thereby improving the development effect of low-permeability reservoirs and enhancing the efficiency of oilfield development.

[0056] The method for determining the development mode of low-permeability reservoirs provided in this application is executed by a computer device, such as a PC (Personal Computer), mobile phone, smartphone, PDA (Personal Digital Assistant), PPC (Pocket PC), tablet computer, smart car system, etc.

[0057] Those skilled in the art should understand that the above-described computer devices are merely examples, and other existing or future computer devices that are applicable to the embodiments of this application should also be included within the scope of protection of the embodiments of this application, and are hereby incorporated by reference.

[0058] It should be noted that the application scenarios and implementation environments described in the embodiments of this application are for the purpose of more clearly illustrating the technical solutions of the embodiments of this application, and do not constitute a limitation on the technical solutions provided in the embodiments of this application. As those skilled in the art will know, with the emergence of new application scenarios and the evolution of implementation environments, the technical solutions provided in the embodiments of this application are also applicable to similar technical problems.

[0059] The method for determining the development mode of low-permeability reservoirs provided in the embodiments of this application will be explained in detail below.

[0060] Please refer to Figure 1 , Figure 1 This is a flowchart of a method for determining the development mode of a low-permeability reservoir provided in an embodiment of this application. The method includes the following steps.

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

[0062] Low-permeability reservoirs are defined as reservoirs with a permeability of less than 50 mD. Among them, reservoirs with a permeability between 10 and 50 mD are conventional low-permeability reservoirs, reservoirs with a permeability between 1 and 10 mD are ultra-low-permeability reservoirs, and reservoirs with a permeability between 0.1 and 1 mD are extra-low-permeability reservoirs.

[0063] Among the factors influencing the development effect mentioned above, the average throat radius is an important parameter characterizing the pore structure of the reservoir. Pores are enlarged parts surrounded by skeletal particles in the reservoir and play a significant role in fluid storage. Throats refer to the channels between pores, and the average throat radius is the average of the radii of these channels. The percentage of movable fluid is the ratio of the amount of fluid with good flowability under external driving force to the total amount of oil, gas, and water fluids 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 that expands in water to the volume that expands in oil. Porosity is the ratio of the sum of the volumes of all pore spaces in a rock sample to the volume of the rock sample. The starting pressure gradient refers to the pressure gradient at which fluid can overcome the resistance caused by the adsorption film or hydration film on the rock surface when it seeps into a low-permeability oil reservoir. Crude oil viscosity is a measure of the frictional resistance when one part of crude oil flows relative to another part. The reservoir depth is the vertical distance of the oil reservoir from the natural ground surface.

[0064] As described above, directly determining the development method based on the permeability of a low-permeability reservoir may result in a chosen development method that is not actually suitable for that reservoir. In reality, the development effect of a low-permeability reservoir is closely related to its reservoir properties. Using the same development method on low-permeability reservoirs with different reservoir properties will yield significantly different oil recovery rates. The parameters characterizing the reservoir properties of a low-permeability reservoir are the factors that affect its development effect. Therefore, by obtaining actual parameters of factors affecting the development effect of the target low-permeability reservoir, such as the average throat radius, percentage of mobile fluid, formation pressure coefficient, hydrophilicity coefficient, porosity, starting pressure gradient, clay mineral content, crude oil viscosity, and reservoir depth, we can gain a clearer understanding of the target low-permeability reservoir. This will help in selecting a development method based on this information, leading to a more reasonable development method for the low-permeability reservoir.

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

[0066] In some embodiments, the factors influencing the development effect include a first type of influencing factor and a second type of influencing factor. The first type of influencing factor is positively correlated with reservoir permeability, and the second type of influencing factor is negatively correlated with reservoir permeability. In this case, the reservoir classification coefficient of the target low-permeability reservoir is determined based on the actual parameters of the factors influencing the development effect, including 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 of influencing factors.

[0068] As an example, the first category of influencing factors includes the average throat radius, percentage of mobile fluid, formation pressure coefficient, hydrophilicity coefficient, and porosity; in this case, the first classification coefficient is determined according to the following formula (1) based on the actual parameters, weighting coefficients, and calibration parameters of the first category of influencing factors.

[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 Let k represent the actual parameter of the i-th influencing factor. i c represents the weight coefficient of the i-th influencing factor. istd This 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 type of influencing factors.

[0072] As an example, the second category of influencing factors includes the starting pressure gradient, clay mineral content, crude oil viscosity, and reservoir depth; in this case, the second category coefficient is determined according to the following formula (2) based on the actual parameters, weight coefficients, and calibration parameters of the second category of influencing factors.

[0073]

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

[0075] The calibration parameters in steps (1) and (2) above can be the boundary value of the fifth category in the single-factor classification standard, the median value of the third category in the single-factor classification standard, or the left / right boundary value or median value of other categories. This application embodiment does not limit this.

[0076] The single-factor classification criteria are used to classify the magnitude of each development influencing factor in low-permeability reservoirs. The classification criteria for average throat radius, percentage of movable fluid, formation pressure coefficient, hydrophilicity coefficient, porosity, initiation pressure gradient, clay mineral content, crude oil viscosity, and reservoir depth are shown in Table 1 below.

