Method, device and equipment for determining reserves of fractured-vuggy oil reservoir, storage medium and program product

Abstract

The embodiment of the invention provides a fracture-vug type oil reservoir reserve determination method and device, equipment, a storage medium and a program product. The method comprises the following steps: acquiring current data of crude oil under a current condition, original data of the crude oil under an original condition, karst cave porosity, fracture porosity and matrix porosity corresponding to the fractured-vuggy reservoir at intervals of preset time; according to the karst cave porosity, the fracture porosity and the matrix porosity, the oil reservoir comprehensive compressibility coefficient is determined; and according to the current data of the crude oil under the current condition, the original data of the crude oil under the original condition and the oil reservoir comprehensive compression coefficient, determining the fracture-cavity type oil reservoir reserves. According to the method, the porosity of the matrix, the porosity of the fracture and the porosity of the cave are introduced, the porosity of the karst cave, the porosity of the fracture and the porosity of the matrix are added when the reserves are calculated, the characteristics of different reservoir spaces are considered, the actual condition of the oil reservoir can be reflected more accurately, and the accurate dynamic reserves can be obtained.

Description

Technical Field

[0001] This application relates to the field of reservoir development technology, and in particular to a method, apparatus, equipment, storage medium and program product for determining the reserves of fractured-vuggy reservoirs. Background Technology

[0002] Fractured-vuggy carbonate reservoirs exhibit a variety of reservoir space types, ranging from micrometer-sized intergranular and intercrystalline pores to large caverns tens of meters in size. These different reservoir spaces vary greatly in scale and are unevenly distributed. Calculating dynamic reserves is a crucial step in the development of fractured-vuggy reservoirs, as it forms the basis of oilfield development and production and is an important parameter for evaluating reservoir development.

[0003] The most commonly used method for calculating dynamic reserves of oil reservoirs is the material balance method. The material balance method derives the material balance equation for calculating the dynamic reserves of fractured-vuggy reservoirs by introducing the water-oil ratio. This equation can convert the energy intensity of water bodies into the water-oil ratio, analyze the size of water bodies connected to the fractured-vuggy reservoir, and complete the reserve calculation. This method takes into account the influence of internal oil-water coexisting water bodies or water bodies connected to the outside.

[0004] The basic oil and gas storage unit of a fractured-vuggy reservoir is a discrete fractured-vuggy body composed of multiple types of storage spaces, including pores, cavities, and fractures. The above-mentioned storage method does not take into account the reservoir characteristics of pores, cavities, and fractures, nor does it take into account the special characteristics of fractured-vuggy reservoirs. Therefore, it cannot obtain a relatively accurate reservoir storage. Summary of the Invention

[0005] This application provides a method, apparatus, equipment, storage medium, and program product for determining the reserves of fractured-vuggy oil reservoirs, in order to solve the technical problem that conventional dynamic oil reservoir reserve methods do not take into account the special characteristics of fractured-vuggy oil reservoirs and cannot obtain relatively accurate oil reservoir reserves.

[0006] In a first aspect, embodiments of this application provide a method for determining the reserves of fractured-vuggy oil reservoirs, including:

[0007] At preset intervals, acquire current data of crude oil under current conditions, original data of crude oil under original conditions, cavern porosity, fracture porosity, and matrix porosity corresponding to fractured-vuggy reservoirs;

[0008] The overall compressibility coefficient of the reservoir is determined based on the porosity of the karst caves, the porosity of the fractures, and the porosity of the matrix.

[0009] Based on the current data of crude oil under the current conditions, the original data of crude oil under the original conditions, and the comprehensive compressibility coefficient of the reservoir, the reserves of the fractured-vuggy reservoir are determined.

[0010] The current data includes: oil production from the reservoir, the first dissolved gas-oil ratio of crude oil under current conditions, the cumulative gas-oil production ratio of the reservoir, water production, the first crude oil volume factor of crude oil under current conditions, and the first pressure of crude oil under current conditions; the original data includes: the second crude oil volume factor of crude oil under original conditions and the second pressure of crude oil under original conditions.

[0011] In one possible implementation, determining the reservoir's overall compressibility coefficient based on the cavern porosity, the fracture porosity, and the matrix porosity includes:

[0012] Obtain the pore compressibility coefficient, fracture water saturation, matrix water saturation, cavity water saturation, and water compressibility coefficient;

[0013] The overall compressibility coefficient of the reservoir is determined based on the porosity compressibility coefficient, the fracture-bound water saturation, the matrix-bound water saturation, the cavity-bound water saturation, the water compressibility coefficient, the cavern porosity, the fracture porosity, and the matrix porosity.

[0014] In one possible implementation, determining the reserves of a fractured-vuggy reservoir based on current data of crude oil under the current conditions, original data of crude oil under the original conditions, and the reservoir's overall compressibility coefficient includes:

[0015] The reservoir values ​​are calculated based on the oil production, the first crude oil volume factor, the cumulative gas-oil ratio produced by the reservoir, the first dissolved gas-oil ratio, the gas volume factor, the water production, the water volume factor, the second crude oil volume factor, the reservoir comprehensive compressibility factor, two compressibility factors, the first pressure, and the second pressure.

[0016] The reserves of the fractured-vuggy reservoir are determined based on the reservoir data.

[0017] In one possible implementation, the reservoir values ​​include: a first reservoir value and a second reservoir value;

[0018] The calculation of reservoir values ​​based on the reservoir's produced oil volume, the first crude oil volume factor, the reservoir's cumulative produced gas-oil ratio, the first dissolved gas-oil ratio, the gas volume factor, the water production, the water volume factor, the second crude oil volume factor, the reservoir's comprehensive compressibility factor, two compressibility factors, the first pressure, and the second pressure includes:

[0019] The values ​​of the first oil reservoir are calculated based on the oil production, the first crude oil volume factor, the cumulative gas-oil ratio of the oil reservoir, the first dissolved gas-oil ratio, the gas volume factor, the water production, and the water volume factor.

[0020] The second reservoir value is calculated based on the second crude oil volume factor, the reservoir comprehensive compressibility factor, two compressibility factors, the first pressure, and the second pressure.

[0021] In one possible implementation, determining the reserves of the fractured-vuggy reservoir based on the reservoir data includes:

[0022] Substituting the first reservoir value and the second reservoir value into the material balance equation for fractured-vuggy reservoirs, the reserves of the fractured-vuggy reservoirs are calculated. The material balance equation for fractured-vuggy reservoirs is expressed as follows:

[0023] Y = NX

[0024] Wherein, Y is the value of the first reservoir, N is the reserve of the fractured-vuggy reservoir, and X is the value of the second reservoir.

[0025] In one possible implementation, the raw data for crude oil under the original conditions includes: the second dissolved gas-oil ratio of the crude oil under the original conditions; the two compressibility coefficients are determined by:

[0026] The two compressibility coefficients are determined based on the first crude oil volume coefficient, the second dissolved gas-oil ratio, the first dissolved gas-oil ratio, the gas volume coefficient, the second crude oil volume coefficient, the first pressure, and the second pressure.

[0027] In one possible implementation, the cavern porosity, the fracture porosity, and the matrix porosity are obtained by the following method:

[0028] Obtain the volume of the cavern, the volume of the fissures, the volume of the matrix pores, and the volume of the rock under the original conditions;

[0029] The porosity of the karst cave is calculated based on the volume of the karst cave and the volume of the rock under the original conditions. The porosity of the crack is calculated based on the volume of the crack and the volume of the rock under the original conditions. The porosity of the matrix is ​​calculated based on the porosity of the karst cave, the porosity of the crack, and the volume of the rock under the original conditions.

