A method for calculating watered-out layer mixed solution resistivity and saturation, an electronic device and a medium

Abstract

The application discloses a water-flooded layer mixed solution resistivity and saturation calculation method, electronic equipment and medium, comprising: calculating the volume of the displaced oil and the volume of the displaced water of the rock sample at the initial water displacement stage k; calculating the injected water volume; calculating the salinity of the injected water and the contact ratio Pe of the injected water and the rock formation water, the salinity of the rock water and the salinity of the displaced water; calculating the salinity of the rock sample; combining the environmental temperature T, the total mineralization degree of the rock sample is calculated to obtain the formation water mixed solution resistivity value; combining the Arzi formula, the formation resistivity corresponding to the water saturation at the water displacement stage k is obtained; at this time, let, k=k+1, and the steps 1-6 are repeated until the calculation is completed. The application can be applied and popularized in the water displacement development of multiple oilfield main reservoirs, and has good applicability.

Description

Technical Field

[0001] This invention relates to the field of well logging interpretation technology for clastic rock reservoirs, specifically to a method for calculating the resistivity and saturation of a water-flooded reservoir mixture, as well as electronic equipment and media. Background Technology

[0002] Accurate calculation of the remaining oil saturation in water-flooded formations is crucial for adjusting reservoir water injection development plans. Currently, the main research direction for evaluating remaining oil saturation is studying the changes in sample resistivity during displacement using core experiments or theoretical derivation and numerical simulation methods. The biggest challenge lies in accurately calculating the resistivity of the formation water mixture. The calculation methods mainly include direct and indirect methods. Direct methods determine the resistivity by measuring the salinity of formation water samples through sampling experiments; indirect methods mainly include spontaneous potential calculation and cross-plotting. These methods are not only limited in application, costly, and time-consuming, but also have relatively low calculation accuracy.

[0003] After years of research, many scholars at home and abroad have proposed a number of methods for calculating the resistivity of mixed-liquid formation water. Some of the more representative methods include the resistivity parallel conduction method (Wang Jingnong, 1985; Zou Changchun et al., 1999), the mass balance method (Zhao Wenjie, 1995; Shen Huilin and Fang Peng, 2011), the derivative method of Archie's formula (Zhang Chaomo et al., 2008), and the variable-multiplication mass balance method (Shen Huilin, 2011).

[0004] Currently, the main methods for evaluating the resistivity Rwz of the mixed liquid in flooded layers in China are: (1) Calculation method of natural potential This method describes the baseline shift of the spontaneous potential when the oil layer is flooded with fresh water. Based on the expression for spontaneous potential in the wellbore proposed by Korobolev et al., the relationship between the baseline shift amplitude ΔSP of spontaneous potential and the resistivity Rwz of the formation mixture after flooding is derived.

[0005] Advantages: Obtained based on actual well logging parameters, easy to operate, and the calculation process is controllable.

[0006] Disadvantages: It is affected by many factors, such as mud quality, layer thickness, hydrocarbon content, and filtration potential, making it difficult to guarantee accuracy. It is only suitable for wellbore and reservoir environments with high-intensity freshwater washing.

[0007] (2) Direct method for determining formation water salinity This method mainly involves sampling the produced water from the reservoir during actual drilling, measuring the formation water salinity through experiments, and then calculating the formation water resistivity.

[0008] Advantages: Direct acquisition, high accuracy.

[0009] Disadvantages: Flooding is a dynamic process that depends on sampling, involves a large amount of engineering work, is costly, and has a long cycle, making it impractical for widespread application.

[0010] (3) Parallel conduction model method This method treats the mixed water as an equivalent parallel conductive model of injected water and native water combined in a certain proportion. By changing the proportion of the two different types of water, the resistivity Rwz of the mixed liquid is solved by an iterative method.

[0011] Advantages: Key parameters are easy to obtain, and the calculation process is controllable.

[0012] Disadvantages: This method assumes that only oil is produced and no water is produced during the flooding process, without considering the dynamic changes in water distribution and ion exchange. It is suitable for the early stage of flooding but not for the middle and later stages of the experiment.

