Method, system and equipment for calculating dynamic reserves of fracture-vuggy carbonate reservoir

Abstract

The invention provides a method, a system and equipment for calculating the dynamic reserves of a fracture-vug type carbonate reservoir. The method comprises the following steps: calculating crude oil calculation parameters based on reservoir fluid property data; screening the obtained oil well production data in the flowing period based on the obtained bubble point pressure to obtain historical cumulative pressure drop and historical cumulative oil production, and constructing and obtaining dynamic reserve characteristics based on the historical cumulative pressure drop data and the historical cumulative oil production data; the method comprises the following steps: fitting current cumulative oil pressure drop data and current cumulative oil production data in a well opening production process after obtaining well round water injection to obtain a current production curve, and fitting based on the current production curve to obtain an elastic yield; according to the method, the dynamic reserves of the holes, the fractures and the holes are calculated based on the dynamic reserve characteristics reflected in the flowing period and the water injection oil replacement stage, the change of the reservoir characteristics can be dynamically reflected, then the dynamic reserves of the holes, the fractures and the holes are accurately calculated, and the development and economic benefits of oil and gas reservoirs are improved.

Description

Technical Field

[0001] This invention belongs to the field of oil and gas reservoir development technology, specifically to the method, system and equipment for calculating dynamic reserves of fractured-vuggy carbonate reservoirs. Background Technology

[0002] Fractured-vuggy carbonate reservoirs are highly heterogeneous, with reservoir spaces mainly consisting of three types: pores, fractures, and cavities. This results in a distinct separation of fluid distribution within the reservoir, complex and variable fluid flow characteristics, and numerous uncertainties regarding reservoir space, fluid distribution, and oil-water interface. Pores and cavities have strong storage capacity and are the main oil-bearing spaces, while fractures act as connections between multiple reservoirs, possessing storage and permeability capabilities and serving as important fluid seepage channels. Consequently, the dynamic reserves of the reservoir are unclear, posing significant challenges to their calculation.

[0003] Currently, the calculation of dynamic reserves in fractured-vuggy carbonate reservoirs is mainly based on the material balance theory. This method uses the divided fractured-vuggy units as a basis to establish the control area of ​​a single well based on the recoverable reserves of that well, and then uses the volumetric method to calculate the dynamic reserves of that well. Although this method can calculate the dynamic reserves in a single well, it cannot accurately reflect the increasing drilling depth. As the control area of ​​a single well based on the recoverable reserves of that well gradually increases, the error in the dynamic energy storage data calculated by the volumetric method becomes large. This leads to development plans that do not conform to reality, affecting the development efficiency and economic benefits of oil and gas reservoirs. Summary of the Invention

[0004] To address the problem that existing methods for calculating the dynamic reserves of fractured-vuggy carbonate reservoirs suffer from increasingly larger errors in dynamic energy storage data as the depth of oil and gas reservoir development increases, leading to low development efficiency and high economic costs, this invention provides a method, system, and equipment for calculating the dynamic reserves of fractured-vuggy carbonate reservoirs.

[0005] To achieve the above objectives, the present invention provides the following technical solution: This invention proposes a method for calculating the dynamic reserves of fractured-vuggy carbonate reservoirs, comprising the following steps: Crude oil calculation parameters were obtained based on reservoir fluid property data; Based on the obtained bubble point pressure, the production data of the self-flowing oil wells were screened to obtain historical cumulative pressure drop and historical cumulative oil production. Based on the historical cumulative pressure drop data and historical cumulative oil production data, a feature type library was constructed. Based on the current cumulative oil pressure drop data and current cumulative oil production data obtained after the well is injected with water in each cycle, the current production curve is obtained by fitting the current production curve, and the elastic yield is obtained by fitting the current production curve. Based on the comparison between the feature type library and the current production curve, the dynamic reserve characteristics exhibited by the current production curve are determined. Based on the elastic yield, the crude oil calculation parameters, and the dynamic reserve characteristics reflected in the self-flowing period and the water injection oil replacement stage, the dynamic reserves of pores, fractures, and cavities are calculated respectively.

[0006] Preferably, the crude oil calculation parameters are obtained based on reservoir fluid property data, including: Obtain the saturated oil compressibility coefficient and crude oil volume coefficient from the reservoir fluid properties report of the well being drilled or adjacent wells; The crude oil compressibility coefficient calculation formula is obtained by fitting the saturated oil compressibility coefficient, and the crude oil compressibility coefficient is calculated by using the crude oil compressibility coefficient calculation formula based on the obtained current formation pressure value. The crude oil volume factor calculation formula is obtained based on the crude oil volume factor fitting. The crude oil volume factor under formation pressure is then calculated using the crude oil volume factor calculation formula based on the obtained current formation pressure value.