[0030] In one possible implementation, it also includes:

[0031] Based on the relationship between the reserves and water volume ratio of the fractured-vuggy oil reservoir and the reserves, the water volume ratio corresponding to the reserves of the fractured-vuggy oil reservoir is determined.

[0032] In one possible implementation, it also includes:

[0033] The pressure of water on the formation is calculated based on the reserves of the fractured-vuggy oil reservoir and the production data.

[0034] Secondly, embodiments of this application provide an apparatus for determining the reserves of fractured-vuggy oil reservoirs, comprising:

[0035] The acquisition unit is used to acquire, at preset intervals, the current data of crude oil under the current conditions, the original data of crude oil under the original conditions, the porosity of the vault, the porosity of the fracture, and the matrix porosity of the crude oil in the fractured-vuggy reservoir.

[0036] The processing unit is used to determine the overall compressibility coefficient of the reservoir based on the porosity of the karst caves, the porosity of the fractures, and the porosity of the matrix.

[0037] The processing unit is also used to determine the reserves of fractured-vuggy reservoirs based on the current data of crude oil under the current conditions, the original data of crude oil under the original conditions, and the comprehensive compressibility coefficient of the reservoir.

[0038] The current data includes: oil production from the reservoir, the first dissolved gas-oil ratio of crude oil under current conditions, the cumulative gas-oil production ratio of the reservoir, water production, the first crude oil volume factor of crude oil under current conditions, and the first pressure of crude oil under current conditions; the original data includes: the second crude oil volume factor of crude oil under original conditions and the second pressure of crude oil under original conditions.

[0039] Thirdly, embodiments of this application provide an electronic device, including: a memory and a processor;

[0040] The memory stores computer-executed instructions;

[0041] The processor executes computer execution instructions stored in the memory, causing the processor to perform the first aspect and / or various possible implementations of the first aspect as described above.

[0042] Fourthly, embodiments of this application provide a computer-readable storage medium storing computer-executable instructions, which, when executed by a processor, are used to implement the first aspect and / or various possible implementations of the first aspect.

[0043] Fifthly, embodiments of this application provide a computer program product, including a computer program that, when executed by a processor, implements the first aspect and / or various possible implementations of the first aspect.

[0044] The method, apparatus, equipment, storage medium, and program product for determining the reserves of fractured-vuggy oil reservoirs provided in this application acquire, at preset time intervals, current data of crude oil under current conditions, original data of crude oil under original conditions, cavern porosity, fracture porosity, and matrix porosity corresponding to the fractured-vuggy oil reservoir. Further, based on the cavern porosity, fracture porosity, and matrix porosity, the comprehensive compressibility coefficient of the oil reservoir is determined. Thus, the reserves of the fractured-vuggy oil reservoir are calculated based on the current data of crude oil under current conditions, the original data of crude oil under original conditions, and the comprehensive compressibility coefficient. In calculating the reserves of fractured-vuggy oil reservoirs, matrix, fracture, and cavern porosity are introduced, and cavern porosity, fracture porosity, and matrix porosity are added when calculating reserves, taking into account the characteristics of different reservoir spaces. The comprehensive compressibility coefficient obtained through matrix, fracture, and cavern porosity allows for a more accurate reflection of the actual situation of the oil reservoir and provides a more accurate dynamic reserve. Attached Figure Description

[0045] The accompanying drawings, which are incorporated in and form part of this specification, illustrate embodiments consistent with this application and, together with the description, serve to explain the principles of this application.

[0046] Figure 1 A schematic diagram illustrating a scenario for determining the reserves of fractured-vuggy oil reservoirs provided in an embodiment of this application;

[0047] Figure 2 A flowchart illustrating the method for determining the reserves of fractured-vuggy reservoirs provided in this application embodiment. Figure 1 ;

[0048] Figure 3 A flowchart illustrating the method for determining the reserves of fractured-vuggy reservoirs provided in this application embodiment. Figure 2 ;

[0049] Figure 4 The curve showing the relationship between water volume ratio and storage capacity;

[0050] Figure 5 This is a schematic diagram showing the results of fitting production data from the actual well x.

[0051] Figure 6 A schematic diagram illustrating the calculated formation pressure of water in actual well x.

[0052] Figure 7 A schematic diagram of the fitting results of a single-slit hole with 20 times the water volume;

[0053] Figure 8 A schematic diagram of the fitting results of a single-slit hole with 50 times the water volume;

[0054] Figure 9 A schematic diagram showing the fitting results of a multi-slit hole with a water volume of 10 times its original size.

[0055] Figure 10 A schematic diagram showing the fitting results of a multi-slit hole at 100 times the size of the water body;

[0056] Figure 11 A schematic diagram of the structure of the device for determining the reserves of fractured-vuggy oil reservoirs provided in the embodiments of this application;

[0057] Figure 12 This is a schematic diagram of the structure of an electronic device provided in an embodiment of this application.

[0058] The accompanying drawings illustrate specific embodiments of this application, which will be described in more detail below. These drawings and descriptions are not intended to limit the scope of the concept in any way, but rather to illustrate the concept of this application to those skilled in the art through reference to particular embodiments. Detailed Implementation

[0059] Exemplary embodiments will now be described in detail, examples of which are illustrated in the accompanying drawings. When the following description relates to the drawings, unless otherwise indicated, the same numbers in different drawings denote the same or similar elements. The embodiments described in the following exemplary embodiments do not represent all embodiments consistent with this application. Rather, they are merely examples of apparatuses and methods consistent with some aspects of this application as detailed in the appended claims.

[0060] Figure 1 This is a schematic diagram illustrating a scenario for the method of determining the reserves of fractured-vuggy reservoirs provided in an embodiment of this application. Figure 1 As shown, user terminal 101 and server 102 are connected. At preset intervals, the user inputs the current data of crude oil under the current conditions and the original data of crude oil under the original conditions corresponding to the fractured-vuggy reservoir into user terminal 101, and clicks the confirmation button, thereby triggering a processing request. Server 102 receives the processing request, parses it, and obtains the current data of crude oil under the current conditions, the original data of crude oil under the original conditions, the porosity of the vuggy reservoir, the porosity of the fractures, and the matrix porosity. Server 102 determines the comprehensive compressibility coefficient of the reservoir based on the porosity of the vuggy reservoir, the porosity of the fractures, and the matrix porosity. Server 102 determines the reserves of the fractured-vuggy reservoir based on the current data of crude oil under the current conditions, the original data of crude oil under the original conditions, and the comprehensive compressibility coefficient of the reservoir. Server 102 outputs the reserves of the fractured-vuggy reservoir to user terminal 101.

[0061] In existing technologies, conventional dynamic reservoir reserve methods do not take into account the special characteristics of fractured-vuggy reservoirs, thus failing to obtain accurate reservoir reserves.

[0062] The method for determining the reserves of fractured-vuggy reservoirs provided in this application, by introducing matrix, fracture, and vuggy porosity, obtains a comprehensive compressibility coefficient that can more accurately reflect the actual situation of the reservoir and thus obtain a more accurate reserve.

[0063] The technical solution of this application and how the technical solution of this application solves the above-mentioned technical problems are described in detail below with specific embodiments. These specific embodiments can be combined with each other, and the same or similar concepts or processes may not be described again in some embodiments. The embodiments of this application will now be described with reference to the accompanying drawings.

[0064] Figure 2 A flowchart illustrating the method for determining the reserves of fractured-vuggy reservoirs provided in this application embodiment. Figure 1 ,like Figure 2 As shown, the method includes:

[0065] Step 201: At preset intervals, acquire the current data of crude oil under the current conditions, the original data of crude oil under the original conditions, the porosity of the karst, the porosity of the fracture, and the matrix porosity of the corresponding fractured-vuggy reservoir.

