Reservoir large-diameter porosity calculation method, device, electronic equipment and medium

Abstract

The present application discloses a method, device, electronic device and medium for calculating large-aperture porosity of a reservoir. The method may include: calculating the large-aperture porosity of a sample for each core sample; establishing a first fitting relationship between the large-aperture porosity of the sample and the permeability; calculating the large-aperture porosity of the target area according to the first fitting relationship and the permeability of the target area; calculating the porosity difference, establishing a second fitting relationship between the large-aperture porosity of the target area and the porosity difference; calculating the large-aperture porosity of the target well according to the porosity difference of the target well and the second fitting relationship. The present invention calculates the large-aperture porosity from the permeability through the good correlation between the permeability and the large-aperture porosity, and then establishes a calculation relationship with the logging parameters. The method is simple and practical, has strong operability, and has good effects in practical applications.

Description

Technical Field

[0001] The present invention relates to the technical field of petroleum geophysical exploration, and more specifically, to a method, device, electronic equipment and medium for calculating large-aperture porosity of a reservoir. Background Art

[0002] As reservoirs with complex pore structures such as tight sandstone have become the main areas for oil companies to increase reserves and production, pore structure evaluation has become an important part of exploration and development technology. Some work has been done by predecessors on pore structure evaluation using logging data, such as:

[0003] The reservoir pores are simplified into a curved capillary tube, and the calculation formulas such as the average pore throat radius are derived. The fitting relationship between the natural gamma curve and the formula parameters is established to realize the calculation of pore structure parameters.

[0004] The oil saturation is used to eliminate the influence of hydrocarbon in the reservoir, and then the pore structure parameters are calculated by the transverse relaxation time to achieve continuous characterization of the reservoir pore structure.

[0005] The reservoir pores are simplified into a group of capillaries, and the relationship between pore structure parameters and resistivity parameters is derived, thus forming a method for calculating pore structure parameters from resistivity data.

[0006] The relationship between rock physical phase and reservoir pore structure is summarized through the characteristics of sedimentary phase, diagenetic phase and fracture phase, and the rock physical phase is divided in combination with logging data to realize the classification and evaluation of pore structure;

[0007] The reservoir pore structure is classified according to the mercury injection curve, and the logging parameters are extracted to realize the pore structure classification and discrimination using the self-organizing neural network technology.

[0008] A comprehensive analysis of the previous work shows that either the reservoir pores are simplified into a capillary model and then the calculation formula for the pore structure parameters is derived. However, since the reservoir pore model is too ideal and greatly different from the actual formation conditions, its scope of application is limited. Alternatively, the reservoir pore structure is classified according to information such as diagenetic phases and capillary pressure curve characteristics, and this classification is related to some logging parameters, so as to achieve qualitative evaluation of the pore structure using methods such as plates or neural networks. Alternatively, nuclear magnetic resonance logging is used. Nuclear magnetic resonance logging can continuously and quantitatively evaluate the reservoir pore structure, but it is a special logging method with high data acquisition costs. Most wells do not have nuclear magnetic data, which limits the use of this method.

[0009] Therefore, it is necessary to develop a method, device, electronic equipment and medium for calculating large-diameter porosity of reservoirs.

[0010] The information disclosed in the background technology section of the present invention is only intended to deepen the understanding of the general background technology of the present invention, and should not be regarded as acknowledging or suggesting in any form that the information constitutes the prior art already known to those skilled in the art. Summary of the invention

[0011] The present invention proposes a method, device, electronic equipment and medium for calculating large-aperture porosity of a reservoir, which can calculate large-aperture porosity from permeability through good correlation between permeability and large-aperture porosity, and then establish a calculation relationship with logging parameters. The method is simple, practical, highly operable and has good effects in practical applications.

[0012] In a first aspect, an embodiment of the present disclosure provides a method for calculating large-diameter porosity of a reservoir, comprising:

[0013] The macropore porosity of each core sample is calculated;

[0014] Establishing a first fitting relationship between the macropore porosity of the sample and the permeability;

[0015] Calculating the macropore porosity of the target area according to the first fitting relationship and the permeability of the target area;

[0016] Calculating the porosity difference and establishing a second fitting relationship between the macropore porosity of the target area and the porosity difference;

[0017] The macropore porosity of the target well is calculated according to the porosity difference of the target well and the second fitting relationship.

