Method, device and equipment for determining water volume of fracture-vug type carbonate rock and storage medium

Abstract

The invention discloses a method, a device and equipment for determining the volume of a water body of fracture-vug type carbonate rock and a storage medium. The method comprises the steps that oil reservoir exploitation associated data of the fracture-vuggy carbonate rock is collected, the fracture-vuggy carbonate rock comprises an oil storage space, and the oil storage space at least comprises crude oil and water; based on the oil reservoir exploitation associated data and a pre-constructed target production function, the water volume of the fracture-vuggy carbonate rock is determined, and the target production function is used for representing the linear logic relation between the oil reservoir exploitation associated data and the water volume. And the accuracy of determining the water volume of the fracture-vuggy carbonate rock is improved.

Description

Methods, apparatus, equipment, and storage media for determining the water volume in fractured-cavity carbonate rocks. Technical Field

[0001] This invention relates to the field of fractured-vuggy carbonate reservoir development technology, and in particular to a method, apparatus, equipment and storage medium for determining the water volume of fractured-vuggy carbonate reservoirs. Background Technology

[0002] Fractured-vuggy carbonate reservoirs are characterized by reservoir spaces consisting mainly of fractures and caverns due to tectonic deformation and karstification.

[0003] Compared to conventional sandstone reservoirs, these reservoirs exhibit poor reservoir continuity, complex oil-water relationships, and difficulty in determining water energy levels. The internal oil-bearing space of fractured-vuggy carbonate reservoirs is primarily composed of caverns, while fluid transport channels are mainly fractures. Fractured-vuggy carbonate reservoirs exhibit strong heterogeneity and scale in the development of fractures and caverns, leading to rapid decline in well productivity. Due to the deep burial, complex reservoir structure, and poor fault distribution of carbonate reservoirs, calculating reservoir reserves and water volume using static methods such as seismic analysis is challenging. Existing methods for calculating dynamic reserves and water volume in fractured-vuggy carbonate reservoirs have low accuracy. Summary of the Invention

[0004] This invention provides a method, apparatus, equipment, and storage medium for determining the water volume of fractured-cavity carbonate rocks, in order to solve the problem of low accuracy in calculating the water volume of fractured-cavity carbonate rocks.

[0005] According to one aspect of the present invention, a method for determining the water volume of fractured carbonate rocks is provided, the method comprising:

[0006] Collect oil reservoir development correlation data of fractured-vuggy carbonate rocks, wherein the fractured-vuggy carbonate rocks include oil-bearing spaces, and the oil-bearing spaces include at least crude oil and water bodies;

[0007] The water volume of the fractured-vuggy carbonate rock is determined based on the oil reservoir production correlation data and a pre-constructed target production function, wherein the target production function is used to characterize the linear logical relationship between the oil reservoir production correlation data and the water volume.

[0008] According to another aspect of the present invention, a device for determining the water volume of fractured carbonate rocks is provided, the device comprising:

[0009] The data acquisition module is used to collect oil reservoir development-related data of fractured-vuggy carbonate rocks, wherein the fractured-vuggy carbonate rocks include oil-bearing spaces, and the oil-bearing spaces include at least crude oil and water.

[0010] The water volume determination module is used to determine the water volume of the fractured-vuggy carbonate rock based on the oil reservoir production association data and a pre-constructed target production function, wherein the target production function is used to characterize the linear logical relationship between the oil reservoir production association data and the water volume.

[0011] According to another aspect of the present invention, an electronic device is provided, the electronic device comprising:

[0012] At least one processor; and

[0013] A memory communicatively connected to the at least one processor; wherein,

[0014] The memory stores a computer program that can be executed by the at least one processor, which enables the at least one processor to perform the method for determining the water volume of fractured carbonate rocks according to any embodiment of the present invention.

[0015] According to another aspect of the present invention, a computer-readable storage medium is provided, the computer-readable storage medium storing computer instructions for causing a processor to execute and implement the method for determining the water volume of fractured carbonate rocks according to any embodiment of the present invention.

[0016] The technical solution of this invention collects oil reservoir development correlation data of fractured-vuggy carbonate rocks, wherein the fractured-vuggy carbonate rocks include oil storage space, and the oil storage space includes at least crude oil and water. Based on the oil reservoir development correlation data and a pre-constructed target production function, the water volume of the fractured-vuggy carbonate rocks is determined. The target production function is used to characterize the linear logical relationship between the oil reservoir development correlation data and the water volume. This solves the problem of low accuracy in calculating the water volume of fractured-vuggy carbonate rocks and achieves the beneficial effect of improving the accuracy of water volume calculation for fractured-vuggy carbonate rocks.

[0017] It should be understood that the description in this section is not intended to identify key or essential features of the embodiments of the present invention, nor is it intended to limit the scope of the invention. Other features of the invention will become readily apparent from the following description. Attached Figure Description

[0018] To more clearly illustrate the technical solutions in the embodiments of the present invention, the accompanying drawings used in the description of the embodiments will be briefly introduced below. Obviously, the accompanying drawings described below are only some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0019] Figure 1 is a flowchart of a method for determining the water volume of a fractured carbonate rock according to Embodiment 1 of the present invention;

[0020] Figure 2a is a flowchart of a method for determining the water volume of a fractured carbonate rock according to Embodiment 2 of the present invention;

[0021] Figure 2b is a schematic diagram of a fractured model of an optional example of a method for determining the water volume of fractured carbonate rocks according to Embodiment 2 of the present invention.