[0066] In this embodiment, the preset time is set according to actual needs. At preset intervals, the current data of crude oil under the current conditions, the original data of crude oil under the original conditions, the porosity of the cavern, the porosity of the fracture, and the matrix porosity corresponding to the fractured-vuggy reservoir are obtained. The current data of crude oil under the current conditions refers to the current data corresponding to the extraction of a certain amount of oil, and the original data of crude oil under the original conditions refers to the original data of crude oil before extraction.

[0067] Specifically, the current data includes: oil production from the reservoir, the first dissolved gas-oil ratio of crude oil under current conditions, the cumulative produced gas-oil ratio of the reservoir, water production, the first crude oil volume factor of crude oil under current conditions, and the first pressure of crude oil under current conditions; the raw data includes: the second crude oil volume factor of crude oil under raw conditions and the second pressure of crude oil under raw conditions.

[0068] Optionally, at preset intervals, in response to user-triggered operations, the system acquires current data of crude oil under current conditions, original data of crude oil under original conditions, cavern porosity, fracture porosity, and matrix porosity corresponding to fractured-vuggy reservoirs.

[0069] Specifically, fractured-vuggy reservoirs have a large range of storage space scales, so it is necessary to consider the storage space of pores, fractures, and cavities in fractured-vuggy reservoirs. When calculating reserves, the porosity of caverns, fractures, and matrix is ​​added to take into account the characteristics of different storage spaces.

[0070] Step 202: Determine the overall compressibility coefficient of the reservoir based on the porosity of the karst caves, the porosity of the fractures, and the porosity of the matrix.

[0071] In this embodiment, the comprehensive compressibility coefficient of the reservoir is calculated based on the porosity of the karst caves, the porosity of the fractures, and the porosity of the matrix. The comprehensive compressibility coefficient of the reservoir is an important parameter in reservoir engineering. By introducing the porosity of the matrix, fractures, and caves, the obtained comprehensive compressibility coefficient can more accurately reflect the actual situation of the reservoir.

[0072] Step 203: Determine the reserves of fractured-vuggy reservoirs based on the current data of crude oil under the current conditions, the original data of crude oil under the original conditions, and the comprehensive compressibility coefficient of the reservoir.

[0073] In this embodiment, the reserves of fractured-vuggy reservoirs are calculated based on the current data of crude oil under the current conditions, the original data of crude oil under the original conditions, and the comprehensive compressibility coefficient of the reservoir. The reserves of fractured-vuggy reservoirs are then output. Specifically, the reserves of fractured-vuggy reservoirs are displayed, or the reserves of fractured-vuggy reservoirs are sent to the terminal so that reservoir developers can be informed of the current reservoir status in a timely manner.

[0074] The method for determining the reserves of fractured-vuggy oil reservoirs provided in this application obtains current data of crude oil under current conditions, original data of crude oil under original conditions, cavern porosity, fracture porosity, and matrix porosity corresponding to the fractured-vuggy oil reservoir. Further, based on the cavern porosity, fracture porosity, and matrix porosity, the comprehensive compressibility coefficient of the reservoir is determined. Thus, the reserves of the fractured-vuggy oil reservoir are calculated based on the current data of crude oil under current conditions, the original data of crude oil under original conditions, and the comprehensive compressibility coefficient of the reservoir. When calculating the reserves of fractured-vuggy oil reservoirs, matrix, fracture, and cavern porosity are introduced. By incorporating cavern porosity, fracture porosity, and matrix porosity into the reserve calculation, the characteristics of different reservoir spaces are considered. The comprehensive compressibility coefficient obtained through matrix, fracture, and cavern porosity allows for a more accurate reflection of the actual situation of the reservoir and provides a more accurate dynamic reserve.

[0075] Figure 3 A flowchart illustrating the method for determining the reserves of fractured-vuggy reservoirs provided in this application embodiment. Figure 2 ,like Figure 3 As shown, in this embodiment... Figure 2 Based on the examples, a detailed method for determining the reserves of fractured-vuggy oil reservoirs is provided, which includes:

[0076] Step 301: At preset intervals, obtain the volume of the karst cave, the volume of the cracks, the volume of the matrix pores, and the volume of the rock under the original conditions.

[0077] In this embodiment, the preset time is set according to actual needs. At preset intervals, the volume of the karst cave, the volume of the crack, the volume of the matrix pores, and the volume of the rock under the original conditions are obtained. The porosity of the karst cave, the porosity of the crack, and the porosity of the matrix are calculated by obtaining the volume of the karst cave, the volume of the crack, the volume of the matrix pores, and the volume of the rock under the original conditions.

[0078] Step 302: Calculate the porosity of the karst cave based on the volume of the karst cave and the volume of the rock under the original conditions; calculate the porosity of the crack based on the volume of the crack and the volume of the rock under the original conditions; and calculate the matrix porosity based on the porosity of the karst cave, the porosity of the crack, and the volume of the rock under the original conditions.

[0079] In this embodiment, the ratio of the volume of the karst cave to the volume of the rock under the original conditions is calculated to obtain the porosity of the karst cave. The porosity of the karst cave is calculated using formula (1), which is expressed as:

[0080]

[0081] Where, φ v V represents the porosity of the karst cave. vi V is the volume of the cave. b This represents the volume of the rock under the original conditions.

[0082] Specifically, the ratio of the fracture volume to the rock volume under the original conditions is calculated to obtain the fracture porosity. Specifically, the fracture porosity is calculated using formula (2), which is expressed as:

[0083]

[0084] Where, φ f V represents the crack porosity. fi V is the crack volume. b This represents the volume of the rock under the original conditions.

[0085] Specifically, the porosity of the karst cave, the porosity of the fracture, and the matrix porosity calculated from the rock volume under the original conditions are substituted into formula (3) to calculate the porosity of the karst cave. Formula (3) is expressed as:

[0086]

[0087] Where, φ m V represents matrix porosity. mi V is the matrix pore volume. b The volume of the rock under the original conditions, φ f For crack porosity, φ v This refers to the porosity of the karst cave.

[0088] Step 303: Obtain the current data of crude oil under the current conditions, the original data of crude oil under the original conditions, the porosity of the vault, the porosity of the fracture, and the matrix porosity corresponding to the fractured-vuggy reservoir.

[0089] In this embodiment, the current data of crude oil under the current conditions, the original data of crude oil under the original conditions, the porosity of the cavern, the porosity of the fracture, and the matrix porosity corresponding to the fractured-vuggy reservoir are obtained. The current data of crude oil under the current conditions refers to the current data corresponding to the extraction of a certain amount of oil, and the original data of crude oil under the original conditions refers to the original data of crude oil before extraction.

[0090] Specifically, the current data includes: oil production from the reservoir, the first dissolved gas-oil ratio of crude oil under current conditions, the cumulative produced gas-oil ratio of the reservoir, water production, the first crude oil volume factor of crude oil under current conditions, and the first pressure of crude oil under current conditions; the raw data includes: the second crude oil volume factor of crude oil under raw conditions and the second pressure of crude oil under raw conditions.

[0091] Optionally, at preset intervals, in response to user-triggered operations, the system acquires current data of crude oil under current conditions, original data of crude oil under original conditions, cavern porosity, fracture porosity, and matrix porosity corresponding to fractured-vuggy reservoirs.

[0092] Specifically, fractured-vuggy reservoirs have a large range of storage space scales, so it is necessary to consider the storage space of pores, fractures, and cavities in fractured-vuggy reservoirs. When calculating reserves, the porosity of caverns, fractures, and matrix is ​​added to take into account the characteristics of different storage spaces.