[0018] Preferably, calculating the macropore porosity of each core sample comprises:

[0019] Calculating the capillary force and determining the mercury intrusion saturation corresponding to the capillary force;

[0020] The macropore porosity of the sample is calculated based on the mercury saturation and the core porosity.

[0021] Preferably, the capillary force is calculated by formula (1):

[0022]

[0023] The macropore porosity of the sample is calculated by formula (2):

[0024]

[0025] Among them, P C is the capillary force, r c To calculate the aperture, S C The capillary force is P C The corresponding mercury saturation, is the core porosity.

[0026] Preferably, calculating the porosity difference comprises:

[0027] Extract the logging acoustic wave time difference value and density value on the logging curve;

[0028] Calculate sonic transit time porosity and density porosity;

[0029] The porosity difference is calculated by using the sonic transit time porosity and the density porosity.

[0030] Preferably, the sonic transit time porosity is calculated by formula (3):

[0031]

[0032] Among them, PORA is the acoustic transit time porosity, TM is the rock skeleton acoustic transit time, and AC is the acoustic transit time value.

[0033] Preferably, the density porosity is calculated by formula (4):

[0034]

[0035] Among them, PORD is density porosity, DG is rock density skeleton, DF is formation water density, and DEN is density value.

[0036] Preferably, the porosity difference is calculated by formula (5):

[0037] ΔPOR=PORD-PORA (5)

[0038] Here, ΔPOR is the porosity difference.

[0039] As a specific implementation method of the embodiment of the present disclosure,

[0040] In a second aspect, the present disclosure also provides a reservoir large-diameter porosity calculation device, comprising:

[0041] Sample calculation module, which calculates the large-diameter porosity of each core sample;

[0042] A first fitting module is used to establish a first fitting relationship between the macropore porosity of the sample and the permeability;

[0043] A target area calculation module, which calculates the macropore porosity of the target area according to the first fitting relationship and the permeability of the target area;

[0044] A second fitting module calculates the porosity difference and establishes a second fitting relationship between the macropore porosity of the target area and the porosity difference;

[0045] The target well calculation module calculates the large-diameter porosity of the target well according to the porosity difference of the target well and the second fitting relationship.

[0046] Preferably, calculating the macropore porosity of each core sample comprises:

[0047] Calculating the capillary force and determining the mercury intrusion saturation corresponding to the capillary force;

[0048] The macropore porosity of the sample is calculated based on the mercury saturation and the core porosity.

[0049] Preferably, the capillary force is calculated by formula (1):

[0050]

[0051] The macropore porosity of the sample is calculated by formula (2):

[0052]

[0053] Among them, P C is the capillary force, r c To calculate the aperture, S C The capillary force is P C The corresponding mercury saturation, is the core porosity.

[0054] Preferably, calculating the porosity difference comprises:

[0055] Extract the logging acoustic wave time difference value and density value on the logging curve;

[0056] Calculate sonic transit time porosity and density porosity;

[0057] The porosity difference is calculated by using the sonic transit time porosity and the density porosity.

[0058] Preferably, the sonic transit time porosity is calculated by formula (3):

[0059]

[0060] Among them, PORA is the acoustic transit time porosity, TM is the rock skeleton acoustic transit time, and AC is the acoustic transit time value.

[0061] Preferably, the density porosity is calculated by formula (4):

[0062]

[0063] Among them, PORD is density porosity, DG is rock density skeleton, DF is formation water density, and DEN is density value.

[0064] Preferably, the porosity difference is calculated by formula (5):

[0065] ΔPOR=PORD-PORA (5)

[0066] Here, ΔPOR is the porosity difference.

[0067] In a third aspect, an embodiment of the present disclosure further provides an electronic device, the electronic device comprising:

[0068] A memory storing executable instructions;

[0069] A processor runs the executable instructions in the memory to implement the reservoir large-diameter porosity calculation method.

[0070] In a fourth aspect, an embodiment of the present disclosure further provides a computer-readable storage medium, which stores a computer program, and when the computer program is executed by a processor, the method for calculating the large-aperture porosity of a reservoir is implemented.