[0007] Preferably, the formula for calculating the compressibility coefficient of crude oil is obtained by fitting the compressibility coefficient of saturated oil, including: Using the saturated oil compressibility coefficient as the ordinate and the midpoint of the formation pressure range corresponding to the saturated oil compressibility coefficient as the ordinate, the first coordinate point data is obtained by fitting. The data of the first coordinate point are fitted in a rectangular coordinate system to form a saturated oil compressibility curve; Calculate the fitting coefficient of each of the saturated oil compressibility coefficient curves, select the saturated oil compressibility coefficient curve with the fitting coefficient close to 1 as the crude oil compressibility coefficient fitting curve, and obtain the crude oil compressibility coefficient calculation formula by fitting.

[0008] Preferably, the crude oil volume coefficient calculation formula is obtained based on the crude oil volume coefficient fitting, including: using the crude oil volume coefficient as the vertical axis and the midpoint value of the formation pressure range corresponding to the crude oil volume coefficient as the vertical axis, fitting the second coordinate point data; The data of the second coordinate point are fitted in a rectangular coordinate system to form a crude oil volume factor curve. The linear correlation is then taken to obtain the crude oil volume factor calculation formula.

[0009] Preferably, based on the production data of the self-flowing oil wells obtained through the bubble point pressure screening, the historical cumulative pressure drop and historical cumulative oil production are obtained, including: Obtain production data of oil wells during the self-flowing period, compare the oil pressure and bubble point pressure in the production data of oil wells during the self-flowing period, retain the cumulative pressure drop and cumulative oil production corresponding to the oil pressure being greater than the bubble point pressure, and obtain the historical cumulative pressure drop and historical cumulative oil production.

[0010] Preferably, the feature type library constructed based on historical cumulative pressure drop data and historical cumulative oil production data includes: The historical self-flowing period characteristic curve was obtained by fitting the historical cumulative pressure drop data and the historical cumulative oil production data. Determine the linear relationship of the historical self-spraying period characteristic curves; If the historical spontaneous flow period characteristic curves show a linear relationship, then it belongs to the collective spontaneous flow period characteristics of cave + pore type reservoirs. If the historical self-flowing period characteristic curve is not linear, it means that the reservoir has liquid supply characteristics at the far end, which belongs to the characteristics of cave + pore + fracture type reservoir. The feature type library is obtained by combining the collective characteristics of cave + pore + fracture type reservoirs and the self-flowing period characteristics of cave + pore type reservoirs.

[0011] Preferably, the calculation process for obtaining the dynamic reserves of each reservoir type within the reservoir collective type based on the elastic yield and the crude oil calculation parameters is as follows: ; in, The current cumulative oil production m 3 ; This is the crude oil volume factor under formation pressure; For dynamic reserves; The volume factor under the original pressure; The overall compressibility coefficient is 1 / MPa; where, Total pressure drop (MPa) , =Original formation pressure - Current formation pressure.

[0012] Preferably, after water injection into the oil well, the calculation process for obtaining the dynamic reserves of each reservoir type within the reservoir collective type based on the elastic yield and the crude oil calculation parameters is as follows: ; in, Cumulative oil production on the surface (m) 3 ; This is the crude oil volume factor under formation pressure; Dynamic reserves; The volume factor under the original pressure; The overall compressibility factor is 1 / MPa; Total pressure drop (MPa); The compressibility coefficient of water + rock is 1 / MPa; The volume coefficient of water under the original pressure; For the volume of water to be sealed (m) 3 ; For the cumulative water production at ground level; The volume coefficient of water. , =Original formation pressure - Current formation pressure; Overall compressibility The calculation process is as follows: ; In the formula, This is the overall compression coefficient; The compression coefficient of crude oil; The water compressibility coefficient; To bind water saturation; This represents the original oil saturation. is the rock compressibility coefficient.