[0093] Step 304: Determine the overall compressibility coefficient of the reservoir based on the porosity of the karst caves, the porosity of the fractures, and the porosity of the matrix.

[0094] In this embodiment, the reserves of fractured-vuggy reservoirs are calculated based on the current data of crude oil under the current conditions, the original data of crude oil under the original conditions, and the comprehensive compressibility coefficient of the reservoir. The reserves of fractured-vuggy reservoirs are then output. Specifically, the reserves of fractured-vuggy reservoirs are displayed, or the reserves of fractured-vuggy reservoirs are sent to the terminal so that reservoir developers can be informed of the current reservoir status in a timely manner.

[0095] In one possible implementation, the overall reservoir compressibility coefficient is determined based on cavern porosity, fracture porosity, matrix porosity, and water volume ratio, including:

[0096] Obtain the pore compressibility coefficient, fracture-bound water saturation, matrix-bound water saturation, cavern-bound water saturation, and water compressibility coefficient; determine the reservoir's overall compressibility coefficient based on these parameters, including pore compressibility coefficient, fracture-bound water saturation, matrix-bound water saturation, cavern-bound water saturation, water compressibility coefficient, cavern porosity, fracture porosity, and matrix porosity.

[0097] In this embodiment, the pore compressibility coefficient, fracture-bound water saturation, matrix-bound water saturation, cavity-bound water saturation, and water compressibility coefficient are obtained. These values ​​are then substituted into formula (4) to calculate the reservoir's overall compressibility coefficient. Formula (4) is expressed as:

[0098]

[0100] Among them, C c φ is the reservoir's overall compressibility coefficient. v For the porosity of the karst cave, φ f For crack porosity, φ m For matrix porosity, C p R is the porosity compressibility coefficient. wo S is a multiple of the water volume. wmc S represents the matrix bound water saturation. wfc For the slit binding water saturation, S wvc To determine the saturation of the bound water in the cave, C w is the water compressibility coefficient.

[0101] The water volume ratio is defined as the ratio of the volume of water inside a fractured-vuggy reservoir to the reservoir volume under original conditions, expressed as a water volume ratio; or, the ratio of the volume of water outside the fractured-vuggy reservoir that connects to the oil-bearing layer to the reservoir volume under original conditions, expressed as a water volume ratio. The water volume ratio is defined as follows:

[0102]

[0103] Among them, R wo V is a multiple of the water volume. ci V represents the reservoir volume under original conditions. w V represents the volume of water inside a fractured-vuggy oil reservoir. w This indicates the volume of water that connects the outside of a fractured-vuggy oil reservoir to the oil-bearing layer.

[0104] Step 305: Determine the reserves of fractured-vuggy reservoirs based on the current data of crude oil under the current conditions, the original data of crude oil under the original conditions, and the comprehensive compressibility coefficient of the reservoir.

[0105] In this embodiment, the reserves of fractured-vuggy reservoirs are calculated based on the current data of crude oil under the current conditions, the original data of crude oil under the original conditions, and the comprehensive compressibility coefficient of the reservoir. The reserves of fractured-vuggy reservoirs are then output. Specifically, the reserves of fractured-vuggy reservoirs are displayed, or the reserves of fractured-vuggy reservoirs are sent to the terminal so that reservoir developers can be informed of the current reservoir status in a timely manner.

[0106] Optionally, the reserves of fractured-vuggy reservoirs are determined based on current crude oil data under current conditions, original crude oil data under original conditions, and the reservoir's overall compressibility coefficient, including:

[0107] The reservoir values ​​are calculated based on the reservoir produced oil volume, first crude oil volume factor, reservoir cumulative gas-oil ratio, first dissolved gas-oil ratio, gas volume factor, water production, water volume factor, second crude oil volume factor, reservoir comprehensive compressibility factor, two compressibility factors, first pressure, and second pressure; the reserves of fractured-vuggy reservoirs are determined based on the reservoir values.

[0108] In this embodiment, the reservoir values ​​are first calculated based on the reservoir produced oil volume, first crude oil volume factor, reservoir cumulative gas-oil ratio, first dissolved gas-oil ratio, gas volume factor, water production, water volume factor, second crude oil volume factor, reservoir comprehensive compressibility factor, two compressibility factors, first pressure and second pressure. Then, the reservoir reserves are calculated based on the reservoir values ​​and the material balance equation of the fractured-vuggy reservoir.

[0109] Optionally, reservoir values ​​include: first reservoir values ​​and second reservoir values; reservoir values ​​are calculated based on reservoir produced oil volume, first crude oil volume factor, reservoir cumulative gas-oil ratio, first dissolved gas-oil ratio, gas volume factor, water production, water volume factor, second crude oil volume factor, reservoir composite compressibility factor, two compressibility factors, first pressure, and second pressure, including:

[0110] The values ​​for the first reservoir are calculated based on the reservoir produced oil volume, the first crude oil volume factor, the reservoir cumulative gas-oil ratio, the first dissolved gas-oil ratio, the gas volume factor, the water production, and the water volume factor. The values ​​for the second reservoir are calculated based on the second crude oil volume factor, the reservoir comprehensive compressibility factor, the two compressibility factors, the first pressure, and the second pressure.

[0111] In this embodiment, the reservoir values ​​include: first reservoir values ​​and second reservoir values. The first reservoir value is calculated by substituting the reservoir produced oil volume, first crude oil volume factor, reservoir cumulative gas-oil ratio, first dissolved gas-oil ratio, gas volume factor, water production, and water volume factor into formula (6). Formula (6) is expressed as:

[0112] Y = N p [B o +(R p -R s B g ]+W p B w Formula (6)

[0113] Where Y is the value of the first reservoir, and N p B represents the amount of oil produced from the reservoir. o R is the first crude oil volume factor under current conditions.p R is the cumulative gas-oil production ratio of the reservoir. s B represents the first dissolved gas-oil ratio of crude oil under current conditions. g W is the gas volume coefficient. p For cumulative water production, B w This is the water volume coefficient.

[0114] Specifically, the second crude oil volume factor, reservoir comprehensive compressibility factor, two compressibility factors, first pressure and second pressure are substituted into formula (7) to calculate the value of the second reservoir. Formula (7) is expressed as:

[0115] X = B oi (C o +C c Formula (7) for Δp

[0116] Where X is the value of the second reservoir, and B oi C is the second crude oil volume factor of crude oil under the original conditions. o C is the two-phase compressibility coefficient. c Δp is the reservoir's overall compressibility coefficient, and Δp is the pressure difference, which is the difference between the first pressure of the crude oil under the current conditions and the second pressure of the crude oil under the original conditions.

[0117] Optionally, the reserves of fractured-vuggy reservoirs are determined based on reservoir data, including:

[0118] Substituting the values ​​of the first and second reservoirs into the material balance equation for fractured-vuggy reservoirs, the reserves of the fractured-vuggy reservoirs are calculated. The material balance equation for fractured-vuggy reservoirs is expressed as follows:

[0119] Y=NX formula (8)

[0120] Where Y represents the value of the first reservoir, N represents the reserves of the fractured-vuggy reservoir, and X represents the value of the second reservoir.

[0121] In this embodiment, the first reservoir value and the second reservoir value are substituted into formula (8) to calculate the reserves of the fractured-vuggy reservoir.

[0122] Optionally, the raw data for crude oil under the original conditions include: the second dissolved gas-oil ratio of crude oil under the original conditions; the two compressibility coefficients are determined in the following ways:

[0123] Two compressibility coefficients are determined based on the first crude oil volume coefficient, the second dissolved gas-oil ratio, the first dissolved gas-oil ratio, the gas volume coefficient, the second crude oil volume coefficient, the first pressure, and the second pressure.