[0013] (4) Ion exchange substance balance method This method involves injecting water into the reservoir after flooding, determining the salinity of the mixed solution based on the total salt content (ion content), and then calculating the formation water resistivity based on the salinity.

[0014] Advantages: Key parameters such as injected water and formation water salinity are easy to obtain, making it highly practical.

[0015] Disadvantages: It does not take into account the flow law of oil and water two phases, and does not clarify the change law of ion exchange. When the water saturation is high and oil and water are produced in the core at the same time, the material balance method is no longer applicable and cannot guide actual production applications.

[0016] However, these methods do not fully consider the complexity of the constantly changing injected water and formation water and the release of ions during the water drive process, and therefore are limited in practical applications.

[0017] Therefore, there is an urgent need for a method, electronic equipment, and medium for calculating the resistivity and saturation of water-flooded layer mixtures that can be applied and promoted in multiple oilfields and has good applicability. Summary of the Invention

[0018] The purpose of this invention is to provide a method, electronic device and medium for calculating the resistivity and saturation of the water-flooded layer mixture, so as to overcome the shortcomings of the prior art which does not fully consider the complexity of the continuous changes in the injected water and formation water and the release of ion exchange during the water drive process, and is therefore limited in practical application.

[0019] To achieve the above objectives, the present invention provides a method for calculating the resistivity and saturation of a water-flooded layer mixture, specifically including the following technical solution: comprising the following steps: S1, calculate the volume of oil displaced from the rock sample at the initial waterflooding stage k. and the volume of water displaced ; S2, based on the volume of the displaced oil obtained. and the volume of water displaced, V 驱替水 (k) Calculate the injected water volume : S3, based on the obtained injected water volume Calculate the salinity of the injected water ; and calculate the contact ratio Pe between injected water and formation water, and the salinity of the formation water. Salinity of the displaced water ; S4, based on the obtained salinity of the injected water Salinity of rock water Salinity of the displaced water The salinity of the rock sample was obtained. ; S5, based on the salinity of the obtained rock sample Calculate the total mineralization of the rock sample. Total mineralization of rock samples The resistivity value of the formation water mixture was obtained by combining the ambient temperature T. ; S6, based on the obtained resistivity value of the formation water mixture The water saturation of k at this stage of water drive is obtained by combining the Alzer formula. Corresponding formation resistivity (k); S7, season k=k+1, repeat S1~S6 until... The calculation ends when the formation water mixture resistivity value for each water drive stage is obtained. (k) and formation resistivity ,in, It is the residual oil saturation. To bind water saturation.

[0020] Furthermore, in S7, x is The increment, .

[0021] Furthermore, in S1, during the initial water drive stage, k=1, corresponding to a water saturation level of... ; Volume of displacement oil ; the volume of water displaced ; in, Reservoir porosity; The water saturation level is T; the flooding time is T. Oil flow rate; This refers to the water flow rate.

[0022] Furthermore, in S2, the volume of injected water... The calculation formula is: = + .

[0023] Furthermore, in S3, the salinity of the injected water... The calculation formula is: ; Salinity of rock water The calculation formula is: ; initial state = SALT Sw (0) = SALT Swi = ; Salinity of the displaced water The calculation formula is: =(SALT 注入水 (k)+ SALT Sw (k-1)) ( ) Pe; = ; Among them, P j P0 represents the salinity of the injected water, while P0 represents the salinity of the original formation water. During the flooding process, the contact ratio between the injected water and the rock formation water is Pe= .

[0024] Furthermore, in S4, the salinity of the rock sample... = (SALT 注入水 (k)+ SALT 岩石水 (k))-SALT 驱替水 (k).

[0025] Furthermore, in S6, the total mineralization of the rock sample is PPT(k) = SALT Sw (k) / S w (k)); the above ; The Alzi formula is: ; Where T is the ambient temperature in degrees Fahrenheit, a and b are lithology coefficients, and R is the lithology coefficient. wzR represents the total resistivity of the mixed liquid in the formation pores. t φ is the formation resistivity, m is the formation porosity, and n is the cementation index.