[0022] Figure 2c is a schematic diagram of the initial state of an oil reservoir, representing an optional example of a method for determining the water volume in a fractured-vuggy carbonate rock according to Embodiment 2 of the present invention.

[0023] Figure 2d is a schematic diagram of a sample of pre-water reservoir development, which is an optional example of a method for determining the water volume of fractured carbonate rocks according to Embodiment 2 of the present invention.

[0024] Figure 2e is a schematic diagram of a sample of post-water-spot reservoir development, representing an optional example of a method for determining the water volume in fractured-vuggy carbonate rocks according to Embodiment 2 of the present invention.

[0025] Figure 3 is a schematic diagram of a device for determining the water volume of a fractured carbonate rock according to Embodiment 3 of the present invention.

[0026] Figure 4 is a schematic diagram of the electronic device for implementing the method for determining the water volume of fractured carbonate rocks according to an embodiment of the present invention. Detailed Implementation

[0027] To enable those skilled in the art to better understand the present invention, the technical solutions of the present invention will be clearly and completely described below with reference to the accompanying drawings of the embodiments of the present invention. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort should fall within the scope of protection of the present invention.

[0028] It should be noted that the terms "first," "second," etc., in the specification, claims, and accompanying drawings of this invention are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments of the invention described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover a non-exclusive inclusion; for example, a process, method, system, product, or apparatus that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or apparatus.

[0029] Example 1

[0030] Figure 1 is a flowchart of a method for determining the water volume of fractured-cavity carbonate rocks according to Embodiment 1 of the present invention. This embodiment is applicable to the determination of water volume in fractured-cavity carbonate rocks. This method can be executed by a device for determining the water volume of fractured-cavity carbonate rocks. This device can be implemented in hardware and / or software and can be configured in an electronic device. As shown in Figure 1, the method includes:

[0031] S110. Collect oil reservoir development correlation data of fractured-vuggy carbonate rocks, wherein the fractured-vuggy carbonate rocks include oil storage space, and the oil storage space includes at least crude oil and water.

[0032] Fractured-vuggy carbonate rocks can be understood as rocks composed of carbonate minerals with numerous fractures and caverns inside. Oil reservoir development-related data can be understood as data obtained from the extraction of oil from fractured-vuggy carbonate rock reservoirs.

[0033] Specifically, the oil-bearing space in fractured-vuggy carbonate reservoirs mainly consists of large caverns and connected fracture zones. A three-dimensional model of the fractured-vuggy carbonate reservoir is constructed, dividing it into a fracture system and a cavern system. The cavern system is the primary oil-bearing space, while the fracture system serves as the radial flow channels. During reservoir development, crude oil in the reservoirs releases elastic energy and flows to the well bottom through the fracture flow channels. During this process, changes in the flow system space due to formation pressure alter the crude oil flow pattern.

[0034] Optionally, the reservoir correlation data includes at least one of the following: cumulative oil production before water breakthrough, water volume coefficient, water compressibility coefficient, water viscosity, water phase permeability, oil phase permeability, reservoir thickness, crude oil viscosity, fracture radius, well radius, crude oil compressibility coefficient, crude oil volume coefficient, initial formation pressure, and bottom hole flowing pressure.

[0035] S120. Determine the water volume of the fractured-vuggy carbonate rock based on the oil reservoir production correlation data and the pre-constructed target production function, wherein the target production function is used to characterize the linear logical relationship between the oil reservoir production correlation data and the water volume.

[0036] The water volume can be understood as the total volume of groundwater stored in the oil reservoir.

[0037] Specifically, by constructing a target production function that reflects the actual oil reservoir exploitation situation, the collected oil reservoir exploitation-related data are input into the target production function, and the water volume is calculated based on the target production function.

[0038] Optionally, the target production function can be represented by the following formula:

[0039]

[0040] Where p is the cavern pressure, p w For the bottom hole flowing pressure, p i C is the initial reservoir pressure. o C is the compressibility coefficient of crude oil. f Let W be the rock compressibility coefficient, W be the water volume, and B be the water volume. oi R is the crude oil volume coefficient. e R is the crack radius. w Let μ be the well radius. o The viscosity of crude oil is μ. w K represents the viscosity of water. ro K represents the oil phase permeability after water exposure. rw N represents the aqueous phase permeability after water exposure. p This represents the cumulative oil production before water exposure.

[0041] It is worth noting that the rock compressibility coefficient was determined based on seepage channel volume change data, seepage volume data, and pressure difference data across the seepage channel. The seepage volume data was determined based on the initial reservoir thickness data.

[0042] The technical solution of this invention collects oil reservoir development correlation data of fractured-vuggy carbonate rocks, wherein the fractured-vuggy carbonate rocks include oil storage space, and the oil storage space includes at least crude oil and water. Based on the oil reservoir development correlation data and a pre-constructed target production function, the water volume of the fractured-vuggy carbonate rocks is determined. The target production function is used to characterize the linear logical relationship between the oil reservoir development correlation data and the water volume. This solves the problem of low accuracy in calculating the water volume of fractured-vuggy carbonate rocks and achieves the beneficial effect of improving the accuracy of water volume calculation for fractured-vuggy carbonate rocks.