[0077] Table 1

[0078] Factors affecting development effectiveness A type Category II Three categories Category Four Five categories Average throat radius (μm) ≥4.5 3.9-4.5 2-3.9 0.9-2 ≤0.9 Percentage of movable fluid (%) ≥65 50-65 40-50 25-40 ≤25 Initiate 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 weighting coefficients of the average throat radius, porosity, and initiation pressure gradient in steps (1) and (2) above are first-level weighting coefficients; the weighting coefficients of the percentage of movable fluid, hydrophilicity coefficient, and clay mineral content are second-level weighting coefficients; and the weighting coefficients of the formation pressure coefficient, crude oil viscosity, and reservoir depth are third-level weighting coefficients. The first-level weighting coefficient is greater than the second-level weighting coefficient, and the second-level weighting coefficient is greater than the third-level weighting coefficient. For example, the first-level weighting coefficient is 1.2, the second-level weighting coefficient is 1.0, and the third-level weighting coefficient is 0.8. In practical applications, the specific values ​​of the first-level, second-level, and third-level weighting coefficients can be adjusted according to the characteristics of the oil reservoir; this embodiment does not limit this.

[0080] Since the average throat radius determines the flow properties of low-permeability reservoirs, the initiation pressure gradient is a crucial parameter for reservoir permeability, and porosity significantly contributes to reservoir permeability, these three factors have the greatest impact on the development of low-permeability reservoirs. Therefore, their weighting coefficients are set to the highest, making them primary weighting coefficients. Similarly, since the percentage of movable fluid is an important parameter representing the characteristics of pore fluid occurrence, clay mineral content significantly affects permeability, and the hydrophilicity coefficient reflects wettability and also significantly impacts permeability, these three factors also have a significant impact on the development of low-permeability reservoirs. Therefore, their weighting coefficients are set to the highest, making them secondary weighting coefficients. Since reservoir depth, crude oil viscosity, and formation pressure coefficient are fundamental reservoir properties that influence reservoir permeability, these three factors affect the development of low-permeability reservoirs. However, their impact is relatively small compared to the other two factors. Therefore, the weighting coefficients for these three factors are set relatively small, i.e., they are three-level weighting coefficients. Of course, in practical applications, the weighting coefficients for each development effect influencing factor can be selected according to the characteristics of the reservoir. This application does not limit this selection.

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

[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 Let k represent the actual parameter of the i-th influencing factor. i c represents the weight coefficient of the i-th influencing factor. istd d 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 second-category influencing factors; d j J represents the actual parameter of the j-th influencing factor. j d represents the weight coefficient of the j-th influencing factor. jstd This represents the calibration parameter for the j-th influencing factor. The weighting coefficients and calibration parameters are determined as in the example above.

[0086] Step 103: Based on the reservoir classification coefficient of the target low-permeability reservoir, determine the development mode of the target low-permeability reservoir from the correspondence between the reservoir classification coefficient range and the development mode.

[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, the development mode of the target low-permeability reservoir is determined to be the fracture-network matching advanced 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.

[0088] The pressure threshold refers to the critical value of the formation pressure coefficient that ensures a high recovery rate for low-permeability reservoirs using the fracture-mesh matching simultaneous injection and production method, provided that the formation energy is sufficient. The pressure threshold can also be adjusted based on the reservoir properties of the target low-permeability reservoir; this application does not limit this adjustment.

[0089] Simultaneous water injection refers to the simultaneous injection and production of water injection wells and production wells. Pre-injection refers to water injection wells being injected before production wells are put into operation. By injecting water into production wells in low-permeability reservoirs where formation pressure is below the pressure threshold before production, the formation pressure can be increased. This ensures that the formation has sufficient energy to drive oil flow when subsequent production wells are put into operation, thereby achieving better recovery rates in low-permeability reservoirs.

[0090] In addition, by using fracture-mesh matching technology, the direction of the injection-production well network can be matched with that of the fractures, thus avoiding ineffective water injection and the occurrence of explosive water flooding problems.

[0091] In other embodiments, if the obtained development method includes gas drive and energy storage-based infiltration, it is necessary to determine whether the target low-permeability reservoir has a gas source. If the target low-permeability reservoir has a gas source, the development method of the target low-permeability reservoir is determined to be gas drive; otherwise, the development method of the target low-permeability reservoir is determined to be energy storage-based infiltration.

[0092] Since the viscosity of gas to oil is lower than that of water to oil, the development effect of gas-driven methods is better than that of water-driven energy storage and infiltration methods. Therefore, if the target low-permeability reservoir has a gas source, gas-driven methods are preferred for development.

[0093] The gases that can be used in gas-driven development mainly include carbon dioxide, natural gas, nitrogen, air, and flue gas. In practical applications, different gases can be selected based on the gas source conditions of each reservoir, and this application does not limit this. For example, if a low-permeability reservoir in an oilfield has a carbon dioxide gas source, and the development method of this low-permeability reservoir includes gas-driven development, then carbon dioxide can be used for gas-driven development, without the need to find other gases, thus avoiding excessive economic costs.

[0094] In addition, in actual development, on the basis of ensuring gas supply, we should try to achieve miscible flooding, so that the gas and crude oil form a uniform phase, and ensure that the capillary force of oil trapped in the pores is reduced or eliminated, so that the crude oil can be better driven to the oil well.

[0095] In other embodiments, the energy storage percolation method includes the energy storage displacement method and the energy storage huff and puff method; in this case, determining the development method of the target low-permeability reservoir as the energy storage percolation method 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 the development method of the target low-permeability reservoir is determined to be the energy storage displacement method; otherwise, the development method of the target low-permeability reservoir is determined to be the energy storage huff and puff method.