[0026] Secondly, the present invention also provides an electronic device, the electronic device comprising: a memory storing executable instructions; and a processor that executes the executable instructions in the memory to implement the above-described method for calculating the resistivity and saturation of the water-flooded layer mixture.

[0027] Thirdly, the present invention also provides a computer-readable storage medium storing a computer program that, when executed by a processor, implements the above-described method for calculating the resistivity and saturation of the water-flooded layer mixture.

[0028] Compared with the prior art, the present invention has the following beneficial technical effects: This invention provides a method for calculating the resistivity and saturation of the mixed fluid in a water-flooded layer. This method fully considers the complexity and integrity of the entire water-flooding process. From the perspective of material balance, it describes and derives in detail the dynamic changes in the volume of injected water, rock water, and discharged water, as well as the salinity, with water saturation. It is applicable to the evaluation of water-flooded layers with different water injection properties (fresh water, wastewater). The basic parameters used in the formula derivation, such as porosity and rock electrical parameters, are mature and easily obtained in oilfield development. By probabilistically deriving the logging resistivity value corresponding to any water saturation moment, and in practical applications, using data collected from logging, the remaining oil saturation can be quantitatively calculated. This method has been applied and promoted in the water-drive development of major oil reservoirs in multiple oilfields, demonstrating good applicability. Attached Figure Description

[0029] Figure 1 This is a flowchart illustrating a method for calculating the resistivity and saturation of a water-flooded layer mixture in an embodiment of the present invention.

[0030] Figure 2 This is a schematic diagram of the ion displacement exchange interpretation and evaluation model for oil-water phase permeation control in an embodiment of the present invention.

[0031] Figure 3 This is a schematic diagram of the finite element displacement method of the material balance method in an embodiment of the present invention.

[0032] Figure 4 This is a schematic diagram of the rock ion exchange ratio model in an embodiment of the present invention.

[0033] Figure 5 This is a schematic diagram of the theoretical forward modeling interpretation results in an embodiment of the present invention.

[0034] Figure 6This is a schematic diagram comparing numerical simulations using laboratory environmental data with experimental data in an embodiment of the present invention.

[0035] Figure 7 This is a schematic diagram illustrating the effect of oil enhancement and potential tapping in a practical application of this invention. Detailed Implementation

[0036] 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.

[0037] 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.

[0038] Example 1 See Figures 1 to 6 Taking into full account the complexity of the constantly changing injected water and formation water and the release of ion exchange during the waterflooding process, this invention provides a method for calculating the resistivity and saturation of the water-flooded layer mixture. It fully considers the complete closure of the experimental process and uses an oil-water phase-permeability controlled ion flooding displacement exchange interpretation and evaluation model to simulate the entire waterflooding process. (See also...) Figure 2 Here, reservoir porosity is set. Permeability K, formation temperature T, rock electrical parameters a, b, cementation index m, saturation index n, injected water salinity P j Formation water salinity (Po), and oil viscosity at the measurement temperature. Measure the viscosity of the injected water at the specified temperature. These fundamental parameters are known. Based on the theory of mass balance and following the evaluation approach of the finite element method, see [link to relevant documentation]. Figure 3 The dynamic mass balance equation for the water-drive process of the observed sample is: SALT sw =SALT 注入水+ SALT 岩石水 -SALT 驱替水 SALT 岩石水 It is an iterative and cyclical change, SALT 岩石水1 = SALT 束缚水 SALT 岩石水2 = SALT sw1 ...that is, at any point in time when the water saturation is at any given level, its total salinity (SALT) is... sw This will equal the salt content of the injected water at the previous moment + the salt content of the rock sample itself minus the salt content of the water displaced from the sample.