[0013] This invention proposes a dynamic reserve calculation system for fractured-vuggy carbonate reservoirs, based on the aforementioned dynamic reserve calculation method for fractured-vuggy carbonate reservoirs, including: The first processing unit is used to calculate crude oil calculation parameters based on reservoir fluid property data; The feature processing unit is used to filter the production data of the self-flowing oil well based on the obtained bubble point pressure, obtain the historical cumulative pressure drop and historical cumulative oil production, and construct a feature type library based on the historical cumulative pressure drop data and historical cumulative oil production data. The second processing unit is used to fit the current cumulative oil pressure drop data and current cumulative oil production data during the well opening production process after water injection in the well cycle to obtain the current production curve, and to fit the elastic yield based on the current production curve. The type determination unit is used to determine the dynamic reserve characteristics of the current production curve based on the comparison between the feature type library and the current production curve. The third processing unit is used to calculate the dynamic reserves of holes, fractures, and cavities based on the elastic yield, the crude oil calculation parameters, and the dynamic reserve characteristics reflected in the self-flowing period and the water injection oil replacement stage.

[0014] The output unit is used to output the calculated dynamic reserves of holes, fissures, and cavities.

[0015] The present invention proposes a computer device, including a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, it implements the steps of the above-described method for calculating the dynamic reserves of fractured-vuggy carbonate reservoirs.

[0016] Compared with the prior art, the present invention has the following beneficial technical effects: This invention proposes a dynamic reserve calculation method for fractured-vuggy carbonate reservoirs. This method, based on detailed reservoir fluid property data, accurately calculates crude oil calculation parameters, ensuring the accuracy of the source data for reserve estimation and improving the overall reliability of the calculation. By screening production data from wells during the flow period and constructing a feature type library, it effectively summarizes and generalizes the historical production characteristics of the reservoir. During the production process after water injection in each well cycle, the current cumulative oil pressure drop data and cumulative oil production data are used to fit the current production curve, and the elastic yield is obtained through fitting. This dynamically captures the changes in reservoir characteristics during the production process. By comparing with the feature type library, the dynamic reserve characteristics exhibited by the current production curve can be quickly determined, thus achieving rapid identification of reservoir characteristics. Based on the elastic yield and crude oil calculation parameters, the dynamic reserves of pores, fractures, and vuggy reservoirs are calculated, reflecting the current reserve status of the reservoir and predicting future reserve change trends. By integrating reservoir fluid property data and well production data, this invention constructs a systematic calculation process that can dynamically reflect changes in reservoir characteristics and accurately calculate the dynamic reserves of pores, fractures, and vuggy reservoirs. Furthermore, this method obtains the saturated oil compressibility coefficient and crude oil volume factor from reservoir fluid property reports of drilled wells or adjacent wells, ensuring the reliability and representativeness of the data source. Based on these fundamental data, calculation formulas for the crude oil compressibility coefficient and crude oil volume factor are fitted respectively, fully considering the influence of formation pressure changes on the physical properties of crude oil. Using the fitted calculation formulas, combined with the current formation pressure value, the crude oil compressibility coefficient and crude oil volume factor under formation pressure can be accurately calculated. These two parameters are directly related to the storage state and recoverability of crude oil in the formation, improving the accuracy of crude oil calculation parameters and enhancing the sensitivity of the calculation method to formation pressure changes. As a result, this method can provide more accurate reserve estimation results under different formation pressure conditions, thereby helping to formulate more reasonable development strategies and optimize production plans.

[0017] Furthermore, this method compares oil pressure with bubble point pressure, retaining only production data where oil pressure is greater than bubble point pressure. This effectively eliminates errors that may be introduced by production stages below bubble point pressure, ensuring the accuracy and representativeness of historical cumulative pressure drop and historical cumulative oil production data. Historical self-flowing period characteristic curves are obtained by fitting historical cumulative pressure drop and historical cumulative oil production data. By judging the linear relationship of the characteristic curves, effective identification of reservoir types is achieved. When the characteristic curves show a linear relationship, it indicates that the reservoir is mainly of the cave + pore type. When the characteristic curves are non-linear, it represents that there are fluid supply characteristics at the far end of the dynamic reserve characteristics, belonging to the cave + pore + fracture type reservoir. This improves the accuracy of reservoir type identification. By combining different types of self-flowing period characteristics, a comprehensive characteristic type library is constructed, providing strong support for rapid reservoir type identification. Moreover, the characteristic type library contains rich reservoir characteristic information and has a certain degree of universality and scalability, applicable to different types of fractured-cavity carbonate reservoirs.