[0071] The methods and apparatus of the present invention have other features and advantages that will be apparent from, or will be described in detail in, the accompanying drawings and subsequent detailed descriptions incorporated herein, which together serve to explain the specific principles of the present invention. BRIEF DESCRIPTION OF THE DRAWINGS

[0072] The above and other objects, features and advantages of the present invention will become more apparent through a more detailed description of exemplary embodiments of the present invention in conjunction with the accompanying drawings, wherein like reference numerals generally represent like components throughout the exemplary embodiments of the present invention.

[0073] Figure 1 A flow chart showing the steps of a method for calculating large-pore porosity of a reservoir according to an embodiment of the present invention.

[0074] Figure 2 A schematic diagram of reservoir pore size distribution according to an embodiment of the present invention is shown.

[0075] Figure 3 A schematic diagram showing the fitting relationship between macropore porosity and permeability according to an embodiment of the present invention is shown.

[0076] Figure 4 A schematic diagram showing the fitting relationship between macropore porosity and ΔPOR according to an embodiment of the present invention is shown.

[0077] Figure 5A schematic diagram showing the comparison between the large-aperture porosity calculated by well logging of Well XX26 according to an embodiment of the present invention and the large-aperture porosity obtained by mercury injection experiment is shown.

[0078] Figure 6 A block diagram of a reservoir large-aperture porosity calculation device according to an embodiment of the present invention is shown.

[0079] Description of reference numerals:

[0080] 201, sample calculation module; 202, first fitting module; 203, target area calculation module; 204, second fitting module; 205, target well calculation module. DETAILED DESCRIPTION

[0081] The preferred embodiments of the present invention will be described in more detail below. Although the preferred embodiments of the present invention are described below, it should be understood that the present invention can be implemented in various forms and should not be limited to the embodiments set forth herein.

[0082] The present invention provides a method for calculating large-diameter porosity of a reservoir, comprising:

[0083] The large-aperture porosity of the sample is calculated for each core sample. In one example, the large-aperture porosity of the sample is calculated for each core sample, including: calculating the capillary force, determining the mercury saturation corresponding to the capillary force; and calculating the large-aperture porosity of the sample through the mercury saturation and the core porosity.

[0084] In one example, the capillary force is calculated by equation (1):

[0085]

[0086] The macropore porosity of the sample is calculated by formula (2):

[0087]

[0088] Among them, P C is the capillary force, r c To calculate the aperture, S C The capillary force is P C The corresponding mercury saturation, is the core porosity.

[0089] Specifically, the mercury injection test data of the target oil and gas field are analyzed to obtain the pore throat distribution of the core sample and determine the lower limit of the pore size corresponding to the large pore size porosity. Generally speaking, the pore size distribution of samples from high-quality reservoirs in complex reservoirs such as tight sandstone is generally multi-peaked. The pore size corresponding to the trough between the maximum pore size peak and the second largest pore size peak is taken as the lower limit of the large pore size, denoted as r cThe capillary force is calculated by formula (1) to determine the mercury saturation corresponding to the capillary force; the large-aperture porosity of the sample is calculated by formula (2) based on the mercury saturation and the core porosity.

[0090] The first fitting relationship between the macropore porosity and permeability of the sample was established; the macropore porosity obtained by mercury injection experiment The first fitting relationship established with the permeability K obtained from the physical property experiment is:

[0091]

[0092] Among them, a and b are fitting coefficients.

[0093] According to the first fitting relationship and the permeability of the target area, the macropore porosity of the target area is calculated by formula (6).

[0094] Calculate the porosity difference and establish a second fitting relationship between the large-diameter porosity and the porosity difference of the target area; in one example, calculate the porosity difference including: extracting the logging acoustic time difference value and the density value on the logging curve; calculate the acoustic time difference porosity and the density porosity; calculate the porosity difference through the acoustic time difference porosity and the density porosity.

[0095] In one example, the sonic transit time porosity is calculated by formula (3):

[0096]

[0097] Among them, PORA is the acoustic transit time porosity, TM is the rock skeleton acoustic transit time, and AC is the acoustic transit time value.