[0096] The throat radius threshold, gradient threshold, and porosity threshold are the critical values ​​for the average throat radius, initiation pressure gradient, and porosity required to successfully establish a displacement system, respectively. These three thresholds can be adjusted according to the reservoir properties of the target low-permeability reservoir in actual applications, and this application does not limit this adjustment.

[0097] Determining whether the actual parameters of the target low-permeability reservoir—average throat radius, initiation pressure gradient, and porosity—are all greater than their respective thresholds is essentially assessing the reservoir connectivity of the target low-permeability reservoir. If the actual parameters of the target low-permeability reservoir's average throat radius, initiation pressure gradient, and porosity are all greater than their respective thresholds, it indicates that the reservoir connectivity of the target low-permeability reservoir is good. If the actual parameters of the target low-permeability reservoir's average throat radius, initiation pressure gradient, and porosity are at least less than their respective thresholds, it indicates that the reservoir connectivity of the target low-permeability reservoir is poor.

[0098] Since energy storage displacement is more effective than energy storage huff and puff, but energy storage displacement requires good reservoir connectivity, when the development method for the target low-permeability reservoir is energy storage permeation, the energy storage displacement method can be selected for target low-permeability reservoirs with good reservoir connectivity to establish a displacement system, while the energy storage huff and puff method can be selected for target low-permeability reservoirs with poor reservoir connectivity to achieve local permeation replacement. In this way, the reservoir properties of the target low-permeability reservoir can be better utilized to improve the reservoir recovery rate.

[0099] In other embodiments, if the obtained development method includes gas drive, energy storage and infiltration, and volumetric fracturing asynchronous injection-production and infiltration oil recovery, it is necessary to determine whether the gas source of the target low-permeability reservoir is sufficient. If the gas source of the target low-permeability reservoir is sufficient, the development method of the target low-permeability reservoir is determined to be gas drive. 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 energy storage and infiltration or volumetric fracturing asynchronous injection-production and infiltration oil recovery.

[0100] In the volumetric fracturing asynchronous injection-production-permeation oil recovery method, the deployment of the injection-production well network must be matched with the anisotropy, natural microfracture characteristics, and artificial fracture characteristics of the target low-permeability reservoir. Furthermore, the direction of the water injection well row and the direction of the production well row should be kept as consistent as possible with the direction of the maximum principal stress of the formation. At the same time, the well network is selected as a rectangular five-point well network.

[0101] If the development method for the target low-permeability reservoir is determined to be either energy storage-injection or volumetric fracturing-asynchronous injection-injection production, then volumetric fracturing-asynchronous injection-injection production, being the most expensive but also the most effective, should be chosen if cost is not a concern. Otherwise, energy storage-injection production should be chosen. If energy storage-injection production is chosen, which includes energy storage displacement and energy storage huff-and-puff methods, then the reservoir connectivity of the target low-permeability reservoir must be assessed. Energy storage displacement should be chosen if connectivity is good, and energy storage huff-and-puff should be chosen if connectivity is poor. This approach allows for effective exploitation of the target low-permeability reservoir while considering economic benefits.

[0102] In other embodiments, if the obtained development method includes gas drive and volumetric fracturing asynchronous injection-production-sucking oil recovery, it is also necessary to determine whether the gas source of the target low-permeability reservoir is sufficient. If the gas source of the target low-permeability reservoir is sufficient, the development method of the target low-permeability reservoir is determined to be gas drive; 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 volumetric fracturing asynchronous injection-production-sucking oil recovery.

[0103] For example, suppose the correspondence between reservoir classification coefficient range and 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. Suppose 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. At this time, the development modes obtained include gas drive mode and energy storage and infiltration mode.

[0104] Table 2

[0105]

[0106] The correspondence between the above-mentioned reservoir classification coefficient range and development mode can be obtained by conducting field exploration, processing and analysis of multiple low-permeability reservoirs, or by other means. This application does not limit this.

[0107] In some embodiments, the correspondence between the reservoir classification coefficient range and the development method can be obtained as follows: Multiple core data corresponding to multiple low-permeability reservoirs are acquired, including permeability and actual parameters of factors influencing the development effect of low-permeability reservoirs; based on the actual parameters of factors influencing the development effect of low-permeability reservoirs in the core data, the reservoir classification coefficient of the first low-permeability reservoir is determined; the first low-permeability reservoir is any one of the multiple low-permeability reservoirs; after determining the reservoir classification coefficients of other low-permeability reservoirs in the same manner as described above, a fitting curve of permeability and reservoir classification coefficients for the multiple low-permeability reservoirs is generated; based on the fitting curve, the reservoir classification coefficients are divided into intervals, and the development method corresponding to each reservoir classification coefficient range is determined, thus obtaining the correspondence between the reservoir classification coefficient range and the development method of the low-permeability reservoir.

[0108] Among them, the reservoir classification coefficient of the first low-permeability reservoir can be determined by the actual parameters of the factors affecting the development effect of low-permeability reservoirs in the core data, which can be implemented in the relevant method in step 102 above, and will not be repeated here.

[0109] Since the reservoir classification coefficients obtained in this application embodiment are based on the factors affecting the development effect of low-permeability reservoirs, and these factors are positively or negatively correlated with the permeability of the reservoirs, there is a correlation between the reservoir classification coefficients obtained in this application embodiment and the permeability of the reservoirs. Thus, based on the fitting curve of the permeability of low-permeability reservoirs and the reservoir classification coefficients, when dividing the reservoir classification coefficients of low-permeability reservoirs into intervals, the permeability of the low-permeability reservoirs is taken into account. In fact, as described in step 102, the coarse-grained permeability of the target low-permeability reservoirs is finely divided by the reservoir classification coefficients.