[0018] This invention proposes a dynamic reserve calculation system for fractured-vuggy carbonate reservoirs. The system accurately calculates crude oil parameters through a first processing unit, constructs a feature type library through a feature processing unit, fits the current production curve and calculates the elastic yield through a second processing unit, quickly identifies dynamic reserve characteristics through a type judgment unit, accurately calculates the dynamic reserves of pores, fractures, and vuggy rocks through a third processing unit, and finally displays the results through an output unit. The entire system has a clear structure and complete functions, which not only improves the accuracy and efficiency of dynamic reserve calculation for pores, fractures, and vuggy rocks, but also reduces human intervention and errors, ensuring the objectivity and reliability of the calculation results. Attached Figure Description

[0019] Figure 1 This is a flowchart illustrating the dynamic reserve calculation method for fractured-vuggy carbonate reservoirs proposed in this invention. Figure 2 This is a schematic diagram of the rectangular coordinate system fitted to the saturated oil compressibility coefficient in the dynamic reserve calculation method for fractured-vuggy carbonate reservoirs proposed in this invention. Figure 3 This is a fitted curve of the formula for calculating the compressibility coefficient of crude oil in the dynamic reserve calculation method for fractured-vuggy carbonate reservoirs proposed in this invention. Figure 4 This is a fitting curve of the formula for calculating the volume factor of crude oil in the dynamic reserve calculation method for fractured-vuggy carbonate reservoirs proposed in this invention. Figure 5 This is the self-flowing characteristic curve of the cave + pore reservoir in the dynamic reserve calculation method of fractured-vuggy carbonate reservoir proposed in this invention; Figure 6 This is the self-flowing characteristic curve of the cave + pore + fracture reservoir in the dynamic reserve calculation method of fractured carbonate reservoir proposed in this invention; Figure 7 This is a schematic diagram of the current production curve in the dynamic reserve calculation method for fractured-vuggy carbonate reservoirs proposed in this invention. Figure 8 This is a schematic diagram of the line segment of the fitted elastic yield in the dynamic reserve calculation method for fractured-vuggy carbonate reservoirs proposed in this invention. Figure 9 This is a graph showing the relationship between cumulative oil production, cumulative oil pressure drop, and elastic production in the dynamic reserve calculation method for fractured-vuggy carbonate reservoirs proposed in this invention. Detailed Implementation

[0020] In the following description, only certain exemplary embodiments are briefly described. As those skilled in the art will recognize, the described embodiments can be modified in various ways without departing from the spirit or scope of the invention. Therefore, the drawings and description are considered to be exemplary in nature and not restrictive.

[0021] In the description of this invention, it should be understood that the terms "center," "longitudinal," "lateral," "length," "width," "thickness," "upper," "lower," "front," "rear," "left," "right," "vertical," "horizontal," "top," "bottom," "inner," "outer," "clockwise," "counterclockwise," "axial," "radial," and "circumferential" indicate the orientation or positional relationship based on the orientation or positional relationship shown in the accompanying drawings. They are used only for the convenience of describing this invention and simplifying the description, and do not indicate or imply that the device or element referred to must have a specific orientation, or be constructed and operated in a specific orientation. Therefore, they should not be construed as limitations on this invention.

[0022] Furthermore, the terms "first" and "second" are used for descriptive purposes only and should not be construed as indicating or implying relative importance or implicitly specifying the number of indicated technical features. Thus, a feature defined as "first" or "second" may explicitly or implicitly include one or more of that feature. In the description of this invention, "a plurality of" means two or more, unless otherwise explicitly specified.

[0023] In this invention, unless otherwise explicitly specified and limited, the terms "installation," "connection," "linking," and "fixing," etc., should be interpreted broadly. For example, they can refer to a fixed connection, a detachable connection, or an integral part; they can refer to a mechanical connection, an electrical connection, or a communication connection; they can refer to a direct connection or an indirect connection through an intermediate medium; they can refer to the internal communication of two components or the interaction between two components. Those skilled in the art can understand the specific meaning of the above terms in this invention according to the specific circumstances.

[0024] In this invention, unless otherwise explicitly specified and limited, "above" or "below" the second feature can include direct contact between the first and second features, or contact between the first and second features through another feature between them. Furthermore, "above," "over," and "on top" of the second feature includes the first feature being directly above or diagonally above the second feature, or simply indicates that the first feature is at a higher horizontal level than the second feature. "Below," "below," and "under" the second feature includes the first feature being directly above or diagonally above the second feature, or simply indicates that the first feature is at a lower horizontal level than the second feature.

[0025] The embodiments of the present invention will now be described in detail with reference to the accompanying drawings.