[0098] In one example, the density porosity is calculated by equation (4):

[0099]

[0100] Among them, PORD is density porosity, DG is rock density skeleton, DF is formation water density, and DEN is density value.

[0101] In one example, the porosity difference is calculated by equation (5):

[0102] ΔPOR=PORD-PORA (5)

[0103] Here, ΔPOR is the porosity difference.

[0104] Specifically, according to the macropore porosity of the target area, the logging acoustic time difference value AC and the density value DEN are extracted at the corresponding depth, the acoustic time difference porosity PORA is calculated by formula (3), the density porosity PORD is calculated by formula (4), and then the porosity difference △POR is calculated by formula (5). The porosity difference is fitted with the macropore porosity of the target area, and the second fitting relationship is obtained as follows:

[0105]

[0106] Among them, c and d are fitting coefficients.

[0107] The porosity difference of the target well is calculated according to formulas (4)-(6), and the porosity difference of the target well is substituted into the second fitting relationship to calculate the large-diameter porosity of the target well.

[0108] The present invention also provides a reservoir large-diameter porosity calculation device, comprising:

[0109] The sample calculation module calculates the sample large-aperture porosity for each core sample; in one example, the sample large-aperture porosity is calculated for each core sample, including: calculating the capillary force, determining the mercury saturation corresponding to the capillary force; and calculating the sample large-aperture porosity through the mercury saturation and the core porosity.

[0110] In one example, the capillary force is calculated by equation (1):

[0111]

[0112] The macropore porosity of the sample is calculated by formula (2):

[0113]

[0114] Among them, P C is the capillary force, r c To calculate the aperture, S C The capillary force is P C The corresponding mercury saturation, is the core porosity.

[0115] Specifically, the mercury injection test data of the target oil and gas field are analyzed to obtain the pore throat distribution of the core sample and determine the lower limit of the pore size corresponding to the large pore size porosity. Generally speaking, the pore size distribution of samples from high-quality reservoirs in complex reservoirs such as tight sandstone is generally multi-peaked. The pore size corresponding to the trough between the maximum pore size peak and the second largest pore size peak is taken as the lower limit of the large pore size, denoted as r c The capillary force is calculated by formula (1) to determine the mercury saturation corresponding to the capillary force; the large-aperture porosity of the sample is calculated by formula (2) based on the mercury saturation and the core porosity.

[0116] The first fitting module is used to establish the first fitting relationship between the macropore porosity and permeability of the sample; the macropore porosity obtained by the mercury injection experiment The first fitting relationship established with the permeability K obtained from the physical property experiment is formula (6).

[0117] The target area calculation module calculates the macropore porosity of the target area according to the first fitting relationship and the permeability of the target area through formula (6).

[0118] The second fitting module calculates the porosity difference and establishes a second fitting relationship between the large-diameter porosity and the porosity difference of the target area. In one example, calculating the porosity difference includes: extracting the logging acoustic time difference value and the density value on the logging curve; calculating the acoustic time difference porosity and the density porosity; and calculating the porosity difference through the acoustic time difference porosity and the density porosity.

[0119] In one example, the sonic transit time porosity is calculated by formula (3):

[0120]

[0121] Among them, PORA is the acoustic transit time porosity, TM is the rock skeleton acoustic transit time, and AC is the acoustic transit time value.

[0122] In one example, the density porosity is calculated by equation (4):

[0123]

[0124] Among them, PORD is density porosity, DG is rock density skeleton, DF is formation water density, and DEN is density value.

[0125] In one example, the porosity difference is calculated by equation (5):

[0126] ΔPOR=PORD-PORA (5)

[0127] Here, ΔPOR is the porosity difference.

[0128] Specifically, according to the large-aperture porosity of the target area, the logging acoustic time difference value AC and the density value DEN are extracted at the corresponding depth, the acoustic time difference porosity PORA is calculated by formula (3), the density porosity PORD is calculated by formula (4), and then the porosity difference △POR is calculated by formula (5). The porosity difference is fitted with the large-aperture porosity of the target area, and the second fitting relationship is obtained as formula (7).

[0129] The target well calculation module calculates the porosity difference of the target well according to formulas (3)-(5), substitutes the porosity difference of the target well into the second fitting relationship, and calculates the large-diameter porosity of the target well.