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

[0111] Table 3

[0112]

[0113] Based on the permeability and corresponding reservoir classification coefficients of the 13 low-permeability reservoirs in Table 3, fitting curves for the permeability and reservoir classification coefficients of low-permeability reservoirs were obtained, as follows: Figure 4 As shown.

[0114] Through field development verification of these 13 low-permeability reservoirs, insights were gained regarding the development effectiveness of 52 development units within these reservoirs. Please refer to [reference needed]. Figure 2 , Figure 2 This demonstrates the relationship between the recovery rate and the permeability of 52 development units in 13 low-permeability reservoirs obtained through fracture-mesh matching water injection development. Figure 2 It is evident that development units with permeability above 10 mD generally achieve good or high recovery rates, while those with permeability below 10 mD achieve lower recovery rates, making conventional waterflooding development difficult and requiring other targeted energy replenishment methods. Please also refer to... Figure 3 , Figure 3 The relationship between the starting pressure gradient and permeability is shown. The curve shows an inflection point at 3mD. When the permeability is less than 3mD, the starting pressure gradient rises rapidly. This indicates that for low-permeability reservoirs with permeability less than 3mD, waterflooding development is more difficult and requires gasflooding or volumetric fracturing asynchronous injection-production-sucking oil recovery development methods.

[0115] Based on the above fitted curves and the understanding of the development effects of these 13 low-permeability reservoirs, the reservoir classification coefficients are divided into 5 intervals: F > 15.9, 15.3 < F ≤ 15.9, 14.0 < F ≤ 15.3, 13 < F ≤ 14, and F ≤ 13. Low-permeability reservoirs with classification coefficients in these 5 intervals can be respectively called low-permeability Class I (F > 15.9), low-permeability Class II (15.3 < F ≤ 15.9), low-permeability Class III (14.0 < F ≤ 15.3), low-permeability Class IV (13 < F ≤ 14), and low-permeability Class V (F ≤ 13) reservoirs. The development methods that can be selected for low-permeability reservoirs in each interval are determined, and the correspondence between the reservoir classification coefficient range and the development methods shown in Table 2 above can be obtained.

[0116] Below is an example of a practical application of the method provided in the embodiments of this application:

[0117] Suppose we want to develop a low-permeability reservoir in an oil field. First, we need to obtain the actual parameters of the factors affecting the development effect of the low-permeability reservoir, which are: average throat radius of 3.77 μm, percentage of movable fluid of 63.16%, formation pressure coefficient of 1.33, hydrophilicity coefficient of 0.76, porosity of 19.66%, starting pressure gradient of 0.08 MPa / m, clay mineral content of 7.7%, crude oil viscosity of 7.38 mPa·s, and reservoir depth of 2342.97 m.

[0118] Assuming the calibration parameters are selected from the fifth category of the single-factor classification standard, the weighting coefficients for average throat radius, porosity, and initiation pressure gradient are set to 1.2, the weighting coefficients for movable fluid percentage, hydrophilicity coefficient, and clay mineral content are set to 1.0, and the weighting coefficients for formation pressure coefficient, crude oil viscosity, and reservoir depth are set to 0.8.

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

[0120]

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

[0122]

[0123] Therefore, the reservoir classification coefficient for this low-permeability reservoir is obtained as follows:

[0124] F = F1 + F2 = 15.6581.

[0125] Assuming the development method is determined using the correspondence between reservoir classification coefficient range and development method as shown in example 103, the classification coefficient of this low-permeability reservoir falls within the range of 15.3 < F ≤ 15.9, indicating it is a Class II low-permeability reservoir. Therefore, the development method for this low-permeability reservoir is selected from either the fracture-network matching synchronous water injection method or the fracture-network matching advanced water injection method. At this point, it is necessary to compare its bottom pressure coefficient with the pressure threshold. Assuming the pressure threshold is 1.1, and given that the formation pressure coefficient of this low-permeability reservoir is 1.33, the formation pressure coefficient is greater than the pressure threshold. Therefore, the development method for this low-permeability reservoir is determined to be the fracture-network matching synchronous water injection development method.

[0126] In this embodiment, by comprehensively considering a series of factors that affect the development effect of low-permeability reservoirs, the reservoir classification coefficient and corresponding development method of the target low-permeability reservoir are determined. When the development method is optional, the development method is further determined by judging the relevant reservoir properties of the target low-permeability reservoir. Compared with the previous method of determining the development method solely through permeability, this method is more reasonable and meets the actual application requirements. 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.

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

[0128] The acquisition module 501 is used to acquire actual parameters of the factors affecting the development effect of the target low-permeability reservoir. These factors include average throat radius, percentage of movable fluid, formation pressure coefficient, hydrophilicity coefficient, porosity, starting pressure gradient, clay mineral content, crude oil viscosity, and reservoir depth.

[0129] The first determining module 502 is used to determine the reservoir classification coefficient of the target low-permeability reservoir based on the actual parameters of the factors affecting the development effect. The reservoir classification coefficient is used to finely classify the coarse-grained permeability of the target low-permeability reservoir.

[0130] The second determining module 503 is used to determine the development mode of the target low-permeability reservoir based on the reservoir classification coefficient and the correspondence between the reservoir classification coefficient range and the development mode.