[0043] Example 2

[0044] Figure 2a is a flowchart of a method for determining the water volume of fractured-vuggy carbonate rocks according to Embodiment 2 of the present invention. This embodiment is a further refinement of the above embodiments. Optionally, before determining the water volume before water seepage in the oil reservoir based on the reservoir production correlation data and a pre-constructed target production function, the method further includes: determining the water volume after water seepage in the oil reservoir based on the reservoir production correlation data and a second production function, and constructing the target production function based on the water volume after water seepage in the oil reservoir and a first production function.

[0045] As shown in Figure 2a, the method includes:

[0046] S210. Collect oil reservoir development correlation data of fractured-vuggy carbonate rocks, wherein the fractured-vuggy carbonate rocks include oil storage space, and the oil storage space includes at least crude oil and water.

[0047] S220. Determine the water volume after water seepage in the oil reservoir space based on the oil reservoir development correlation data and the second production function, and construct the target production function based on the water volume after water seepage in the oil reservoir space and the first production function.

[0048] The first production function can be understood as the production function before water seepage in the oil storage space. The second production function can be understood as the production function after water seepage in the oil storage space.

[0049] Specifically, a first production function is constructed before water exposure in the oil reservoir, and a second production function is constructed after water exposure. Based on reservoir development correlation data and the second production function, the water volume after water exposure in the oil reservoir is determined. The water volume after water exposure is then substituted into the first production function to obtain the target production function.

[0050] For example, the effect of rock compressibility on seepage channels during development can be translated into changes in reservoir thickness:

[0051]

[0052] Among them, C f is the rock compressibility coefficient, and is the pressure difference between the two ends of the seepage channel.

[0053] After simplification, we get:

[0054] h'=h(1-C f Δp)

[0055] Where h' is the dynamic reservoir thickness.

[0056] For example, considering the variation of seepage channels with the rock compressibility coefficient, a description of fracture seepage behavior is carried out based on Darcy's law.

[0057]

[0058] Where q is the bottom hole flow rate; K is the reservoir permeability; μ is the fluid viscosity; R e R is the crack radius; w Where is the well radius.

[0059] The first production function and the second production function are constructed based on the fracture seepage law and the oil reservoir development correlation data, respectively.

[0060] For example, in the initial development stage before water is observed in an oil reservoir, the natural energy for reservoir development consists of the expansion energy of crude oil and the expansion energy of water. At this time, no water has been observed in the reservoir, and the fracture seepage channels are entirely composed of crude oil, with the oil-water interface trending upwards. The elastic expansion of the rock causes the thickness of the seepage channels to decrease, resulting in a reduction in seepage capacity.

[0061] Optionally, the first production function can be expressed by the following formula:

[0062]

[0063] Where p is the cavern pressure, p w For bottom hole flowing pressure, C represents the change in pressure within the oil storage cavity over production time. o C is the compressibility coefficient of crude oil. w Let W be the water compressibility coefficient, W be the water volume, and B be the water volume. wi B is the water volume coefficient. oi R is the crude oil volume coefficient. e R is the crack radius. w Let K be the well radius, μ be the crude oil viscosity, and K be the crude oil viscosity. o C represents the oil phase permeability before water exposure. f denoted as the rock compressibility coefficient, and N represents the dynamic reserves of the reservoir before water exposure.

[0064] For example, the oil-water interface rises to the seepage channel, indicating water breakthrough in the reservoir. Oil and water share the same seepage channel; at this point, the energy for crude oil extraction is provided by the expansion energy of the crude oil, and the energy for formation water extraction is provided by the expansion energy of the water body. The thickness of the seepage channel continues to decrease due to the influence of the rock.

[0065] Optionally, the second production function is expressed by the following formula:

[0066]

[0067] Where p is the cavern pressure, p w For bottom hole flowing pressure, C represents the change in pressure within the oil storage cavity over production time. o C is the compressibility coefficient of crude oil. f Let W be the rock compressibility coefficient, W be the water volume, and B be the water volume. wi B is the water volume coefficient. oi R is the crude oil volume coefficient. e R is the crack radius. w Let μ be the well radius. o The viscosity of crude oil is μ. w K represents the viscosity of water. ro K represents the oil phase permeability after water exposure. rw N' represents the water phase permeability after water exposure, and N' represents the dynamic oil reservoir reserves after water exposure in the oil storage space.

[0068] Optionally, the second production function includes an oil phase production function and a water phase production function; determining the water volume after water seepage in the oil storage space based on the reservoir development correlation data and the second production function includes: determining the water volume after water seepage in the oil storage space based on the reservoir development correlation data, the oil phase production function and the water phase production function.

[0069] For example, dividing the oil phase production function by the water phase production function yields:

[0070]

[0071] Simplifying, we get the water volume ratio after water is seen:

[0072]

[0073] Where n' is the multiple of the water volume after the water is exposed.

[0074] The size of the water body can then be expressed as:

[0075]

[0076] The volume of water in the oil storage space after water is exposed is:

[0077]

[0078] S230. Determine the water volume of the fractured-vuggy carbonate rock based on the oil reservoir production correlation data and the pre-constructed target production function, wherein the target production function is used to characterize the linear logical relationship between the oil reservoir production correlation data and the water volume.

[0079] Optionally, determining the water volume of the fractured-vuggy carbonate rock based on the reservoir development correlation data and a pre-constructed target production function includes: obtaining the water volume after water exposure in the oil storage space; substituting the water volume after water exposure into the target production function to obtain the dynamic oil reservoir reserves before water exposure in the oil storage space; substituting the dynamic oil reservoir reserves before water exposure into the first production function to determine the water volume before water exposure in the oil storage space; and determining the water volume before water exposure in the oil storage space as the water volume of the fractured-vuggy carbonate rock.