[0130] The present invention also provides an electronic device, which includes: a memory storing executable instructions; and a processor, which runs the executable instructions in the memory to implement the above-mentioned reservoir large-diameter porosity calculation method.

[0131] The present invention also provides a computer-readable storage medium, which stores a computer program. When the computer program is executed by a processor, the above-mentioned reservoir large-diameter porosity calculation method is implemented.

[0132] To facilitate understanding of the solutions and effects of the embodiments of the present invention, four specific application examples are given below. Those skilled in the art should understand that the examples are only for facilitating understanding of the present invention, and any specific details thereof are not intended to limit the present invention in any way.

[0133] Example 1

[0134] Figure 1 A flow chart showing the steps of a method for calculating large-pore porosity of a reservoir according to an embodiment of the present invention.

[0135] like Figure 1 As shown, the reservoir large-pore porosity calculation method includes: step 101, calculating the sample large-pore porosity for each core sample; step 102, establishing a first fitting relationship between the sample large-pore porosity and permeability; step 103, calculating the large-pore porosity of the target area according to the first fitting relationship and the permeability of the target area; step 104, calculating the porosity difference, and establishing a second fitting relationship between the large-pore porosity of the target area and the porosity difference; step 105, calculating the large-pore porosity of the target well according to the porosity difference of the target well and the second fitting relationship.

[0136] Figure 2 A schematic diagram of reservoir pore size distribution according to an embodiment of the present invention is shown.

[0137] For a certain well area, conventional logging data is used to obtain large-diameter porosity, such as Figure 2 As shown in Figure 1, from the reservoir pore size distribution obtained from the mercury injection experiment of samples from high-quality reservoirs, it can be seen that the sample pores are distributed in a tri-peaked manner. The pores corresponding to the valley between the first peak and the second peak from right to left are about 0.1 μm. Therefore, the lower limit of the pore size of the large-diameter pores is determined to be 0.1 μm.

[0138] The large-diameter porosity is calculated by taking the HH1057-3 core sample with a depth of 2230.7 m as an example. The lower limit of the large-diameter pores is 0.1 μm. The corresponding capillary force is 7.35 MPa obtained from formula (1). From the mercury injection test data of the sample, it can be seen that the mercury saturation at 7.35 MPa is 28.73%. The porosity obtained from the core physical property experiment of the sample is 7.5%. The large-diameter porosity of the sample is 2.15% obtained from formula (2). The large-diameter porosity of the 19 core samples in the target area for mercury injection experiments can be obtained.

[0139] Figure 3 A schematic diagram showing the fitting relationship between macropore porosity and permeability according to an embodiment of the present invention is shown.

[0140] A fitting relationship is established between the macropore porosity obtained from the mercury injection test sample and the permeability from the physical property test, such as Figure 3 As shown, it can be seen that in formula (6), a=9.8922, b=0.5729.

[0141] The macropore porosity of 184 core samples in the target area that underwent physical property experiments (permeability measurements) was calculated using formula (6).

[0142] Figure 4 A schematic diagram showing the fitting relationship between macropore porosity and ΔPOR according to an embodiment of the present invention is shown.

[0143] The acoustic time difference logging values ​​and density logging values ​​were extracted at the corresponding depths for 184 core samples that underwent physical property experiments. The difference between density porosity and acoustic porosity, △POR, was calculated using formulas (3)-(5). A fitting relationship was established between the large-aperture porosity calculated from the permeability of the 184 samples and △POR, as shown in the following example: Figure 4 As shown, we can know that formula (7) c = 53.185, d = 2.8516.

[0144] Figure 5 A schematic diagram showing the comparison between the large-aperture porosity calculated by well logging of Well XX26 according to an embodiment of the present invention and the large-aperture porosity obtained by mercury injection experiment is shown.

[0145] For the well that needs pore structure analysis (taking Well XX26 as an example), the difference between density porosity and acoustic porosity △POR is calculated according to formulas (3)-(5), and the macropore porosity is calculated according to formula (7), as follows: Figure 5 Track 5, PHIX is the large-aperture porosity calculated by well logging, and CPHIX (bar graph display) is the large-aperture porosity obtained by mercury injection experiment. The two are in good agreement, indicating that the invention has a good application effect in the study area.