[0131] Optionally, the factors influencing the development effect include a first type of influencing factor and a second type of influencing factor. The first type of influencing factor is positively correlated with reservoir permeability, and the second type of influencing factor is negatively correlated with reservoir permeability. The first determining module includes:

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

[0133] The second coefficient determination submodule is used to determine the second classification coefficient based on the 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 and second classification coefficients.

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

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

[0137]

[0138] Where F1 represents the first classification coefficient, i represents the i-th influencing factor in the first category, m represents the number of influencing factors in the first category, and c i Let k represent the actual parameter of the i-th influencing factor. i c represents the weight coefficient of the i-th influencing factor. istd This represents the calibration parameter of the i-th influencing factor.

[0139] Optionally, the second category of influencing factors includes the 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, weighting coefficients, and calibration parameters of the second category of influencing factors, the second category coefficient is determined according to the following formula;

[0141]

[0142] Where F2 represents the second category coefficient, j represents the j-th influencing factor in the second category, n represents the number of influencing factors in the second category, and d j J represents the actual parameter of the j-th influencing factor. j d represents the weight coefficient of the j-th influencing factor. jstd This represents the calibration parameter of the j-th influencing factor.

[0143] Optionally, the weighting coefficients for average throat radius, porosity, and initiation pressure gradient are first-level weighting coefficients; the weighting coefficients for percentage of mobile fluid, hydrophilicity coefficient, and clay mineral content are second-level weighting coefficients; and the weighting coefficients for formation pressure coefficient, crude oil viscosity, and reservoir depth are third-level weighting 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 used for:

[0146] From the correspondence between reservoir classification coefficient range and development mode, obtain the development mode corresponding to the reservoir classification coefficient of the target low-permeability reservoir;

[0147] If the obtained development methods include the fracture-mesh matching synchronous water injection method and the fracture-mesh matching advanced water injection method, then determine 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 method for the target low-permeability reservoir is determined to be the fracture-network matching pre-injection method; otherwise, the development method for the target low-permeability reservoir is determined to be the fracture-network matching synchronous injection method.

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

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

[0151] If the target low-permeability reservoir has a gas source, the development method for the target low-permeability reservoir is determined to be gas drive; otherwise, the development method for the target low-permeability reservoir is determined to be energy storage and infiltration.

[0152] Optionally, the energy storage infiltration method includes energy storage displacement and energy storage throughput; the second determining module is also 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 porosity is greater than the porosity threshold, then the development mode of the target low-permeability reservoir is determined to be energy storage displacement mode; otherwise, the development mode of the target low-permeability reservoir is determined to be energy storage huff and puff mode.

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

[0155] If the development methods obtained include gas drive, energy storage and infiltration, and volumetric fracturing asynchronous injection and production infiltration, then determine whether the gas source of the target low-permeability reservoir is sufficient.

[0156] If the target low-permeability reservoir has sufficient gas supply, then the development method for the target low-permeability reservoir is determined to be gas drive.

[0157] If the gas source for the target low-permeability reservoir is insufficient, the development method for the target low-permeability reservoir will be determined as either energy storage and infiltration or volumetric fracturing asynchronous injection and production infiltration.

[0158] In this embodiment, by comprehensively considering a series of factors that affect the development effect of low-permeability reservoirs, the reservoir classification coefficient and corresponding development method of the target low-permeability reservoir are determined. When the development method is optional, the development method is further determined by judging the relevant reservoir properties of the target low-permeability reservoir. This can quickly and accurately determine the development method of the target low-permeability reservoir in practical applications, avoiding economic losses and low recovery rates caused by unreasonable selection of development methods during reservoir development.

[0159] It should be noted that the low-permeability reservoir development method determination device provided in the above embodiments is only illustrated by the division of the above functional modules when determining the development method of the reservoir. In practical applications, the above functions can be assigned to different functional modules as needed, that is, the internal structure of the device can be divided into different functional modules to complete all or part of the functions described above. In addition, the low-permeability reservoir development method determination device and the low-permeability reservoir development method determination method embodiments provided in the above embodiments belong to the same concept, and the specific implementation process is detailed in the method embodiments, which will not be repeated here.

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

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

[0162] Processor 601 may include one or more processing cores, such as a quad-core processor, an octa-core processor, etc. Processor 601 may be implemented using at least one hardware form selected from DSP (Digital Signal Processing), FPGA (Field Programmable Gate Array), and PLA (Programmable Logic Array). Processor 601 may also include a main processor and a coprocessor. The main processor, also known as a CPU (Central Processing Unit), is used to process data in the wake-up state; the coprocessor is a low-power processor used to process data in the standby state. In some embodiments, processor 601 may integrate a GPU (Graphics Processing Unit), which is responsible for rendering and drawing the content to be displayed on the screen. In some embodiments, processor 601 may also include an AI (Artificial Intelligence) processor, which is used to handle computational 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 high-speed random access memory and non-volatile memory, such as one or more disk storage devices or flash memory devices. In some embodiments, the non-transitory computer-readable storage media in the memory 602 is used to store at least one instruction, which is executed by the processor 601 to implement the method for determining the development mode of low-permeability reservoirs provided in the method embodiments of this application.