[0124] In this embodiment, the first crude oil volume factor, the second dissolved gas-oil ratio, the first dissolved gas-oil ratio, the gas volume factor, the second crude oil volume factor, the first pressure, and the second pressure are substituted into formula (9) to calculate two compressibility coefficients. Formula (9) is expressed as:

[0125] The two-phase compressibility coefficient is expressed as:

[0126]

[0127] Among them, C o B is the two-phase compressibility coefficient. o R is the first crude oil volume factor under current conditions. si R represents the second dissolved gas-oil ratio of crude oil under the original conditions. s B represents the first dissolved gas-oil ratio of crude oil under current conditions. g B is the gas volume coefficient. oi Δp is the second crude oil volume coefficient under the original conditions, and Δp is the pressure difference.

[0128] Furthermore, there are two unknowns in formulas (8) and (4): the reserves N and R of fractured-vuggy reservoirs. wo To eliminate the problem of multiple solutions in the equation, a method of dimensionality reduction of unknowns is adopted. Specifically, the basic parameters, compressibility coefficient, and production data corresponding to the fractured-vuggy reservoir are obtained. Based on the basic parameters, compressibility coefficient, and production data, the least squares method is used to obtain the relationship between the water volume multiple and the reserves, and a quantitative relationship between the water volume multiple and the reserves is established as Rwo=F(N). The two unknown variables in formula (8) and formula (4), namely the reserves N of the fractured-vuggy reservoir and the water volume multiple Rwo, are reduced to a single unknown variable, the reserves N of the fractured-vuggy reservoir. The reserves N of the fractured-vuggy reservoir are calculated by least squares on the formula (8) after dimensionality reduction of unknowns.

[0129] To illustrate with an example, the basic parameters of the actual well x in Table 1, the compressibility coefficient of the saturated crude oil in Table 2, and the production data of the actual well x pressure measurement point in Table 3 are substituted into equation (6). The least squares method is used to give a series of different water volume multiples of 0, 1, 3, 5, 7, 10, 15, 20, 30, 50, and 70, corresponding to the corresponding reserve sizes, which are represented in curve form, such as... Figure 4 As shown, Figure 4 This is a curve showing the relationship between water volume ratio and storage capacity.

[0130] Table 1. Basic parameters of actual well x

[0131]

[0132]

[0133] Table 2 Compressibility of crude oil from well x

[0134] Pressure (MPa) <![CDATA[Compressibility factor (×10 -4 1 / MPa)]]> 78.8~70MPa 15.12 70~60MPa 17.15 60~50MPa 19.75 50~40MPa 24.51 40~30MPa 30.16

[0135] Table 3 Actual production data from well x pressure testing points

[0136]

[0137] Furthermore, based on the relationship curve between water volume ratio and reserves, a quantitative relationship between water volume ratio and reserves is established: Rwo = F(N). The two unknown variables, reserves N and water volume ratio Rwo, in formulas (8) and (4) are reduced to a single unknown variable, reserves N. The reserves are fitted according to formula (8), and the fitted reserves N of the fractured-vuggy reservoir in the actual well are 115 × 10⁴ m³. 3 That is, the actual x-well formula (9) is Y = 1510 × 4 X, see also Figure 5 , Figure 5 This is a schematic diagram showing the results of fitting production data from the actual well x.

[0138] Optionally, it also includes:

[0139] Based on the correspondence between the reserves and water volume ratio of fractured-vuggy oil reservoirs and the reserves, the water volume ratio corresponding to the reserves of fractured-vuggy oil reservoirs is determined.

[0140] Calculating the size of the water body is a crucial foundational task for reservoir dynamic analysis, development adjustment planning, and the implementation of oil stabilization and water control measures. Existing methods for calculating reservoir water multiples are complex and have poor applicability. To address this issue, this application provides a method for calculating horizontal multiples. Specifically, it obtains the correspondence between the reserves and water multiples of fractured-vuggy reservoirs and their reserves. Based on this correspondence, the water multiple corresponding to the reserves of the fractured-vuggy reservoir is determined. For example, using the aforementioned water multiple versus reserve relationship curve, after calculating the reserves N of the fractured-vuggy reservoir, an interpolation method is used to determine the corresponding water multiple as 18.7. After calculating the reserves, the water multiple can be obtained through the correspondence, providing more accurate data for reservoir energy evaluation.

[0141] Optionally, it also includes:

[0142] The pressure of water on the formation is calculated based on the reserves and production data of fractured-vuggy oil reservoirs.

[0143] Formation pressure is a key parameter in the development and production process of oil and gas fields. Existing methods and models for calculating formation pressure are not only computationally intensive and complex, but also cannot accurately calculate formation pressure. This embodiment provides a method for calculating pressure. Specifically, after calculating the reserves N of fractured-vuggy reservoirs, if the cumulative oil, gas, and water production of the actual wells remain unchanged, as shown in Table 3, then assuming the water body multiplier is 0, the pressure of the current water body on the formation is fitted using the least squares method according to formula (8), that is, the pressure contributed by the water body to the formation, as shown in Table 3. Figure 6 As shown, Figure 6 The current contribution pressure of the water body to the bottom layer is 43.88 MPa. This allows us to obtain a more accurate estimate of the contribution of the water body to the formation pressure, reducing the workload and difficulty of calculations, thereby improving work efficiency and benefiting subsequent operations.

[0144] Specifically, the material balance equation for fractured-vuggy reservoirs is obtained in the following way:

[0145] The reservoir volume under original conditions is determined in the following way:

[0146] Obtain the reservoir pore volume and initial water cut volume, and determine the reservoir volume under the original conditions based on the reservoir pore volume and initial water cut volume.

[0147] In this embodiment, the reservoir pore volume and the initial water cut volume are obtained, and the reservoir volume under the original conditions is calculated by substituting the reservoir pore volume and the initial water cut volume into formula (10). Formula (10) is expressed as:

[0148] V ci =V p -V wc Formula (10)

[0149] Among them, V ci V represents the reservoir volume under original conditions. p V is the reservoir pore volume. wc This represents the initial water-bearing volume of the reservoir.

[0150] The reservoir pore volume is determined in the following way:

[0151] The reservoir pore volume is determined based on the rock volume, cavern porosity, fracture porosity, and matrix porosity under the original conditions.

[0152] In this embodiment, the rock volume, cavern porosity, fracture porosity, and matrix porosity under the original conditions are substituted into formula (11) to calculate the reservoir pore volume. Formula (11) is expressed as:

[0153] V p =V b ×[φ v +φf +(1-φ f -φ v )×φ m ] Formula (11)

[0154] Among them, V p V is the reservoir pore volume. b The volume of the rock under the original conditions, φ v For the porosity of the karst cave, φ f For crack porosity, φ m This refers to the matrix porosity.

[0155] The initial water-bearing volume of the reservoir is determined in the following way:

[0156] The initial water-bearing volume of the reservoir is determined based on the matrix pore volume, matrix bound water saturation, fracture volume, fracture bound water saturation, cavern volume, and cavern bound water saturation.

[0157] In this embodiment, the matrix pore volume, matrix bound water saturation, fracture volume, fracture bound water saturation, cavern volume, and cavern bound water saturation are substituted into formula (12) to calculate the initial water-bearing volume of the reservoir. Formula (12) is expressed as:

[0158] V wc =V mi ×S wmc +V fi ×S wfc +V vi ×S wvc Formula (12)

[0159] Among them, V wc V represents the initial water-bearing volume of the reservoir. mi S represents the matrix pore volume. wmc V represents the matrix's bound water saturation. fi Let S be the crack volume. wfc For the slit binding water saturation, V vi S represents the volume of the cave. wvc To determine the water saturation level in the cave.