[0039] This invention provides the following steps: Calculate the volume of oil displaced from the rock sample at the initial waterflood stage k. and the volume of water displaced In the initial water drive stage, k=1, corresponding to a water saturation level of... ; Volume of displacement oil ; the volume of water displaced ; in, Reservoir porosity; The water saturation level is T; the flooding time is T. Oil flow rate; Water flow rate; Based on the volume of the displacement oil obtained and the volume of water displaced, V 驱替水 (k) Calculate the injected water volume ; Volume of water injected The calculation formula is: = + ; Based on the obtained injected water volume Calculate the salinity of the injected water ; and calculate the contact ratio Pe between injected water and formation water, and the salinity of the formation water. Salinity of the displaced water Salinity of the injected water The calculation formula is: ; Salinity of rock water The calculation formula is: ; Salinity of the displaced water The calculation formula is: =(SALT 注入水 (k)+ SALTSw (k-1)) ( ) Pe; = ; Among them, P j P0 represents the salinity of the injected water, while P0 represents the salinity of the original formation water. During the flooding process, the contact ratio between the injected water and the rock formation water is Pe= ; Based on the salinity of the injected water Salinity of rock water Salinity of the displaced water The salinity of the rock sample was obtained. The salinity of the rock sample = (SALT 注入水 (k)+ SALT 岩石水 (k))-SALT 驱替水 (k); Based on the salinity of the obtained rock samples Calculate the total mineralization of the rock sample. Total mineralization of rock samples The resistivity value of the formation water mixture was obtained by combining the ambient temperature T. ; Based on the obtained resistivity value of the formation water mixture The water saturation of k at this stage of water drive is obtained by combining the Alzer formula. Corresponding formation resistivity (k); The total mineralization of the rock sample is PPT(k) = SALT Sw (k) / S w (k)); the above ; The Alzi formula is: ; Where T is the ambient temperature in degrees Fahrenheit, a and b are lithology coefficients, and R is the lithology coefficient. wz R represents the total resistivity of the mixed liquid in the formation pores. t denoted as φ, where φ is the formation resistivity, φ is the formation porosity, m is the cementation index, and n is the saturation index. season k = k + 1, repeat steps 1 to 6 until... The calculation ends when the formation water mixture resistivity value for each water drive stage is obtained. (k) and formation resistivity ,in, It is the residual oil saturation. To bind water saturation.

[0040] The present invention is verified by comparing the experimental data of water-driven rock physics. The present invention will be further described in detail below with reference to the accompanying drawings and specific embodiments.

[0041] Basic parameters were collected from two samples, CJ13-4-1 and CJ13-4-2. The parameters were the same: simulated oil viscosity 14 mPa·s, injected water viscosity 0.914 mPa·s, rock electrical parameters a=1, b=1, m=1.714, n=2.127, and temperature 24℃. The parameters differed: Sample CJ13-4-1 had a porosity of 24.4%, permeability of 419 mD, bound water saturation of 27.64%, residual oil saturation of 31.53%, and displacement water salinity of 500 mg / L (sodium chloride solution); Sample CJ13-4-2 had a porosity of 25.4%, permeability of 518 mD, bound water saturation of 25.16%, residual oil saturation of 31.67%, and displacement water salinity of 80000 mg / L (sodium chloride solution). The calculation and verification were performed using CJ13-4-1 as an example.

[0042] The table below compares laboratory measurement data with model calculation data:

[0043] According to Darcy's law, it can be clearly determined from steady-state displacement experiments that K0 = K w = K ro = ; Processing results ; Where A is the cross-sectional area of ​​the rock sample in m. 2 L is the length of the rock sample; P1 and P2 are the pressures at both ends of the rock sample, in MPa; K o（Swi） K represents the effective permeability of the oil phase in the bound water state. w K represents the effective permeability of the aqueous phase. rw The relative permeability of the aqueous phase; K ro This represents the relative permeability of the oil phase.