[0080] For example, the volume of water after the oil storage space is exposed to water is substituted into the first production function:

[0081]

[0082] Simplifying, we get:

[0083]

[0084] Assuming constant pressure extraction at the bottom of the well, then p w =C is a constant, let pp w If x = , then the expression can be simplified to:

[0085]

[0086] Integrating both sides of the formula, we get:

[0087]

[0088] Where, x1 = pp w x0 = p i -p w

[0089] After integration and simplification, we get:

[0090]

[0091] Further simplification yields the target production function:

[0092]

[0093] The curve exponent b is obtained through curve fitting.

[0094] Determine the dynamic reserves of the oil reservoir before water exposure in the oil storage space:

[0095]

[0096] Then, substituting the dynamic reserves of the oil reservoir before water exposure into the first production function, the volume of water in the oil reservoir before water exposure is determined as follows:

[0097]

[0098] The technical solution of this invention determines the water volume after water breakthrough in the reservoir space based on the reservoir development correlation data and a second production function, and constructs the target production function based on the water volume after water breakthrough and the first production function. A target production function considering the dynamic changes of oil and gas seepage channels in fractured-vuggy carbonate reservoirs is established, transforming the influence of rock characteristics on seepage channels into an influence on reservoir height. This further restores the actual flow conditions of the reservoir and can deeply describe the internal laws of reservoir development.

[0099] As an optional example of Embodiment 1 of the present invention, the method for determining the water volume of fractured-cavity carbonate rocks in this embodiment specifically includes the following steps:

[0100] Step 1: Establish a fracture-vuggy carbonate reservoir model.

[0101] Figure 2b provides a schematic diagram of a fracture-vuggy model as an optional example of a method for determining the water volume in fractured-vuggy carbonate reservoirs. As shown in Figure 2b, this model divides fractured-vuggy carbonate reservoirs into a fracture system and a cavern system. The cavern system is the primary oil-bearing space, while the fracture system serves as the radial seepage channels. During reservoir development, crude oil in the storage space releases elastic energy and flows to the bottom of the well through the fracture seepage channels. During this process, changes in the seepage system space due to formation pressure alter the crude oil seepage pattern.

[0102] Figure 2c provides a schematic diagram of the initial state of an oil reservoir, representing an optional example of a method for determining the water volume in fractured-vuggy carbonate rocks. As shown in Figure 2c, crude oil has a low density; when it comes into contact with water, it will naturally float on the surface because its density is less than that of water.

[0103] Step 2: Define the fracture seepage law based on the rock compressibility coefficient.

[0104] Figure 2d provides a schematic diagram of a sample of pre-water-hidden reservoir development, representing an optional example of a method for determining the water volume in fractured-vuggy carbonate rocks. As shown in Figure 2d, during the pre-water-hidden development stage, the natural energy for reservoir development consists of the expansion energy of crude oil and the expansion energy of water. At this time, the reservoir has no water, and the fracture seepage channels are entirely composed of crude oil, with the oil-water interface trending upwards. The elastic expansion of the rock leads to a decrease in the thickness of the seepage channels and a reduction in seepage capacity.

[0105] For example, the effect of rock compressibility on seepage channels during development can be translated into changes in reservoir thickness:

[0106]

[0107] Among them, C f is the rock compressibility coefficient, and is the pressure difference between the two ends of the seepage channel.

[0108] After simplification, we get:

[0109] h'=h(1-C f Δp)

[0110] Where h' is the dynamic reservoir thickness.

[0111] For example, considering the variation of seepage channels with the rock compressibility coefficient, a description of fracture seepage behavior is carried out based on Darcy's law.

[0112]

[0113] Where q is the bottom hole flow rate; K is the reservoir permeability; μ is the fluid viscosity; R e R is the crack radius; w Where is the well radius.

[0114] Step 3: Construct the first production function.

[0115] The first production function is constructed based on fracture seepage patterns and reservoir development correlation data.

[0116] Figure 2e provides a schematic diagram of a sample of post-water breakthrough reservoir development, representing an optional example of a method for determining the water volume in fractured-vuggy carbonate rocks. As shown in Figure 2e, the oil-water interface rises to the seepage channel, indicating water breakthrough in the reservoir. Oil and water share the same seepage channel; at this point, the energy for crude oil extraction is provided by the expansion energy of the crude oil, and the energy for formation water extraction is provided by the expansion energy of the water body. The thickness of the seepage channel continues to decrease due to the influence of the rock.

[0117] For example, in the initial development stage before water is observed in an oil reservoir, the natural energy for reservoir development consists of the expansion energy of crude oil and the expansion energy of water. At this time, no water has been observed in the reservoir, and the fracture seepage channels are entirely composed of crude oil, with the oil-water interface trending upwards. The elastic expansion of the rock causes the thickness of the seepage channels to decrease, resulting in a reduction in seepage capacity.