[0026] See Figure 1 This invention proposes a method for calculating the dynamic reserves of fractured-vuggy carbonate reservoirs. This method includes the following steps: Crude oil calculation parameters are obtained based on reservoir fluid property data. These crude oil calculation parameters include crude oil compressibility and crude oil volume factor. Specifically, obtain the saturated oil compressibility coefficient and crude oil volume coefficient from the reservoir fluid properties report (PVT report) of the well being drilled or adjacent wells; A formula for calculating the crude oil compressibility coefficient is obtained by fitting the midpoint of the pressure range corresponding to the saturated oil compressibility coefficient and the oil compressibility coefficient. Based on the obtained current formation pressure value, the crude oil compressibility coefficient is calculated using the fitted formula. ; The formula for calculating the compressibility coefficient of crude oil is as follows: y=220.93x -0.692 ; In the formula, y is the crude oil compressibility coefficient. , where x is the current formation pressure value.

[0027] In this embodiment, the saturated oil compressibility coefficient is used as the vertical axis, and the midpoint of the formation pressure range corresponding to the saturated oil compressibility coefficient is used as the vertical axis to obtain the first coordinate point data. The first coordinate point data is marked in a rectangular coordinate system to obtain the saturated oil compressibility coefficient coordinate marker points. These coordinate marker points are fitted to form the saturated oil compressibility coefficient curve. The fitting coefficient of each saturated oil compressibility coefficient curve is calculated, that is, the slope of the saturated oil compressibility coefficient curve. The saturated oil compressibility coefficient curve with a slope close to 1 is selected as the crude oil compressibility coefficient fitting curve to obtain the crude oil compressibility coefficient calculation formula. The following explanation of this step is provided in conjunction with specific examples; Obtain the saturated oil compressibility coefficient from the PVT report of the currently drilling well or adjacent well, as shown in Table 1;

[0028] Table 1 shows the saturated oil compressibility coefficient in the PVT reports of currently drilling wells or adjacent wells. The median values ​​of the formation pressure ranges in Table 1 above were removed to obtain 83.06, 75, 65, 55, 45, 35, and 25. The coordinates (83.06, 10.47) were obtained by fitting 83.06 to 10.47; (75, 10.47) by fitting 75 to 11.11; (65, 12.19) by fitting 65 to 12.19; (55, 13.70) by fitting 55 to 13.70; (45, 16.08) by fitting 45 to 16.08; (35, 18.23) by fitting 35 to 18.23; and (25, 24.28) by fitting 25 to 24.28. These coordinates were then fitted to a rectangular coordinate system as follows: Figure 2 As shown, power-fitting these coordinate points yields a fitted curve and its corresponding fitting coefficient. A fitting coefficient of 0.9965 is selected, resulting in the formula for calculating the crude oil compressibility coefficient, as follows: Figure 3 As shown.

[0029] A formula for calculating the crude oil volume factor is obtained by fitting the crude oil volume factor and the midpoint of the pressure range corresponding to the crude oil volume factor. Based on the obtained current formation pressure value, the crude oil volume factor under the formation pressure is calculated using the fitted crude oil volume factor calculation formula. ; The formula for calculating the crude oil volume factor is as follows: Y = -0.0022X + 1.4846; In the formula, Y is the crude oil volume coefficient under formation pressure. X represents the current formation pressure value.

[0030] In this embodiment, the crude oil volume factor is used as the ordinate, and the saturation pressure corresponding to the crude oil volume factor is used as the ordinate to fit the second coordinate point data. This second coordinate point data is then marked in a Cartesian coordinate system, such as... Figure 4 As shown, the coordinate markers of the crude oil volume coefficient are obtained. These coordinate markers are fitted to form the crude oil volume coefficient curve. The linear correlation is taken to obtain the crude oil volume coefficient calculation formula. Obtain the bubble point pressure from the reservoir fluid properties report (PVT report) of the well or adjacent well. Based on the bubble point pressure, filter the production data of the well during the flow period, retain the production data with a pressure greater than the bubble point pressure, and calculate the historical cumulative pressure drop and historical cumulative oil production based on the production data. Historical spontaneous flow period characteristic curves were obtained by fitting historical cumulative pressure drop data and historical cumulative oil production data. Characteristic types were then determined based on these curves, and a characteristic type library was constructed based on these types. A linear relationship between the historical spontaneous flow period characteristic curves indicates that the reservoir exhibits characteristics of a collective spontaneous flow period in cavernous and pore-type reservoirs. Figure 5 As shown; if the historical spontaneous flow characteristic curves are not linear, it indicates that there is fluid supply characteristics at the distal end, belonging to the collective characteristics of cavern + pore + fracture type reservoirs, such as... Figure 6 As shown. After obtaining the water injection data for each well cycle, the current cumulative oil pressure drop and current cumulative oil production data are used to fit the current production curve during the well opening process. Figure 7 As shown, a non-linear relationship was observed, with the later upward tilt indicating degassing. Therefore, a straight line segment is preferred to fit the elastic yield, as shown below. Figure 8 As shown, the elastic yield K is obtained based on the fitting of the current production curve, as follows: Figure 9 As shown in the figure. Here, the elastic yield K is the reciprocal of the slope of the current production curve.