[0146] Example 2

[0147] Figure 3 A block diagram of a reservoir large-aperture porosity calculation device according to an embodiment of the present invention is shown.

[0148] like Figure 3 As shown, the reservoir large-aperture porosity calculation device comprises:

[0149] A sample calculation module 201 calculates the large-aperture porosity of each core sample;

[0150] A first fitting module 202, establishing a first fitting relationship between the macropore porosity and permeability of the sample;

[0151] The target area calculation module 203 calculates the macropore porosity of the target area according to the first fitting relationship and the permeability of the target area;

[0152] The second fitting module 204 calculates the porosity difference and establishes a second fitting relationship between the large-diameter porosity and the porosity difference of the target area;

[0153] The target well calculation module 205 calculates the large-diameter porosity of the target well according to the porosity difference of the target well and the second fitting relationship.

[0154] As an option, calculate the macropore porosity of each core sample including:

[0155] Calculate the capillary force and determine the mercury saturation corresponding to the capillary force;

[0156] The large-diameter porosity of the sample is calculated based on the mercury saturation and core porosity.

[0157] As an alternative, the capillary force can be calculated using formula (1):

[0158]

[0159] The macropore porosity of the sample is calculated by formula (2):

[0160]

[0161] Among them, P C is the capillary force, r c To calculate the aperture, S C The capillary force is P C The corresponding mercury saturation, is the core porosity.

[0162] As an option, calculate the porosity difference by:

[0163] Extract the logging acoustic wave time difference value and density value on the logging curve;

[0164] Calculate sonic transit time porosity and density porosity;

[0165] The porosity difference is calculated by comparing the sonic time difference porosity with the density porosity.

[0166] As an alternative, the sonic transit time porosity can be calculated using formula (3):

[0167]

[0168] Among them, PORA is the acoustic transit time porosity, TM is the rock skeleton acoustic transit time, and AC is the acoustic transit time value.

[0169] As an alternative, the density porosity can be calculated using formula (4):

[0170]

[0171] Among them, PORD is density porosity, DG is rock density skeleton, DF is formation water density, and DEN is density value.

[0172] As an alternative, the porosity difference can be calculated by formula (5):

[0173] ΔPOR=PORD-PORA (5)

[0174] Here, ΔPOR is the porosity difference.

[0175] Example 3

[0176] The present disclosure provides an electronic device, which includes: a memory storing executable instructions; a processor, which runs the executable instructions in the memory to implement the above-mentioned reservoir large-aperture porosity calculation method.

[0177] An electronic device according to an embodiment of the present disclosure includes a memory and a processor.

[0178] The memory is used to store non-temporary computer-readable instructions. Specifically, the memory may include one or more computer program products, which may include various forms of computer-readable storage media, such as volatile memory and / or non-volatile memory. The volatile memory may, for example, include random access memory (RAM) and / or cache memory (cache), etc. The non-volatile memory may, for example, include read-only memory (ROM), hard disk, flash memory, etc.

[0179] The processor may be a central processing unit (CPU) or other forms of processing units having data processing capabilities and / or instruction execution capabilities, and may control other components in the electronic device to perform desired functions. In one embodiment of the present disclosure, the processor is used to run the computer-readable instructions stored in the memory.

[0180] Those skilled in the art should be able to understand that in order to solve the technical problem of how to obtain a good user experience, the present embodiment may also include well-known structures such as a communication bus and an interface, and these well-known structures should also be included in the protection scope of the present disclosure.

[0181] For detailed description of this embodiment, reference may be made to the corresponding descriptions in the aforementioned embodiments, which will not be repeated here.

[0182] Example 4

[0183] An embodiment of the present disclosure provides a computer-readable storage medium, which stores a computer program. When the computer program is executed by a processor, the method for calculating the large-aperture porosity of a reservoir is implemented.

[0184] According to the computer-readable storage medium of the embodiment of the present disclosure, non-transitory computer-readable instructions are stored thereon. When the non-transitory computer-readable instructions are executed by a processor, all or part of the steps of the above-mentioned methods of each embodiment of the present disclosure are executed.