[0118] Optionally, the first production function can be expressed by the following formula:

[0119]

[0120] Where p is the cavern pressure, p w For bottom hole flowing pressure, C represents the change in pressure within the oil storage cavity over production time. oC is the compressibility coefficient of crude oil. w Let W be the water compressibility coefficient, W be the water volume, and B be the water volume. wi B is the water volume coefficient. oi R is the crude oil volume coefficient. e R is the crack radius. w Let μ be the well radius. o K represents the viscosity of crude oil. o C represents the oil phase permeability before water exposure. f denoted as the rock compressibility coefficient, and N represents the dynamic reserves of the reservoir before water exposure.

[0121] Step 4: Construct the second production function.

[0122] The first production function is constructed based on fracture seepage patterns and reservoir development correlation data.

[0123] Optionally, the second production function includes an oil phase production function and a water phase production function; determining the water volume after water seepage in the oil storage space based on the reservoir development correlation data and the second production function includes: determining the water volume after water seepage in the oil storage space based on the reservoir development correlation data, the oil phase production function and the water phase production function.

[0124] For example, the oil-water interface rises to the seepage channel, indicating water breakthrough in the reservoir. Oil and water share the same seepage channel; at this point, the energy for crude oil extraction is provided by the expansion energy of the crude oil, and the energy for formation water extraction is provided by the expansion energy of the water body. The thickness of the seepage channel continues to decrease due to the influence of the rock.

[0125] Optionally, the second production function is expressed by the following formula:

[0126]

[0127] Where p is the cavern pressure, p w For bottom hole flowing pressure, C represents the change in pressure within the oil storage cavity over production time. o C is the compressibility coefficient of crude oil. f Let W be the rock compressibility coefficient, W be the water volume, and B be the water volume. wi B is the water volume coefficient. oi R is the crude oil volume coefficient. e R is the crack radius. w Let μ be the well radius. o The viscosity of crude oil is μ. w K represents the viscosity of water. ro K represents the oil phase permeability after water exposure. rw N' represents the water phase permeability after water exposure, and N' represents the dynamic oil reservoir reserves after water exposure in the oil storage space.

[0128] For example, dividing the oil phase production function by the water phase production function yields:

[0129]

[0130] Simplifying, we get the water volume ratio after water is seen:

[0131]

[0132] Where n' is the multiple of the water volume after the water is exposed.

[0133] The size of the water body can then be expressed as:

[0134]

[0135] The volume of water in the oil storage space after water is exposed is:

[0136]

[0137] Step 5: Construct the target production function.

[0138] The volume of water after water exposure in the oil reservoir is obtained. The volume of water after water exposure is substituted into the target production function to obtain the dynamic reserves of the oil reservoir before water exposure. The dynamic reserves of the oil reservoir before water exposure are substituted into the first production function to determine the volume of water before water exposure in the oil reservoir. The volume of water before water exposure in the oil reservoir is determined as the volume of water in the fractured-vuggy carbonate rock.

[0139] For example, the volume of water after the oil storage space is exposed to water is substituted into the first production function:

[0140]

[0141] Simplifying, we get:

[0142]

[0143] Assuming constant pressure extraction at the bottom of the well, then p w =C is a constant, let pp w If x = , then the expression can be simplified to:

[0144]

[0145] Integrating both sides of the formula, we get:

[0146]

[0147] Where, x1 = pp w x0 = p i -p w

[0148] After integration and simplification, we get:

[0149]

[0150] Further simplification yields the target production function:

[0151]

[0153] Where p is the cavern pressure, p w For the bottom hole flowing pressure, p i C is the initial reservoir pressure. o C is the compressibility coefficient of crude oil. f Let W be the rock compressibility coefficient, W be the water volume, and B be the water volume. oi R is the crude oil volume coefficient. e R is the crack radius. w Let μ be the well radius. o The viscosity of crude oil is μ. w K represents the viscosity of water. ro K represents the oil phase permeability after water exposure. rw N represents the aqueous phase permeability after water exposure. p This represents the cumulative oil production before water exposure.

[0154] Step 6: Determine the water volume of the fractured carbonate rock.

[0155] The volume of water after water exposure in the oil-bearing space is obtained. This volume is then substituted into the objective function to obtain the dynamic oil reservoir reserves before water exposure. Finally, this dynamic oil reservoir reserves before water exposure are substituted into the first production function to determine the volume of water before water exposure. This volume is then defined as the water volume of the fractured-vuggy carbonate rock.

[0156] Substituting the water volume after water exposure into the target production function using the following formula, the dynamic oil reservoir reserves before water exposure are obtained:

[0157]

[0158] Then, substituting the dynamic reserves of the oil reservoir before water exposure into the first production function, the volume of water in the oil reservoir before water exposure is determined as follows:

[0159]

[0160] The technical solution of this invention establishes a radial seepage model for fractured-vuggy carbonate reservoirs that considers the influence of rock compressibility coefficient on seepage channels. Combined with a reservoir fractured-vuggy combination model, the oil-water production material balance equations before and after water breakthrough are established, and a production indicator curve applicable to water-bearing fractured-vuggy carbonate reservoirs is derived. Based on the dynamic production data before water breakthrough, the dynamic reserves of the reservoir and the rock compressibility coefficient are calculated, thereby clarifying the water volume and improving the accuracy of water volume calculation.

[0161] Example 3

[0162] Figure 3 is a schematic diagram of a device for determining the water volume of fractured carbonate rocks according to Embodiment 3 of the present invention. As shown in Figure 3, the device includes a data acquisition module 310 and a water volume determination module 320.