[0031] Based on the comparison between the feature type library and the current production curve, the dynamic reserve characteristics exhibited by the current production curve are determined. Specifically, the current production curve is compared with the historical self-flowing period characteristic curves in the characteristic type library to determine the characteristic types present in the current production curve, which are denoted as dynamic reserve characteristics. Dynamic reserve characteristics include cave + pore + fracture type reservoir collectives and cave + pore type reservoir collectives.

[0032] Based on elastic yield K and crude oil compressibility coefficient Crude oil volume coefficient under formation pressure Based on the dynamic reserve characteristics reflected in the self-flowing period and the water injection oil replacement stage, the dynamic reserves of pores, fractures, and vulnerabilities were calculated respectively. The calculation process is as follows: ; in, The current cumulative oil production m 3 ; This is the crude oil volume factor under formation pressure; Dynamic reserves; The volume factor under the original pressure; The overall compressibility coefficient is 1 / MPa; where, Total pressure drop (MPa) , =Original formation pressure - Current formation pressure.

[0033] The calculation process after water injection into the oil well is as follows: ; in, Cumulative oil production on the surface (m) 3 ; This is the crude oil volume factor under formation pressure; Dynamic reserves; The volume factor under the original pressure; The overall compressibility factor is 1 / MPa; Total pressure drop (MPa); The compressibility coefficient of water + rock is 1 / MPa; The volume coefficient of water under the original pressure; For the volume of water to be sealed (m) 3 ; For the cumulative water production at ground level; The volume coefficient of water. , =Original formation pressure - Current formation pressure.

[0034] Overall compressibility The calculation process is as follows: ; In the formula, This is the overall compression coefficient; The compression coefficient of crude oil; The water compressibility coefficient; To bind water saturation; This represents the original oil saturation. is the rock compressibility coefficient.

[0035] For cavern + pore + fracture reservoirs: the first segment of the slope during the self-flowing period represents the cavern + pore reserves N1, and the second segment represents the cavern + pore + fracture reserves N2; during water injection for oil replacement, the stable elastic production segment is the cavern type reserves N3, therefore the pore reserves N4 = N1 - N3, and the fracture reserves = N2 - N1; for cavern + pore reservoirs: the self-flowing period reserves are the cavern + pore reserves N1, and the stable elastic production segment is the cavern type reserves N2, then the dynamic reserves of the pores = N1 - N2.

[0036] The present invention also discloses a system for calculating the gas content of shale reservoirs, comprising a first processing unit, a feature processing unit, a second processing unit, a type judgment unit, a third processing unit, and an output unit. The first processing unit is communicatively connected to the second processing unit and the third processing unit, the second processing unit is communicatively connected to the type judgment unit, the type judgment unit is communicatively connected to the third processing unit, and the third processing unit is communicatively connected to the output unit.

[0037] The first processing unit is used to calculate crude oil calculation parameters based on reservoir fluid property data; The feature processing unit is used to filter the production data of the self-flowing oil wells obtained based on the bubble point pressure to obtain the historical cumulative pressure drop and historical cumulative oil production, and to construct a feature type library based on the historical cumulative pressure drop data and historical cumulative oil production data. The second processing unit is used to fit the current cumulative oil pressure drop data and current cumulative oil production data during the well opening production process after water injection in the well cycle to obtain the current production curve, and to fit the elastic yield based on the current production curve. The type determination unit is used to determine the reservoir collective type corresponding to the current production curve based on the comparison between the feature type library and the current production curve. The third processing unit is used to calculate the dynamic reserves of each reservoir type in the reservoir collective type based on the elastic yield and the crude oil calculation parameters.

[0038] The output unit is used to output the dynamic reserves of each reservoir type in the reservoir collective type.

[0039] In another embodiment of the present invention, a computer device is provided, comprising a processor and a memory. The memory stores a computer program, which includes program instructions. The processor executes the program instructions stored in the computer storage medium. The processor may be a Central Processing Unit (CPU), or other general-purpose processors, digital signal processors (DSPs), application-specific integrated circuits (ASICs), field-programmable gate arrays (FPGAs), or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, etc. It is the computing and control core of the terminal, suitable for implementing one or more instructions, specifically suitable for loading and executing one or more instructions in the computer storage medium to achieve a corresponding method flow or corresponding function. The processor described in this embodiment of the present invention can be used for the operation of a dynamic reserve calculation method for fractured-vuggy carbonate reservoirs.