[0164] In some embodiments, the terminal 600 may also optionally include a peripheral device interface 603 and at least one peripheral device. The processor 601, memory 602, and peripheral device interface 603 can be connected via a bus or signal line. Each peripheral device can be connected to the peripheral device interface 603 via a bus, signal line, or circuit board. Specifically, the peripheral device includes at least one of the following: 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] Peripheral interface 603 can be used to connect at least one I / O (Input / Output) related peripheral device to processor 601 and memory 602. In some embodiments, processor 601, memory 602 and peripheral interface 603 are integrated on the same chip or circuit board; in some other embodiments, any one or two of processor 601, memory 602 and peripheral interface 603 can be implemented on separate chips or circuit boards, which is not limited in this embodiment.

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

[0167] Display screen 605 is used to display a UI (User Interface). This UI may include graphics, text, icons, videos, and any combination thereof. When display screen 605 is a touch display screen, it also has the ability to collect touch signals on or above its surface. These touch signals can be input as control signals to processor 601 for processing. In this case, display screen 605 can also be used to provide virtual buttons and / or a virtual keyboard, also known as soft buttons and / or a soft keyboard. In some embodiments, there may be one display screen 605, which serves as the front panel of terminal 600; in other embodiments, there may be at least two display screens, respectively disposed on different surfaces of terminal 600 or in a folded design; in still other embodiments, display screen 605 may be a flexible display screen, disposed on a curved or folded surface of terminal 600. Furthermore, display screen 605 may be configured as a non-rectangular, irregular shape, i.e., a non-rectangular screen. Display screen 605 may be made of materials such as LCD (Liquid Crystal Display) or OLED (Organic Light-Emitting Diode).

[0168] The camera assembly 606 is used to acquire images or videos. Optionally, the camera assembly 606 includes a front-facing camera and a rear-facing camera. Typically, the front-facing camera is located on the front panel of the terminal, and the rear-facing camera is located on the back of the terminal. In some embodiments, there are at least two rear-facing cameras, which are any one of a main camera, a depth-sensing camera, a wide-angle camera, and a telephoto camera, to achieve background blurring by fusion of the main camera and the depth-sensing camera, panoramic shooting by fusion of the main camera and the wide-angle camera, VR (Virtual Reality) shooting, or other fusion shooting functions. In some embodiments, the camera assembly 606 may also include a flash. The flash can be a single-color temperature flash or a dual-color temperature flash. A dual-color temperature flash refers to a combination of a warm light flash and a cool light flash, which can be used for light compensation at different color temperatures.

[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, converting the sound waves into electrical signals that are input to the processor 601 for processing, or input to the radio frequency circuit 604 for voice communication. For stereo sound acquisition or noise reduction purposes, multiple microphones may be used, each located at a different part of the terminal 600. The microphone may also be an array microphone or an omnidirectional microphone. The speaker is used to convert the electrical signals from the processor 601 or the radio frequency circuit 604 into sound waves. The speaker may be a conventional diaphragm speaker or a piezoelectric ceramic speaker. When the speaker is a piezoelectric ceramic speaker, it can convert electrical signals not only into audible sound waves but also into inaudible sound waves for purposes such as distance measurement. In some embodiments, the audio circuit 607 may also include a headphone jack.

[0170] The positioning component 608 is used to determine the current geographic location of the terminal 600 in order to enable navigation or LBS (Location Based Service). The positioning component 608 can be a positioning component of GPS (Global Positioning System), BeiDou system, or Galileo system.

[0171] Power supply 609 is used to supply power to the various components in terminal 600. Power supply 609 can be AC ​​power, DC power, a disposable battery, or a rechargeable battery. When 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 that is charged via a wired line, and a wireless rechargeable battery is a battery that is charged via 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. The one or more sensors 610 include, but are not limited to: an accelerometer 611, a gyroscope 612, a pressure sensor 613, a fingerprint sensor 614, an optical sensor 615, and a proximity sensor 616.

[0173] Accelerometer 611 can detect the magnitude of acceleration along the three axes of a coordinate system established by terminal 600. For example, accelerometer 611 can be used to detect the components of gravitational acceleration along the three axes. Processor 601 can control touchscreen 605 to display the user interface in landscape or portrait view based on the gravitational acceleration signal acquired by accelerometer 611. Accelerometer 611 can also be used for games or for acquiring user motion data.

[0174] The gyroscope sensor 612 can detect the orientation and rotation angle of the terminal 600. The gyroscope sensor 612, in conjunction with the accelerometer sensor 611, can collect 3D motion data from the user on the terminal 600. Based on the data collected by the gyroscope sensor 612, the processor 601 can perform the following functions: motion sensing (e.g., changing the UI based on the user's tilt), image stabilization during shooting, game control, and inertial navigation.

[0175] The pressure sensor 613 can be disposed on the side bezel of the terminal 600 and / or on the lower layer of the touch display screen 605. When the pressure sensor 613 is disposed on the side bezel of the terminal 600, it can detect the user's grip signal on the terminal 600, and the processor 601 can perform left / right hand recognition or quick operation based on the grip signal collected by the pressure sensor 613. When the pressure sensor 613 is disposed on the lower layer of the touch display screen 605, the processor 601 can control the operable controls on the UI interface based on the user's pressure operation on the touch display screen 605. The operable controls include at least one of button controls, scroll bar controls, icon controls, and menu controls.

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

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

[0178] The proximity sensor 616, also known as a distance sensor, is typically located on the front panel of the terminal 600. The proximity sensor 616 is used to detect 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 touchscreen display 605 to switch from a screen-on state to a 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 touchscreen display 605 to switch from a screen-off state to a screen-on state.