[0160] Specifically, we obtain the following through formulas (1), (2), (3), and (12):

[0161] V wc =V b ×[(1-φ f -φ v )×φ m ×S wmc +φ f ×S wfc +φ v ×S wvc] Formula (13)

[0162] Among them, V wc V represents the initial water-bearing volume of the reservoir. b The volume of the rock under the original conditions, φ f For crack porosity, φ v For the porosity of the karst cave, φ m S represents the matrix porosity. wmc S represents the matrix bound water saturation. wfc For the slit binding water saturation, S wvc To determine the water saturation level in the cave.

[0163] Specifically, when a certain amount of oil N is extracted from the reservoir p Subsequently, the reservoir pressure decreased from the original formation pressure to the current formation pressure, and the change in reservoir volume was calculated using formula (14):

[0164] ΔV=ΔV p +ΔV wc +ΔV g +W formula(14)

[0165] Wherein, △V is the change in reservoir volume, △Vp is the decrease in pore volume, △Vwc is the expansion of bound water, △Vg is the amount of gas stored in the reservoir, and W is the amount of water stored in the reservoir.

[0166] Alternatively, the reduction in pore volume can be determined in the following way:

[0167] The reduction in pore volume is determined based on the pore volume, pore compressibility coefficient, the first pressure of crude oil under current conditions, and the second pressure of crude oil under original conditions.

[0168] In this embodiment, the difference between the second pressure of crude oil under the original conditions and the first pressure of crude oil under the current conditions is calculated to obtain the pressure difference. The pore volume, pore compressibility coefficient, and pressure difference are substituted into formula (15) to calculate and determine the reduction in pore volume. Formula (15) is expressed as:

[0169] ΔV p =V p ×C p ×Δp formula (15)

[0170] Where ΔVp is the decrease in pore volume, V p For the volume of the pore, C p Δp is the pore compressibility coefficient, and Δp is the pressure difference.

[0171] Alternatively, the amount of bound water expansion is determined in the following way:

[0172] The expansion amount of bound water is determined based on the volume of bound water, the water compressibility coefficient, the first pressure of crude oil under the current conditions, and the second pressure of crude oil under the original conditions.

[0173] In this embodiment, the difference between the second pressure of crude oil under the original conditions and the first pressure of crude oil under the current conditions is calculated to obtain the pressure difference. The bound water volume, water compressibility coefficient, and pressure difference are substituted into formula (16) to calculate and determine the bound water expansion amount. Formula (16) is expressed as:

[0174] ΔV wc =V wc ×C w ×Δp formula (16)

[0175] Where △Vwc is the expansion amount of bound water, V wc To bind the water volume, C w Let be the water compressibility coefficient, and Δp be the pressure difference.

[0176] Alternatively, the gas reserves in the reservoir can be expressed as:

[0177] ΔV g =N×(R) si -R s )×B g -N p ×(R p -R s )×B g Formula (17)

[0178] Where △Vg represents the gas reserves in the reservoir, N represents the reserves of the fractured-vuggy reservoir, and R... si R represents the second dissolved gas-oil ratio of crude oil under the original conditions. s B represents the first dissolved gas-oil ratio of crude oil under current conditions. g N is the gas volume coefficient. p R represents the amount of oil produced from the reservoir. p The cumulative gas-oil ratio of the reservoir.

[0179] Alternatively, the reservoir water content can be expressed as:

[0180] W = V w C w Δp+V w C p Δp-W p B w Formula (18)

[0181] Where W represents the reservoir water volume, and V w C represents the water volume corresponding to a fractured-vuggy oil reservoir. w C is the water compressibility coefficient, Δp is the pressure difference, and C is the pressure coefficient. p W is the porosity compressibility coefficient.p For cumulative water production, B w This is the water volume coefficient.

[0182] Optionally, the change in reservoir volume can be obtained using formulas (1)-(3) and (10)-(18):

[0183]

[0184] Alternatively, under the current conditions, the reservoir volume can be expressed as:

[0185] V c =V ci -ΔV Formula (20)

[0186] Among them, V c Vci represents the reservoir volume under current conditions, Vci represents the reservoir volume under original conditions, and ΔV represents the change in reservoir volume.

[0187] Specifically, based on the material balance relationship: the original oil volume equals the sum of the produced oil volume and the remaining oil volume, the material balance equation for fractured-vuggy reservoirs is obtained from the above formula as follows:

[0188] N p [B o +(R p -R s B g ]+W p B w =NB oi (C o +C c Formula (21) for Δp

[0189] Where, N p B represents the amount of oil produced from the reservoir. o R is the first crude oil volume factor under current conditions. p R is the cumulative gas-oil production ratio of the reservoir. s B represents the first dissolved gas-oil ratio of crude oil under current conditions. g W is the gas volume coefficient. p For cumulative water production, B w Where is the water volume factor, N is the reservoir capacity of the fractured-vuggy oil reservoir, and B is the water volume factor. oi C is the second crude oil volume factor of crude oil under the original conditions. o is the two-phase compressibility coefficient, and Cc is the overall reservoir compressibility coefficient.

[0190] The two-phase compressibility coefficient is expressed as:

[0191]

[0192] Among them, C o B is the two-phase compressibility coefficient.o R is the first crude oil volume factor under current conditions. si R represents the second dissolved gas-oil ratio of crude oil under the original conditions. s B represents the first dissolved gas-oil ratio of crude oil under current conditions. g B is the gas volume coefficient. oi Δp is the second crude oil volume coefficient under the original conditions, and Δp is the pressure difference.

[0193] Let: Y = N p [B o +(R p -R s B g ]+W p B w X = B oi (C o +C c )Δp, Formula (21)

[0194] It can be represented as:

[0195] Y=NX formula (23)

[0196] Furthermore, the equations were verified by substituting production dynamic data into Y and X, and plotting the Y-X reservoir material balance analysis curve as a straight line passing through the origin. A trial-and-error method was used to determine the water volume ratio, while simultaneously adjusting the dynamic reserves. Based on the adjusted dynamic reserves, the water volume ratio was recalculated, and the above process was repeated until the convergence condition was met. Further, different water volume ratios were used for fitting, specifically: 20 times water volume for single-fractured caverns, 50 times water volume for single-fractured caverns, 10 times water volume for multi-fractured caverns, and 100 times water volume for multi-fractured caverns. The fitting results for single-fractured and multi-fractured caverns with different water volume ratios are shown below. Figures 7-10 As shown, Figure 7 This is a schematic diagram of the fitting results of a single-slit hole with a water volume of 20 times. Figure 8 This is a schematic diagram of the fitting results of a single-slit hole with a water volume of 50 times. Figure 9 This is a schematic diagram of the fitting results of a 10-fold water volume with multiple pores. Figure 10 This is a schematic diagram of the fitting results for a fractured-vuggy reservoir with a water volume of 100 times. Combining the experimental results of the reservoir utilization evaluation with different water volume multiples, the experimental data were fitted using the established material balance equation for fractured-vuggy reservoirs. The fitting results are in good agreement with the experimental results, and the fitted water volume multiples and reserves are consistent with the experimental results, indicating that the established equation is reliable.

[0197] The method for determining the reserves of fractured-vuggy oil reservoirs provided in this application comprehensively considers various factors of the reservoir and fluid in fractured-vuggy oil reservoirs, as well as the effects of external water bodies. It establishes a material balance equation for fractured-vuggy oil reservoirs that includes three media: matrix, fractures, and caverns. This provides a basis for calculating the dynamic reserves of fractured-vuggy volatile oil reservoirs and can obtain relatively accurate reserves.