[0163] The data acquisition module 310 is used to acquire oil reservoir development-related data of fractured-vuggy carbonate rocks, wherein the fractured-vuggy carbonate rocks include oil storage space, and the oil storage space includes at least crude oil and water. The water volume determination module 320 is used to determine the water volume of the fractured-vuggy carbonate rocks based on the oil reservoir development-related data and a pre-constructed target production function, wherein the target production function is used to characterize the linear logical relationship between the oil reservoir development-related data and the water volume.

[0164] The technical solution of this invention collects oil reservoir development correlation data of fractured-vuggy carbonate rocks, wherein the fractured-vuggy carbonate rocks include oil storage space, and the oil storage space includes at least crude oil and water. Based on the oil reservoir development correlation data and a pre-constructed target production function, the water volume of the fractured-vuggy carbonate rocks is determined. The target production function is used to characterize the linear logical relationship between the oil reservoir development correlation data and the water volume. This solves the problem of low accuracy in calculating the water volume of fractured-vuggy carbonate rocks and achieves the beneficial effect of improving the accuracy of water volume calculation for fractured-vuggy carbonate rocks.

[0165] Optionally, the reservoir correlation data includes at least one of the following: cumulative oil production before water breakthrough, water volume coefficient, water compressibility coefficient, water viscosity, water phase permeability, oil phase permeability, reservoir thickness, crude oil viscosity, fracture radius, well radius, crude oil compressibility coefficient, crude oil volume coefficient, initial formation pressure, and bottom hole flowing pressure.

[0166] Optional, water volume determination module, specifically used for:

[0167] The target production function is expressed by the following formula:

[0168]

[0169] Where p is the cavern pressure, p w For the bottom hole flowing pressure, p i C is the initial reservoir pressure. o C is the compressibility coefficient of crude oil. f Let W be the rock compressibility coefficient, W be the water volume, and B be the water volume. oi R is the crude oil volume coefficient. e R is the crack radius. w Let μ be the well radius. o The viscosity of crude oil is μ. w K represents the viscosity of water. ro K represents the oil phase permeability after water exposure. rw N represents the aqueous phase permeability after water exposure. p This represents the cumulative oil production before water exposure.

[0170] Optionally, the apparatus further includes a target production function construction module.

[0171] The target production function construction module is used to determine the water volume after water seepage in the oil storage space based on the oil reservoir development correlation data and the pre-constructed target production function, before determining the water volume before water seepage in the oil storage space, and to construct the target production function based on the water volume after water seepage in the oil storage space and the first production function.

[0172] Optionally, the water volume determination module is used for:

[0173] The dynamic reserve determination unit is used to obtain the water volume after water seepage in the oil storage space, and substitute the water volume after water seepage into the target production function to obtain the dynamic oil reservoir reserves before water seepage in the oil storage space.

[0174] The water volume determination unit is used to substitute the dynamic reserves of the oil reservoir before water seepage in the oil storage space into the first production function to determine the water volume before water seepage in the oil storage space, and to determine the water volume before water seepage in the oil storage space as the water volume of fractured-vuggy carbonate rocks.

[0175] Optionally, the target production function construction module is specifically used for:

[0176] The first production function is expressed by the following formula:

[0177]

[0178] Where p is the cavern pressure, p w For bottom hole flowing pressure, C represents the change in pressure within the oil storage cavity over production time. o C is the compressibility coefficient of crude oil. wLet C be the water compressibility coefficient, and B be the water volume. wi B is the water volume coefficient. oi R is the crude oil volume coefficient. e R is the crack radius. w Let μ be the well radius. o K represents the viscosity of crude oil. o C represents the oil phase permeability before water exposure. f denoted as the rock compressibility coefficient, and N represents the dynamic reserves of the reservoir before water exposure.

[0179] Optionally, the target production function construction module is specifically used for:

[0180] The second production function is expressed by the following formula:

[0181]

[0182]

[0183] Where p is the cavern pressure, p w For bottom hole flowing pressure, C represents the change in pressure within the oil storage cavity over production time. o C is the compressibility coefficient of crude oil. f Let W be the rock compressibility coefficient, W be the water volume, and B be the water volume. wi B is the water volume coefficient. oi R is the crude oil volume coefficient. e R is the crack radius. w Let μ be the well radius. o The viscosity of crude oil is μ. w K represents the viscosity of water. ro K represents the oil phase permeability after water exposure. rw N' represents the water phase permeability after water exposure, and N' represents the dynamic oil reservoir reserves after water exposure in the oil storage space.

[0184] The water volume determination device for fractured carbonate rocks provided in this embodiment of the invention can execute the water volume determination method for fractured carbonate rocks provided in any embodiment of the invention, and has the corresponding functional modules and beneficial effects of the method.

[0185] Example 4

[0186] Figure 4 illustrates a schematic diagram of an electronic device 10 that can be used to implement embodiments of the present invention. The electronic device is intended to represent various forms of digital computers, such as laptop computers, desktop computers, workstations, personal digital assistants, servers, blade servers, mainframe computers, and other suitable computers. The electronic device can also represent various forms of mobile devices, such as personal digital processors, cellular phones, smartphones, wearable devices (e.g., helmets, glasses, watches, etc.), and other similar computing devices. The components shown herein, their connections and relationships, and their functions are merely illustrative and are not intended to limit the implementation of the invention described and / or claimed herein.