[0044] calculate / = =0.914 / 14*K rw / K ro =0.0652*K rw / K ro S1, calculate the volume of oil displaced by the rock sample when k=1 in the initial waterflood stage. and the volume of water displaced At this point, the comparison value is Sw(1) = 32.36%; Calculate V 驱替油 (1)= Sw(1)-Sw(1-1))=0.244 Sw(1)-Sw(0))=0.244*(0.3236-0.2764)=0.012; V 驱替水 (1) = V 驱替油 (1) / = 0.012*0.0652*0.0026 / 0.717=2.83e-6; S2, based on the volume of the displacement oil and the volume of water displaced calculate V 注入水 (1)=V 驱替油 (1)+V 驱替水 (1) = 0.012; S3, based on the obtained injected water volume Calculate the salinity of the injected water The contact ratio Pe between injected water and formation water, and the salinity of the formation water were calculated. Salinity of the displaced water ; Pe= = = =0.11; SALT 注入水 (1) = V 注入水 (1) P j = 0.012 * 500 = 6.08 SALT 岩石水 (1) = SALT Sw (0) = SALT Swi = = 160000 * 0.244 * 0.2764 = 10790.656 SALT 驱替水 (1) = (SALT) 注入水 (1)+ SALT Sw (0)) ( ) Pe = 8.875 SALT Sw (1) = (SALT 注入水 (1)+ SALT Sw(0))-SALT 驱替水 (1) = 10787.86; SALT 驱替水 (1) = (SALT) 注入水 (1)+ SALT Sw (0)) ( ) Pe = 8.875 S4, based on the obtained salinity of the injected water Salinity of rock water Salinity of the displaced water The salinity of the rock sample was obtained. ; SALT Sw (1) = (SALT 注入水 (1)+ SALT Sw (0))-SALT 驱替水 (1) = 10787.86 S5, according to PPT(1) = SALT Sw (1) / S w (1) Calculate the mineralization at the corresponding water saturation level, and get PPT(1) = PPT(SW1) = 136627.2ppm. At this time, the ambient temperature is 24℃, which is converted to 75.2℉. According to Rwz = ( ) 0.88 The conversion yields Rwz(1) = 0.050 Ω·m; S6, based on the obtained resistivity value of the formation water mixture Combining the Archie formula At this point, the water saturation of water drive stage 1 is... Corresponding formation resistivity (1); S7, at this time ,make k=k+1, repeat S1~S6 until... The calculation ends at that time. See the comparison table of laboratory measurement data and model calculation data. The fourth column of the table shows the calculation results of this method, and the fifth column shows the laboratory measurement results.

[0045] Appendix Figure 5 This is a comparison chart of laboratory measurement data and calculated data of the original formation water salinity of 1,600,000 ppm under two injection water salinity conditions of 500 ppm and 80,000 ppm, respectively. The overall comparison results show good consistency, confirming that the interpretation and evaluation scheme has accuracy, reliability and applicability.

[0046] Example 2 This invention uses a typical water-flooded formation logging well from an oilfield as an example, see reference. Figure 7 This figure shows the actual effect of the invention in oilfield application. The first channel is the three-porosity curve, including sonic transit time, compensated density, and compensated seed; the second channel is the lithology channel, including natural gamma, spontaneous potential, and well diameter; the third channel is the sandstone group, generally provided by oilfield geologists through multi-well comparison; the fourth channel is the depth channel; the fifth channel is the interpretation conclusion channel; the sixth channel is the suggested perforation interval channel; the seventh channel is microsphere focusing and dual lateral resistivity; the eighth channel is the array induced resistivity; the ninth and tenth channels are rapid evaluation qualitative method identification channels; the eleventh channel is the clay content and calculated lithological profile; the eleventh and twelfth channels are the calculated porosity and permeability; the thirteenth channel is the saturation calculated using the invention; the fourteenth channel is the calculated bound water and residual oil saturation; the fifteenth channel is the calculated oil-water relative permeability; and the sixteenth channel is the calculated water cut. The main objective of this well is to tap the potential and increase efficiency of the old oilfield. The recommended perforated section was tested to avoid strong water flooding of the reservoir. The initial daily production was 7.16 cubic meters of fluid, 5.95 tons of oil, and 1.21 cubic meters of water, with a water production rate of 16.90%. The cumulative oil production was 378.58 tons.