[0198] Figure 11 This is a schematic diagram of the structure of the device for determining the reserves of fractured-vuggy oil reservoirs provided in the embodiments of this application, as shown below. Figure 11 As shown, the apparatus 110 for determining the reserves of fractured-vuggy oil reservoirs provided in this embodiment includes:

[0199] The acquisition unit 1101 is used to acquire, at preset time intervals, the current data of crude oil under the current conditions, the original data of crude oil under the original conditions, the porosity of the vault, the porosity of the fracture, and the matrix porosity of the corresponding fractured-vuggy reservoir. The processing unit 1102 is used to determine the comprehensive compressibility coefficient of the reservoir based on the vault porosity, fracture porosity, and matrix porosity. The processing unit 1102 is also used to determine the reserves of the fractured-vuggy reservoir based on the current data of crude oil under the current conditions, the original data of crude oil under the original conditions, and the comprehensive compressibility coefficient of the reservoir; wherein, the current data includes: reservoir produced oil volume, the first dissolved gas-oil ratio of crude oil under the current conditions, the cumulative produced gas-oil ratio of the reservoir, water production, the first crude oil volume factor of crude oil under the current conditions, and the first pressure of crude oil under the current conditions; the original data includes: the second crude oil volume factor of crude oil under the original conditions and the second pressure of crude oil under the original conditions.

[0200] In one possible implementation, the acquisition unit 1101 is further configured to acquire the pore compressibility coefficient, fracture-bound water saturation, matrix-bound water saturation, cavity-bound water saturation, and water compressibility coefficient. The processing unit 1102 is further configured to determine the reservoir's overall compressibility coefficient based on the pore compressibility coefficient, fracture-bound water saturation, matrix-bound water saturation, cavity-bound water saturation, water compressibility coefficient, cavern porosity, fracture porosity, and matrix porosity.

[0201] In one possible implementation, the processing unit 1102 is further configured to calculate reservoir values ​​based on reservoir produced oil volume, first crude oil volume factor, reservoir cumulative gas-oil ratio, first dissolved gas-oil ratio, gas volume factor, water production, water volume factor, second crude oil volume factor, reservoir comprehensive compressibility factor, two compressibility factors, first pressure and second pressure; and determine the reserves of fractured-vuggy reservoirs based on the reservoir values.

[0202] In one possible implementation, the processing unit 1102 is further configured to calculate the first reservoir value based on the reservoir produced oil volume, the first crude oil volume factor, the reservoir cumulative gas-oil ratio, the first dissolved gas-oil ratio, the gas volume factor, the water production volume, and the water volume factor.

[0203] The values ​​for the second reservoir are calculated based on the second crude oil volume factor, the reservoir comprehensive compressibility factor, the two compressibility factors, the first pressure, and the second pressure.

[0204] Substituting the values ​​of the first and second reservoirs into the material balance equation for fractured-vuggy reservoirs, the reserves of the fractured-vuggy reservoirs are calculated. The material balance equation for fractured-vuggy reservoirs is expressed as follows:

[0205] Y = NX

[0206] Where Y represents the value of the first reservoir, N represents the reserves of the fractured-vuggy reservoir, and X represents the value of the second reservoir.

[0207] In one possible implementation, the processing unit 1102 is further configured to determine two compressibility coefficients based on the first crude oil volume coefficient, the second dissolved gas-oil ratio, the first dissolved gas-oil ratio, the gas volume coefficient, the second crude oil volume coefficient, the first pressure, and the second pressure.

[0208] In one possible implementation, the acquisition unit 1101 is further configured to acquire the volume of the karst cave, the volume of the fissure, the volume of the matrix pores, and the volume of the rock under the original conditions. The processing unit 1102 is further configured to calculate the karst cave porosity based on the karst cave volume and the volume of the rock under the original conditions, calculate the fissure porosity based on the fissure volume and the volume of the rock under the original conditions, and calculate the matrix porosity based on the karst cave porosity, the fissure porosity, and the volume of the rock under the original conditions.

[0209] In one possible implementation, the processing unit 1102 is further configured to determine the water multiple corresponding to the reserves of the fractured-vuggy reservoir based on the reserves and water multiple of the fractured-vuggy reservoir and the corresponding relationship between the reserves.

[0210] In one possible implementation, the processing unit 1102 is also used to calculate the pressure of water on the formation based on the reserves and production data of the fractured-vuggy reservoir.

[0211] The apparatus for determining the reserves of fractured-vuggy oil reservoirs provided in this embodiment can execute the method provided in the above-described method embodiment. Its implementation principle and technical effect are similar, and will not be described in detail here.

[0212] Figure 12 This is a schematic diagram of the structure of an electronic device provided in an embodiment of this application. Figure 12 As shown, the electronic device 120 provided in this embodiment includes at least one processor 1201 and a memory 1202. Optionally, the device 120 further includes a communication component 1203. The processor 1201, the memory 1202, and the communication component 1203 are connected via a bus 1204.

[0213] In a specific implementation, at least one processor 1201 executes computer execution instructions stored in memory 1202, causing at least one processor 1201 to perform the above-described method.

[0214] The specific implementation process of processor 1201 can be found in the above method embodiments, and its implementation principle and technical effect are similar. It will not be repeated here.

[0215] In the above embodiments, it should be understood that the processor can be a Central Processing Unit (CPU), or other general-purpose processors, digital signal processors (DSPs), application-specific integrated circuits (ASICs), etc. The general-purpose processor can be a microprocessor or any conventional processor. The steps of the method disclosed in this invention can be directly implemented by a hardware processor, or implemented by a combination of hardware and software modules within the processor.

[0216] The memory may include random access memory (RAM) and may also include non-volatile memory (NVM), such as at least one disk storage device.

[0217] The bus can be an Industry Standard Architecture (ISA) bus, a Peripheral Component Interconnect (PCI) bus, or an Extended Industry Standard Architecture (EISA) bus, etc. Buses can be categorized as address buses, data buses, control buses, etc. For ease of illustration, the buses shown in the accompanying drawings are not limited to a single bus or a single type of bus.

[0218] This application also provides a computer program product, including a computer program that, when executed by a processor, implements the above-described method.

[0219] This application also provides a computer-readable storage medium storing computer-executable instructions, which, when executed by a processor, implement the above-described method.

[0220] The aforementioned readable storage medium can be implemented by any type of volatile or non-volatile storage device or a combination thereof, such as static random access memory (SRAM), electrically erasable programmable read-only memory (EEPROM), erasable programmable read-only memory (EPROM), programmable read-only memory (PROM), read-only memory (ROM), magnetic storage, flash memory, magnetic disk, or optical disk. The readable storage medium can be any available medium accessible to a general-purpose or special-purpose computer.

[0221] An exemplary readable storage medium is coupled to a processor, enabling the processor to read information from and write information to the readable storage medium. Of course, the readable storage medium can also be a component of the processor. The processor and the readable storage medium can reside in an Application Specific Integrated Circuit (ASIC). Alternatively, the processor and the readable storage medium can exist as discrete components in the device.

[0222] The division of units is merely a logical functional division; in actual implementation, there may be other division methods. For example, multiple units or components may be combined or integrated into another system, or some features may be ignored or not executed. Furthermore, the coupling or direct coupling or communication connection shown or discussed may be indirect coupling or communication connection through some interfaces, devices, or units, and may be electrical, mechanical, or other forms.

[0223] The units described as separate components may or may not be physically separate. The components shown as units may or may not be physical units; that is, they may be located in one place or distributed across multiple network units. Some or all of the units can be selected to achieve the purpose of this embodiment according to actual needs.

[0224] In addition, the functional units in the various embodiments of the present invention can be integrated into one processing unit, or each unit can exist physically separately, or two or more units can be integrated into one unit.