[0187] As shown in Figure 4, the electronic device 10 includes at least one processor 11 and a memory, such as a read-only memory (ROM) 12 or a random access memory (RAM) 13, communicatively connected to the at least one processor 11. The memory stores computer programs executable by the at least one processor. The processor 11 can perform various appropriate actions and processes based on the computer programs stored in the ROM 12 or loaded from storage unit 18 into the RAM 13. The RAM 13 can also store various programs and data required for the operation of the electronic device 10. The processor 11, ROM 12, and RAM 13 are interconnected via a bus 14. An input / output (I / O) interface 15 is also connected to the bus 14.

[0188] Multiple components in electronic device 10 are connected to I / O interface 15, including: input unit 16, such as keyboard, mouse, etc.; output unit 17, such as various types of displays, speakers, etc.; storage unit 18, such as disk, optical disk, etc.; and communication unit 19, such as network card, modem, wireless transceiver, etc. Communication unit 19 allows electronic device 10 to exchange information / data with other devices through computer networks such as the Internet and / or various telecommunications networks.

[0189] Processor 11 can be a variety of general-purpose and / or special-purpose processing components with processing and computing capabilities. Some examples of processor 11 include, but are not limited to, a central processing unit (CPU), a graphics processing unit (GPU), various special-purpose artificial intelligence (AI) computing chips, various processors running machine learning model algorithms, a digital signal processor (DSP), and any suitable processor, controller, microcontroller, etc. Processor 11 performs the various methods and processes described above, such as the method for determining the water volume of fractured-cavity carbonate rocks.

[0190] In some embodiments, the determination of the water volume of the method-fractured carbonate rock can be implemented as a computer program tangibly contained in a computer-readable storage medium, such as storage unit 18. In some embodiments, part or all of the computer program can be loaded and / or installed on electronic device 10 via ROM 12 and / or communication unit 19. When the computer program is loaded into RAM 13 and executed by processor 11, one or more steps of the method-fractured carbonate rock water volume determination described above can be performed. Alternatively, in other embodiments, processor 11 can be configured to perform the method-fractured carbonate rock water volume determination by any other suitable means (e.g., by means of firmware).

[0191] Various embodiments of the systems and techniques described above herein can be implemented in digital electronic circuit systems, integrated circuit systems, field-programmable gate arrays (FPGAs), application-specific integrated circuits (ASICs), application-specific standard products (ASSPs), systems-on-a-chip (SoCs), payload-programmable logic devices (CPLDs), computer hardware, firmware, software, and / or combinations thereof. These various embodiments may include implementations in one or more computer programs that can be executed and / or interpreted on a programmable system including at least one programmable processor, which may be a dedicated or general-purpose programmable processor, capable of receiving data and instructions from a storage system, at least one input device, and at least one output device, and transmitting data and instructions to the storage system, the at least one input device, and the at least one output device.

[0192] Computer programs used to implement the methods of the present invention may be written in any combination of one or more programming languages. These computer programs may be provided to a processor of a general-purpose computer, a special-purpose computer, or other programmable data processing device, such that when executed by the processor, the computer programs cause the functions / operations specified in the flowcharts and / or block diagrams to be performed. The computer programs may be executed entirely on a machine, partially on a machine, or as a standalone software package, partially on a machine and partially on a remote machine, or entirely on a remote machine or server.

[0193] In the context of this invention, a computer-readable storage medium can be a tangible medium that may contain or store a computer program for use by or in conjunction with an instruction execution system, apparatus, or device. A computer-readable storage medium may include, but is not limited to, electronic, magnetic, optical, electromagnetic, infrared, or semiconductor systems, apparatus, or devices, or any suitable combination thereof. Alternatively, a computer-readable storage medium may be a machine-readable signal medium. More specific examples of machine-readable storage media include electrical connections based on one or more wires, portable computer disks, hard disks, random access memory (RAM), read-only memory (ROM), erasable programmable read-only memory (EPROM or flash memory), optical fibers, portable compact disk read-only memory (CD-ROM), optical storage devices, magnetic storage devices, or any suitable combination thereof.

[0194] To provide interaction with a user, the systems and techniques described herein can be implemented on an electronic device having: a display device (e.g., a CRT (cathode ray tube) or LCD (liquid crystal display) monitor) for displaying information to the user; and a keyboard and pointing device (e.g., a mouse or trackball) through which the user provides input to the electronic device. Other types of devices can also be used to provide interaction with the user; for example, feedback provided to the user can be any form of sensory feedback (e.g., visual feedback, auditory feedback, or tactile feedback); and input from the user can be received in any form (including sound input, voice input, or tactile input).

[0195] The systems and technologies described herein can be implemented in computing systems that include backend components (e.g., as data servers), or computing systems that include middleware components (e.g., application servers), or computing systems that include frontend components (e.g., user computers with graphical user interfaces or web browsers through which users can interact with implementations of the systems and technologies described herein), or any combination of such backend, middleware, or frontend components. The components of the system can be interconnected via digital data communication of any form or medium (e.g., communication networks). Examples of communication networks include local area networks (LANs), wide area networks (WANs), blockchain networks, and the Internet.

[0196] A computing system can include clients and servers. Clients and servers are generally located far apart and typically interact through communication networks. The client-server relationship is created by computer programs running on the respective computers and having a client-server relationship with each other. The server can be a cloud server, also known as a cloud computing server or cloud host, which is a hosting product within the cloud computing service system to address the shortcomings of traditional physical hosts and VPS services, such as high management difficulty and weak business scalability.