[0040] The foregoing has shown and described the basic principles, main features, and advantages of the present invention. It will be apparent to those skilled in the art that the invention is not limited to the details of the exemplary embodiments described above, and that the invention can be implemented in other specific forms without departing from its spirit or essential characteristics. Therefore, the embodiments should be considered illustrative and non-limiting in all respects, and the scope of the invention is defined by the appended claims rather than the foregoing description. Thus, all variations falling within the meaning and scope of equivalents of the claims are intended to be included within the scope of the invention. No reference numerals in the claims should be construed as limiting the scope of the claims.

[0041] Furthermore, it should be understood that although this specification describes embodiments, not every embodiment contains only one independent technical solution. This narrative style is merely for clarity. Those skilled in the art should consider the specification as a whole, and the technical solutions in each embodiment can be appropriately combined to form other embodiments that can be understood by those skilled in the art. The above content is only for illustrating the technical concept of the present invention and should not be construed as limiting the scope of protection of the present invention. Any modifications made based on the technical concept proposed in this invention shall fall within the scope of protection of the claims of this invention.

Claims

1. A method for calculating the dynamic reserves of fractured-vuggy carbonate reservoirs, characterized in that, Includes the following steps: Crude oil calculation parameters were obtained based on reservoir fluid property data; Based on the obtained bubble point pressure, the production data of the self-flowing oil wells were screened to obtain historical cumulative pressure drop and historical cumulative oil production. Based on the historical cumulative pressure drop data and historical cumulative oil production data, a feature type library was constructed. Based on the current cumulative oil pressure drop data and current cumulative oil production data obtained after the well is injected with water in each cycle, the current production curve is obtained by fitting the current production curve, and the elastic yield is obtained by fitting the current production curve. Based on the comparison between the feature type library and the current production curve, the dynamic reserve characteristics exhibited by the current production curve are determined. Based on the elastic yield, the crude oil calculation parameters, and the dynamic reserve characteristics reflected in the self-flowing period and the water injection oil replacement stage, the dynamic reserves of pores, fractures, and cavities are calculated respectively.

2. The method for calculating the dynamic reserves of fractured-vuggy carbonate reservoirs according to claim 1, characterized in that, Crude oil calculation parameters are obtained based on reservoir fluid property data, including: Obtain the saturated oil compressibility coefficient and crude oil volume coefficient from the reservoir fluid properties report of the well being drilled or adjacent wells; The crude oil compressibility coefficient calculation formula is obtained by fitting the saturated oil compressibility coefficient, and the crude oil compressibility coefficient is calculated by using the crude oil compressibility coefficient calculation formula based on the obtained current formation pressure value. The crude oil volume factor calculation formula is obtained based on the crude oil volume factor fitting. The crude oil volume factor under formation pressure is then calculated using the crude oil volume factor calculation formula based on the obtained current formation pressure value.

3. The method for calculating the dynamic reserves of fractured-vuggy carbonate reservoirs according to claim 2, characterized in that, The formula for calculating the compressibility coefficient of crude oil is obtained based on the fitting of the compressibility coefficient of saturated oil, including: Using the saturated oil compressibility coefficient as the ordinate and the midpoint of the formation pressure range corresponding to the saturated oil compressibility coefficient as the ordinate, the first coordinate point data is obtained by fitting. The data of the first coordinate point are fitted in a rectangular coordinate system to form a saturated oil compressibility curve; Calculate the fitting coefficient of each of the saturated oil compressibility coefficient curves, select the saturated oil compressibility coefficient curve with the fitting coefficient close to 1 as the crude oil compressibility coefficient fitting curve, and obtain the crude oil compressibility coefficient calculation formula by fitting.

4. The method for calculating the dynamic reserves of fractured-vuggy carbonate reservoirs according to claim 1, characterized in that, The crude oil volume coefficient calculation formula is obtained by fitting the crude oil volume coefficient, including: using the crude oil volume coefficient as the vertical axis and the midpoint value of the formation pressure range corresponding to the crude oil volume coefficient as the vertical axis, fitting the second coordinate point data. The data of the second coordinate point are fitted in a rectangular coordinate system to form a crude oil volume factor curve. The linear correlation is then taken to obtain the crude oil volume factor calculation formula.