[0179] Those skilled in the art will understand that Figure 6 The structure shown does not constitute a limitation on terminal 600, and may include more or fewer components than shown, or combine certain components, or use different component arrangements.

[0180] In some embodiments, a computer-readable storage medium is also provided, which stores a computer program that, when executed by a processor, implements the steps of the method for determining the development mode of low-permeability reservoirs described in the above embodiments. For example, the computer-readable storage medium may be a ROM, RAM, CD-ROM, magnetic tape, floppy disk, or optical data storage device.

[0181] It is worth noting that the computer-readable storage medium mentioned in the embodiments of this application can be a non-volatile storage medium, in other words, it can be a non-transient storage medium.

[0182] It should be understood that all or part of the steps of the above embodiments can be implemented by software, hardware, firmware, or any combination thereof. When implemented in software, it can be implemented wholly or partially 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-described computer-readable storage medium.

[0183] That is, in some embodiments, a computer program product containing instructions is also provided, which, when run on a computer, causes the computer to perform the steps of the method for determining the development mode of a low-permeability reservoir as described above.

[0184] It should be understood that "at least one" as mentioned herein refers to one or more, and "multiple" refers to two or more. In the description of the embodiments of this application, unless otherwise stated, " / " means "or," for example, A / B can mean A or B; "and / or" in this document is merely a description of the relationship between related objects, indicating that three relationships can exist. For example, A and / or B can represent: A existing alone, A and B existing simultaneously, and B existing alone. In addition, in order to clearly describe the technical solutions of the embodiments of this application, the terms "first," "second," etc., are used in the embodiments of this application to distinguish identical or similar items with substantially the same function and effect. Those skilled in the art will understand that the terms "first," "second," etc., do not limit the quantity or execution order, and the terms "first," "second," etc., are not 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, data stored, data displayed, etc.) and signals involved in the embodiments of this application are all authorized by the user or fully authorized by all parties, and the collection, use and processing of related data must comply with the relevant laws, regulations and standards of the relevant countries and regions.

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

Claims

1. A method for determining the development mode of a low-permeability reservoir, characterized in that, The method includes: The actual parameters of the factors affecting the development effect of the target low-permeability reservoir are obtained. These factors include average throat radius, percentage of movable fluid, formation pressure coefficient, hydrophilicity coefficient, porosity, starting pressure gradient, clay mineral content, crude oil viscosity, and reservoir depth. Based on the actual parameters of the factors affecting the development effect, the reservoir classification coefficient of the target low-permeability reservoir is determined. The reservoir classification coefficient is used to finely classify the permeability of the target low-permeability reservoir at the coarse-grained level. Different reservoir classification coefficient ranges correspond to low-permeability reservoir categories and permeability ranges. Based on the reservoir classification coefficient of the target low-permeability reservoir, the development mode of the target low-permeability reservoir is determined from the correspondence between the reservoir classification coefficient range and the development mode. The factors affecting the development effect include a first category of factors and a second category of factors. The first category of factors is positively correlated with reservoir permeability, and the second category of factors is negatively correlated with reservoir permeability. The reservoir classification coefficient of the target low-permeability reservoir is determined based on the actual parameters of the factors influencing the development effect, including: The first classification coefficient is determined based on the actual parameters, weight coefficients, and calibration parameters of the first type of influencing factors. The second classification coefficient is determined 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; The first category of influencing factors includes the average throat radius, the percentage of movable fluid, the formation pressure coefficient, the hydrophilicity coefficient, and the porosity; determining the first classification coefficient based on the actual parameters of the first category of influencing factors includes: 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; Among them, the Represents the first classification coefficient, the This represents the i-th influencing factor in the first category of influencing factors. This indicates the number of the first type of influencing factors, the This represents the actual parameter of the i-th influencing factor. This represents the weight coefficient of the i-th influencing factor. The calibration parameter represents the i-th influencing factor; The second category of influencing factors includes the starting pressure gradient, the clay mineral content, the crude oil viscosity, and the reservoir depth; determining the second classification coefficient based on the actual parameters of the second category of influencing factors includes: Based on the actual parameters, weighting coefficients, and calibration parameters of the second category of influencing factors, the second classification coefficient is determined according to the following formula; Among them, the Represents the second classification coefficient, the This represents the j-th influencing factor in the second category of influencing factors. This indicates the number of the second type of influencing factors, the This represents the actual parameter of the j-th influencing factor. This represents the weight coefficient of the j-th influencing factor. The calibration parameter represents the j-th influencing factor; The process of determining the reservoir classification coefficient based on the first classification coefficient and the second classification coefficient includes: Add the first classification coefficient to the second classification coefficient to obtain the reservoir classification coefficient; or, Based on the actual parameters of the first type of influencing factors, the actual parameters of the second type of influencing factors, the weight coefficients and calibration parameters of each influencing factor, the reservoir classification coefficients are determined according to the following formula (3); （3） in, Indicates the reservoir classification coefficient. This represents the i-th influencing factor in the first category of influencing factors. This indicates the number of the first type of influencing factors. This represents the actual parameter of the i-th influencing factor. This represents the weight coefficient of the i-th influencing factor. This represents the calibration parameter of the i-th influencing factor; This represents the j-th influencing factor in the second category of influencing factors. This indicates the number of the second type of influencing factors. This represents the actual parameter of the j-th influencing factor. This represents the weight coefficient of the j-th influencing factor. This represents the calibration parameter of the j-th influencing factor.