[0197] It should be understood that the various forms of processes shown above can be used, with steps reordered, added, or deleted. For example, the steps described in this invention can be executed in parallel, sequentially, or in different orders, as long as the desired result of the technical solution of this invention can be achieved, and this is not limited herein.

[0198] The specific embodiments described above do not constitute a limitation on the scope of protection of this invention. Those skilled in the art should understand that various modifications, combinations, sub-combinations, and substitutions can be made according to design requirements and other factors. Any modifications, equivalent substitutions, and improvements made within the spirit and principles of this invention should be included within the scope of protection of this invention.

Claims

1. A method for determining the water volume in fractured carbonate rocks, characterized in that, include: Collect oil reservoir development correlation data for fractured-vuggy carbonate rocks, wherein the fractured-vuggy carbonate rocks include oil-bearing spaces, and the oil-bearing spaces include at least crude oil and water. Determine the water volume of the fractured-vuggy carbonate rocks based on the oil reservoir development correlation data and a pre-constructed target production function, wherein the target production function is used to characterize the linear logical relationship between the oil reservoir development correlation data and the water volume.

2. The method according to claim 1, characterized in that, The reservoir-related data includes at least one of the following: cumulative oil production before water breakthrough, water volume coefficient, water compressibility coefficient, water viscosity, water phase permeability, oil phase permeability, reservoir thickness, crude oil viscosity, fracture radius, well radius, crude oil compressibility coefficient, crude oil volume coefficient, initial formation pressure, and bottom hole flowing pressure.

3. The method according to claim 1, characterized in that, The target production function is expressed by the following formula: Where p is the cavern pressure, p w For the bottom hole flowing pressure, p i C is the initial reservoir pressure. o C is the compressibility coefficient of crude oil. f Let W be the rock compressibility coefficient, W be the water volume, and B be the water volume. oi R is the crude oil volume coefficient. e R is the crack radius. w Let μ be the well radius. o The viscosity of crude oil is μ. w K represents the viscosity of water. ro K represents the oil phase permeability after water exposure. rw N represents the aqueous phase permeability after water exposure. p This represents the cumulative oil production before water exposure.

4. The method according to claim 1, characterized in that, Before determining the water volume before water seepage in the oil reservoir based on the reservoir production correlation data and the pre-constructed target production function, the method further includes: determining the water volume after water seepage in the oil reservoir based on the reservoir production correlation data and the second production function, and constructing the target production function based on the water volume after water seepage in the oil reservoir and the first production function.

5. The method according to claim 4, characterized in that, The step of determining the water volume of the fractured-vuggy carbonate rock based on the reservoir development correlation data and the pre-constructed target production function includes: obtaining the water volume after water seepage in the oil storage space; substituting the water volume after water seepage into the target production function to obtain the dynamic oil reservoir reserves before water seepage in the oil storage space; substituting the dynamic oil reservoir reserves before water seepage in the oil storage space into the first production function to determine the water volume before water seepage in the oil storage space; and determining the water volume before water seepage in the oil storage space as the water volume of the fractured-vuggy carbonate rock.

6. The method according to claim 4, characterized in that, The first production function is expressed by the following formula: Where p is the cavern pressure, p w For bottom hole flowing pressure, C represents the change in pressure within the oil storage cavity over production time. o C is the compressibility coefficient of crude oil. w Let W be the water compressibility coefficient, W be the water volume, and B be the water volume. wi B is the water volume coefficient. oi R is the crude oil volume coefficient. e R is the crack radius. w Let μ be the well radius. o K represents the viscosity of crude oil. o C represents the oil phase permeability before water exposure. f denoted as the rock compressibility coefficient, and N represents the dynamic reserves of the reservoir before water exposure.

7. The method according to claim 4, characterized in that, The second production function is expressed by the following formula: Where p is the cavern pressure, p w For bottom hole flowing pressure, C represents the change in pressure within the oil storage cavity over production time. o C is the compressibility coefficient of crude oil. f Let W be the rock compressibility coefficient, W be the water volume, and B be the water volume. wi B is the water volume coefficient. oi R is the crude oil volume coefficient. e R is the crack radius. w Let μ be the well radius. o The viscosity of crude oil is μ. w K represents the viscosity of water. ro K represents the oil phase permeability after water exposure. rw N' represents the water phase permeability after water exposure, and N' represents the dynamic oil reservoir reserves after water exposure in the oil storage space.

8. A device for determining the water volume of fractured carbonate rocks, characterized in that, include: The data acquisition module is used to acquire oil reservoir development-related data of fractured-vuggy carbonate rocks, wherein the fractured-vuggy carbonate rocks include oil storage space, and the oil storage space includes at least crude oil and water. The water volume determination module is used to determine the water volume of the fractured-vuggy carbonate rocks based on the oil reservoir development-related data and a pre-constructed target production function, wherein the target production function is used to characterize the linear logical relationship between the oil reservoir development-related data and the water volume.

9. An electronic device, characterized in that, The electronic device includes: at least one processor; and a memory communicatively connected to the at least one processor; wherein the memory stores a computer program executable by the at least one processor, the computer program being executed by the at least one processor to enable the at least one processor to perform the method for determining the water volume of fractured carbonate rocks according to any one of claims 1-7.

10. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores computer instructions that cause a processor to execute the method for determining the water volume of fractured carbonate rocks as described in any one of claims 1-7.

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