5. The method for calculating the dynamic reserves of fractured-vuggy carbonate reservoirs according to claim 1, characterized in that, Based on the production data of the self-flowing oil wells obtained through the bubble point pressure screening, the historical cumulative pressure drop and historical cumulative oil production are obtained, including: Obtain production data of oil wells during the self-flowing period, compare the oil pressure and bubble point pressure in the production data of oil wells during the self-flowing period, retain the cumulative pressure drop and cumulative oil production corresponding to the oil pressure being greater than the bubble point pressure, and obtain the historical cumulative pressure drop and historical cumulative oil production.

6. The method for calculating the dynamic reserves of fractured-vuggy carbonate reservoirs according to claim 1, characterized in that, The feature type library constructed based on historical cumulative pressure drop data and historical cumulative oil production data includes: The historical self-flowing period characteristic curve was obtained by fitting the historical cumulative pressure drop data and the historical cumulative oil production data. Determine the linear relationship of the historical self-spraying period characteristic curves; If the historical spontaneous flow period characteristic curves show a linear relationship, then it belongs to the collective spontaneous flow period characteristics of cave + pore type reservoirs. If the historical self-flowing period characteristic curve is not linear, it means that the reservoir has liquid supply characteristics at the far end, which belongs to the characteristics of cave + pore + fracture type reservoir. The feature type library is obtained by combining the collective characteristics of cave + pore + fracture type reservoirs and the self-flowing period characteristics of cave + pore type reservoirs.

7. The method for calculating the dynamic reserves of fractured-vuggy carbonate reservoirs according to claim 1, characterized in that, The calculation process for the dynamic reserves of pores, fractures, and vulnerabilities, based on the elastic yield, crude oil calculation parameters, and the dynamic reserve characteristics reflected in the self-flowing period and water injection oil replacement stage, is as follows: ； in, The current cumulative oil production m 3 ; This is the crude oil volume factor under formation pressure; Dynamic reserves; The volume factor under the original pressure; The overall compressibility coefficient is 1 / MPa; where, Total pressure drop (MPa) , =Original formation pressure - Current formation pressure.

8. The method for calculating the dynamic reserves of fractured-vuggy carbonate reservoirs according to claim 7, characterized in that, After water injection into the oil well, the calculation process for determining the dynamic reserves of pores, fractures, and vulnerabilities based on the elastic yield, crude oil calculation parameters, and the dynamic reserve characteristics reflected during the self-flowing period and the water injection replacement stage is as follows: ； in, Cumulative oil production on the surface (m) 3 ; This is the crude oil volume factor under formation pressure; Dynamic reserves; The volume factor under the original pressure; The overall compressibility factor is 1 / MPa; Total pressure drop (MPa); The compressibility coefficient of water + rock is 1 / MPa; The volume coefficient of water under the original pressure; For the volume of water to be sealed (m) 3 ; For the cumulative water production at ground level; The volume coefficient of water. , =Original formation pressure - Current formation pressure; Overall compressibility The calculation process is as follows: ； In the formula, This is the overall compression coefficient; The compression coefficient of crude oil; The water compressibility coefficient; To bind water saturation; This represents the original oil saturation. is the rock compressibility coefficient.

9. A dynamic reserve calculation system for fractured-vuggy carbonate reservoirs, characterized in that, The method for calculating the dynamic reserves of fractured-vuggy carbonate reservoirs according to any one of claims 1 to 8 includes: The first processing unit is used to calculate crude oil calculation parameters based on reservoir fluid property data; The feature processing unit is used to filter the production data of the self-flowing oil well based on the obtained bubble point pressure, obtain the historical cumulative pressure drop and historical cumulative oil production, and construct a feature type library based on the historical cumulative pressure drop data and historical cumulative oil production data. The second processing unit is used to fit the current cumulative oil pressure drop data and current cumulative oil production data during the well opening production process after water injection in the well cycle to obtain the current production curve, and to fit the elastic yield based on the current production curve. The type determination unit is used to determine the dynamic reserve characteristics of the current production curve based on the comparison between the feature type library and the current production curve. The third processing unit is used to calculate the dynamic reserves of holes, fractures, and cavities based on the elastic yield, the crude oil calculation parameters, and the dynamic reserve characteristics reflected in the self-flowing period and the water injection oil replacement stage. The output unit is used to output the calculated dynamic reserves of holes, fissures, and cavities.

10. A computer device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that, When the processor executes the computer program, it implements the steps of the dynamic reserve calculation method for fractured-vuggy carbonate reservoirs as described in any one of claims 1 to 8.

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