[0225] If a function is implemented as a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of this invention, or the part that contributes to the prior art, or a part of the technical solution, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute all or part of the steps of the methods of the various embodiments of this invention. The aforementioned storage medium includes various media capable of storing program code, such as USB flash drives, portable hard drives, read-only memory (ROM), random access memory (RAM), magnetic disks, or optical disks.

[0226] Those skilled in the art will understand that all or part of the steps of the above-described method embodiments can be implemented by hardware related to program instructions. The aforementioned program can be stored in a computer-readable storage medium. When executed, the program performs the steps of the above-described method embodiments; and the aforementioned storage medium includes various media capable of storing program code, such as ROM, RAM, magnetic disks, or optical disks.

[0227] Finally, it should be noted that other embodiments of the invention will readily occur to those skilled in the art upon consideration of the specification and practice of the invention disclosed herein. This invention is intended to cover any variations, uses, or adaptations of the invention that follow the general principles of the invention and include common knowledge or customary techniques in the art not disclosed herein, and is not limited to the precise structures described above and shown in the accompanying drawings, and various modifications and changes can be made without departing from its scope. The scope of the invention is limited only by the appended claims.

Claims

1. A method for determining the reserves of fractured-vuggy oil reservoirs, characterized in that, include: At preset intervals, acquire current data of crude oil under current conditions, original data of crude oil under original conditions, cavern porosity, fracture porosity, and matrix porosity corresponding to fractured-vuggy reservoirs; The overall compressibility coefficient of the reservoir is determined based on the porosity of the karst caves, the porosity of the fractures, and the porosity of the matrix. Based on the current data of crude oil under the current conditions, the original data of crude oil under the original conditions, and the comprehensive compressibility coefficient of the reservoir, the reserves of the fractured-vuggy reservoir are determined. The current data includes: oil production from the reservoir, the first dissolved gas-oil ratio of crude oil under current conditions, the cumulative gas-oil production ratio of the reservoir, water production, the first crude oil volume factor of crude oil under current conditions, and the first pressure of crude oil under current conditions; the original data includes: the second crude oil volume factor of crude oil under original conditions and the second pressure of crude oil under original conditions.

2. The method according to claim 1, characterized in that, The determination of the reservoir's overall compressibility coefficient based on the cavern porosity, fracture porosity, and matrix porosity includes: Obtain the pore compressibility coefficient, fracture water saturation, matrix water saturation, cavity water saturation, and water compressibility coefficient; The overall compressibility coefficient of the reservoir is determined based on the porosity compressibility coefficient, the fracture-bound water saturation, the matrix-bound water saturation, the cavity-bound water saturation, the water compressibility coefficient, the cavern porosity, the fracture porosity, and the matrix porosity.

3. The method according to claim 1, characterized in that, The step of determining the reserves of fractured-vuggy reservoirs based on current crude oil data under the current conditions, original crude oil data under the original conditions, and the reservoir's comprehensive compressibility coefficient includes: The reservoir values ​​are calculated based on the oil production, the first crude oil volume factor, the cumulative gas-oil ratio produced by the reservoir, the first dissolved gas-oil ratio, the gas volume factor, the water production, the water volume factor, the second crude oil volume factor, the reservoir comprehensive compressibility factor, two compressibility factors, the first pressure, and the second pressure. The reserves of the fractured-vuggy reservoir are determined based on the reservoir data.

4. The method according to claim 3, characterized in that, The reservoir values ​​include: first reservoir values ​​and second reservoir values; The calculation of reservoir values ​​based on the reservoir's produced oil volume, the first crude oil volume factor, the reservoir's cumulative produced gas-oil ratio, the first dissolved gas-oil ratio, the gas volume factor, the water production, the water volume factor, the second crude oil volume factor, the reservoir's comprehensive compressibility factor, two compressibility factors, the first pressure, and the second pressure includes: The values ​​of the first oil reservoir are calculated based on the oil production, the first crude oil volume factor, the cumulative gas-oil ratio of the oil reservoir, the first dissolved gas-oil ratio, the gas volume factor, the water production, and the water volume factor. The second reservoir value is calculated based on the second crude oil volume factor, the reservoir comprehensive compressibility factor, two compressibility factors, the first pressure, and the second pressure.

5. The method according to claim 4, characterized in that, Determining the reserves of the fractured-vuggy reservoir based on the reservoir data includes: Substituting the first reservoir value and the second reservoir value into the material balance equation for fractured-vuggy reservoirs, the reserves of the fractured-vuggy reservoirs are calculated. The material balance equation for fractured-vuggy reservoirs is expressed as follows: Y = NX Wherein, Y is the value of the first reservoir, N is the reserve of the fractured-vuggy reservoir, and X is the value of the second reservoir.

6. The method according to claim 3, characterized in that, The original data for crude oil under the original conditions include: the second dissolved gas-oil ratio of crude oil under the original conditions; the two compressibility coefficients are determined in the following way: The two compressibility coefficients are determined based on the first crude oil volume coefficient, the second dissolved gas-oil ratio, the first dissolved gas-oil ratio, the gas volume coefficient, the second crude oil volume coefficient, the first pressure, and the second pressure.

7. The method according to any one of claims 1 to 6, characterized in that, The porosity of the karst caves, the porosity of the fractures, and the porosity of the matrix are obtained through the following methods: Obtain the volume of the cavern, the volume of the fissures, the volume of the matrix pores, and the volume of the rock under the original conditions; The porosity of the karst cave is calculated based on the volume of the karst cave and the volume of the rock under the original conditions. The porosity of the crack is calculated based on the volume of the crack and the volume of the rock under the original conditions. The porosity of the matrix is ​​calculated based on the porosity of the karst cave, the porosity of the crack, and the volume of the rock under the original conditions.

8. The method according to any one of claims 1 to 6, characterized in that, Also includes: Based on the relationship between the reserves and water volume ratio of the fractured-vuggy oil reservoir and the reserves, the water volume ratio corresponding to the reserves of the fractured-vuggy oil reservoir is determined.

9. The method according to claim 1, characterized in that, Also includes: The pressure of water on the formation is calculated based on the reserves of the fractured-vuggy oil reservoir and the production data.

10. A device for determining the reserves of fractured-vuggy oil reservoirs, characterized in that, include: The acquisition unit is used to acquire, at preset intervals, the current data of crude oil under the current conditions, the original data of crude oil under the original conditions, the porosity of the vault, the porosity of the fracture, and the matrix porosity of the crude oil in the fractured-vuggy reservoir. The processing unit is used to determine the overall compressibility coefficient of the reservoir based on the porosity of the karst caves, the porosity of the fractures, and the porosity of the matrix. The processing unit is also used to determine the reserves of fractured-vuggy reservoirs based on the current data of crude oil under the current conditions, the original data of crude oil under the original conditions, and the comprehensive compressibility coefficient of the reservoir. The current data includes: oil production from the reservoir, the first dissolved gas-oil ratio of crude oil under current conditions, the cumulative gas-oil production ratio of the reservoir, water production, the first crude oil volume factor of crude oil under current conditions, and the first pressure of crude oil under current conditions; the original data includes: the second crude oil volume factor of crude oil under original conditions and the second pressure of crude oil under original conditions.

11. An electronic device, characterized in that, include: Memory, processor; The memory stores computer-executed instructions; The processor executes computer execution instructions stored in the memory, causing the processor to perform the method as described in any one of claims 1 to 7.

12. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores computer-executable instructions, which, when executed by a processor, are used to implement the method as described in any one of claims 1 to 7.

13. A computer program product comprising a computer program that, when executed by a processor, implements the method of any one of claims 1 to 7.

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