[0185] The above-mentioned computer-readable storage media include, but are not limited to: optical storage media (e.g., CD-ROM and DVD), magneto-optical storage media (e.g., MO), magnetic storage media (e.g., magnetic tape or mobile hard disk), media with built-in rewritable non-volatile memory (e.g., memory card) and media with built-in ROM (e.g., ROM box).

[0186] Those skilled in the art should understand that the purpose of the above description of the embodiments of the present invention is only to exemplarily illustrate the beneficial effects of the embodiments of the present invention, and is not intended to limit the embodiments of the present invention to any given examples.

[0187] The embodiments of the present invention have been described above, and the above description is exemplary, not exhaustive, and is not limited to the disclosed embodiments. Many modifications and changes will be apparent to those skilled in the art without departing from the scope and spirit of the described embodiments.

Claims

1. A method for calculating large-diameter porosity of a reservoir, characterized in that: include: The macropore porosity of each core sample is calculated; Establishing a first fitting relationship between the macropore porosity and permeability of the sample; Calculating the macropore porosity of the target area according to the first fitting relationship and the permeability of the target area; Calculating the porosity difference and establishing a second fitting relationship between the macropore porosity of the target area and the porosity difference; Calculating the macropore porosity of the target well according to the porosity difference of the target well and the second fitting relationship; The calculation of the large-aperture porosity of each core sample includes: Calculating the capillary force and determining the mercury intrusion saturation corresponding to the capillary force; Calculating the large-aperture porosity of the sample through the mercury injection saturation and the core porosity; The capillary force is calculated by formula (1): The macropore porosity of the sample is calculated by formula (2): Among them, P C is the capillary force, r c To calculate the aperture, S C The capillary force is P C The corresponding mercury saturation, is the core porosity.

2. The reservoir large-diameter porosity calculation method according to claim 1, wherein: Calculating the porosity difference involves: Extract the logging acoustic wave time difference value and density value on the logging curve; Calculate sonic transit time porosity and density porosity; The porosity difference is calculated by using the sonic transit time porosity and the density porosity.

3. The reservoir large-diameter porosity calculation method according to claim 1, wherein: The sonic transit time porosity is calculated by formula (3): Among them, PORA is the acoustic transit time porosity, TM is the rock skeleton acoustic transit time, and AC is the acoustic transit time value.

4. The reservoir large-diameter porosity calculation method according to claim 1, wherein: The density porosity is calculated by formula (4): Among them, PORD is density porosity, DG is rock density skeleton, DF is formation water density, and DEN is density value.

5. The reservoir large-diameter porosity calculation method according to claim 1, wherein: The porosity difference is calculated by formula (5): ΔPOR=PORD-PORA (5) Here, △POR is the porosity difference.

6. A reservoir large-diameter porosity calculation device, characterized in that: include: Sample calculation module, which calculates the large-diameter porosity of each core sample; A first fitting module is used to establish a first fitting relationship between the macropore porosity and permeability of the sample; A target area calculation module, which calculates the macropore porosity of the target area according to the first fitting relationship and the permeability of the target area; A second fitting module calculates the porosity difference and establishes a second fitting relationship between the macropore porosity of the target area and the porosity difference; a target well calculation module, which calculates the macropore porosity of the target well according to the porosity difference of the target well and the second fitting relationship; The calculation of the large-aperture porosity of each core sample includes: Calculating the capillary force and determining the mercury intrusion saturation corresponding to the capillary force; Calculating the large-aperture porosity of the sample through the mercury injection saturation and the core porosity; The capillary force is calculated by formula (1): The macropore porosity of the sample is calculated by formula (2): Among them, P C is the capillary force, r c To calculate the aperture, S C The capillary force is P C The corresponding mercury saturation, is the core porosity.

7. An electronic device, characterized in that: The electronic device comprises: A memory storing executable instructions; A processor, wherein the processor runs the executable instructions in the memory to implement the reservoir large-diameter porosity calculation method according to any one of claims 1 to 5.

8. A computer-readable storage medium, characterized in that: The computer-readable storage medium stores a computer program, and when the computer program is executed by a processor, the method for calculating the large-diameter porosity of a reservoir according to any one of claims 1 to 5 is implemented.

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