2. The method as described in claim 1, characterized in that, The weighting coefficients for the average throat radius, porosity, and initiation pressure gradient are first-level weighting coefficients; the weighting coefficients for the percentage of movable fluid, hydrophilicity coefficient, and clay mineral content are second-level weighting coefficients; and the weighting coefficients for the formation pressure coefficient, crude oil viscosity, and reservoir burial depth are third-level weighting coefficients. Wherein, 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.

3. The method as described in claim 1, characterized in that, The determination of the development mode for the target low-permeability reservoir based on the reservoir classification coefficient and the correspondence between the reservoir classification coefficient range and the development mode includes: From the correspondence between the reservoir classification coefficient range and the development method, the development method corresponding to the reservoir classification coefficient of the target low-permeability reservoir is obtained; If the obtained development methods include the fracture-mesh matching synchronous water injection method and the fracture-mesh matching advanced water injection method, then determine whether the formation pressure coefficient is lower than the pressure threshold. If the formation pressure coefficient is lower than the pressure threshold, the development method for the target low-permeability reservoir is determined to be the fracture-network matched advance water injection method; otherwise, the development method for the target low-permeability reservoir is determined to be the fracture-network matched synchronous water injection method.

4. The method as described in claim 3, characterized in that, The method further includes: If the obtained development methods include gas drive and energy storage and infiltration, then determine whether the target low-permeability reservoir has a gas source; If the target low-permeability reservoir has a gas source, then the development method of the target low-permeability reservoir is determined to be the gas drive method; otherwise, the development method of the target low-permeability reservoir is determined to be the energy storage and infiltration method.

5. The method as described in claim 4, characterized in that, The energy storage and permeation methods include energy storage displacement and energy storage huff and puff methods; the development method for determining the target low-permeability reservoir as the energy storage and permeation method 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 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 huff and puff mode.

6. The method as described in claim 3, characterized in that, The method further includes: If the obtained development methods include gas drive, energy storage and infiltration, and volumetric fracturing asynchronous injection and production infiltration, then determine whether the gas source of the target low-permeability reservoir is sufficient. If the gas source of the target low-permeability reservoir is sufficient, then the development method of the target low-permeability reservoir is determined to be the gas drive method; 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 either the energy storage and infiltration method or the volumetric fracturing asynchronous injection-production infiltration method.

7. An apparatus for determining the development mode of a low-permeability oil reservoir, characterized in that, The device includes: The acquisition module is used to acquire actual parameters of the factors affecting the development effect of the target low-permeability reservoir. These factors include average throat radius, percentage of movable fluid, formation pressure coefficient, hydrophilicity coefficient, porosity, starting pressure gradient, clay mineral content, crude oil viscosity, and reservoir depth. The first determining module is used to determine the reservoir classification coefficient of the target low-permeability reservoir based on the actual parameters of the factors affecting the development effect. The reservoir classification coefficient is used to finely classify the permeability of the target low-permeability reservoir at the coarse-grained level. Different reservoir classification coefficient ranges correspond to low-permeability reservoir categories and permeability ranges. The second determining module is used to determine the development mode of the target low-permeability reservoir based on the reservoir classification coefficient and the correspondence between the reservoir classification coefficient range and the development mode. The factors affecting the development effect include a first category of factors and a second category of factors. The first category of factors is positively correlated with reservoir permeability, and the second category of factors is negatively correlated with reservoir permeability. The first determining module is used for: The first classification coefficient is determined based on the actual parameters, weight coefficients, and calibration parameters of the first type of influencing factors. The second classification coefficient is determined 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; The first category of influencing factors includes the average throat radius, the percentage of movable fluid, the formation pressure coefficient, the hydrophilicity coefficient, and the porosity; the first determining module is used for: 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; Among them, the Represents the first classification coefficient, the This represents the i-th influencing factor in the first category of influencing factors. This indicates the number of the first type of influencing factors, the This represents the actual parameter of the i-th influencing factor. This represents the weight coefficient of the i-th influencing factor. The calibration parameter represents the i-th influencing factor; The second category of influencing factors includes the starting pressure gradient, the clay mineral content, the crude oil viscosity, and the reservoir depth; the first determining module is used for: Based on the actual parameters, weighting coefficients, and calibration parameters of the second category of influencing factors, the second classification coefficient is determined according to the following formula; Among them, the Represents the second classification coefficient, the This represents the j-th influencing factor in the second category of influencing factors. This indicates the number of the second type of influencing factors, the This represents the actual parameter of the j-th influencing factor. This represents the weight coefficient of the j-th influencing factor. The calibration parameter represents the j-th influencing factor; The first determining module is used for: Add the first classification coefficient to the second classification coefficient to obtain the reservoir classification coefficient; or, Based on the actual parameters of the first type of influencing factors, the actual parameters of the second type of influencing factors, the weight coefficients and calibration parameters of each influencing factor, the reservoir classification coefficients are determined according to the following formula (3); （3） in, Indicates the reservoir classification coefficient. This represents the i-th influencing factor in the first category of influencing factors. This indicates the number of the first type of influencing factors. This represents the actual parameter of the i-th influencing factor. This represents the weight coefficient of the i-th influencing factor. This represents the calibration parameter of the i-th influencing factor; This represents the j-th influencing factor in the second category of influencing factors. This indicates the number of the second type of influencing factors. This represents the actual parameter of the j-th influencing factor. This represents the weight coefficient of the j-th influencing factor. This represents the calibration parameter of the j-th influencing factor.

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