[0047] The present invention also provides an electronic device, the electronic device comprising: a memory storing executable instructions; and a processor, the processor executing the executable instructions in the memory to implement the above-described method for calculating the resistivity and saturation of the water-flooded layer mixture.

[0048] The present invention also provides a computer-readable storage medium storing a computer program that, when executed by a processor, implements the above-described method for calculating the resistivity and saturation of the water-flooded layer mixture.

[0049] Those skilled in the art will understand that embodiments of the present invention can be provided as methods, systems, or computer program products. Therefore, the present invention can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, the present invention can take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0050] The foregoing has shown and described the basic principles, main features, and advantages of the present invention. It will be apparent to those skilled in the art that the invention is not limited to the details of the exemplary embodiments described above, and that the invention can be implemented in other specific forms without departing from its spirit or essential characteristics. Therefore, the embodiments should be considered illustrative and non-limiting in all respects, and the scope of the invention is defined by the appended claims rather than the foregoing description. Thus, all variations falling within the meaning and scope of equivalents of the claims are intended to be included within the scope of the invention. No reference numerals in the claims should be construed as limiting the scope of the claims.

Claims

1. A method for calculating the resistivity and saturation of a water-flooded layer mixture, characterized in that, Includes the following steps: S1, calculate the volume of oil displaced from the rock sample at the initial waterflood stage k. and the volume of water displaced ; S2, based on the volume of the displaced oil obtained. and the volume of water displaced, V 驱替水 (k) Calculate the injected water volume : S3, based on the obtained injected water volume Calculate the salinity of the injected water ; and calculate the contact ratio Pe between injected water and formation water, and the salinity of the formation water. Salinity of the displaced water ; S4, based on the obtained salinity of the injected water Salinity of rock water Salinity of the displaced water The salinity of the rock sample was obtained. ; S5, based on the salinity of the obtained rock sample Calculate the total mineralization of the rock sample. Total mineralization of rock samples The resistivity value of the formation water mixture was obtained by combining the ambient temperature T. ; S6, based on the obtained resistivity value of the formation water mixture The water saturation of k at this stage of water drive is obtained by combining the Alzer formula. Corresponding formation resistivity (k); S7, season k=k+1, repeat S1~S6 until... The calculation ends when the formation water mixture resistivity value for each water drive stage is obtained. (k) and formation resistivity ,in, It is the residual oil saturation. To bind water saturation.

2. The method for calculating the resistivity and saturation of a water-flooded layer mixture according to claim 1, characterized in that, In S7, x is Step size increment, .

3. The method for calculating the resistivity and saturation of a water-flooded layer mixture according to claim 1, characterized in that, In S1, during the initial water drive stage, k=1, corresponding to a water saturation level of... ; Volume of displacement oil ; the volume of water displaced ; in, Reservoir porosity; The water saturation level is T; the flooding time is T. Oil flow rate; This refers to the water flow rate.

4. The method for calculating the resistivity and saturation of a water-flooded layer mixture according to claim 3, characterized in that, According to Darcy's law, it can be clearly determined from steady-state displacement experiments that K0 = K w = K ro = The ratio of water flow rate to oil flow rate obtained after processing: ; Where A is the cross-sectional area of ​​the rock sample in m. 2 L is the length of the rock sample; P1 and P2 are the pressures at both ends of the rock sample, in mPa; K o（Swi） K represents the effective permeability of the oil phase in the bound water state. w K represents the effective permeability of the aqueous phase. rw The relative permeability of the aqueous phase; K ro This represents the relative permeability of the oil phase.

5. The method for calculating the resistivity and saturation of a water-flooded layer mixture according to claim 1, characterized in that, In S2, the volume of water injected... The calculation formula is: = + 。 6. The method for calculating the resistivity and saturation of a water-flooded layer mixture according to claim 1, characterized in that, In S3, the salinity of the injected water The calculation formula is: ; Salinity of rock water The calculation formula is: ； initial state = SALT Sw (0) = SALT Swi = ; Salinity of the displaced water The calculation formula is: =(SALT 注入水 (k)+ SALT Sw (k-1)) ( ) Pe; = ； Among them, P j P0 represents the salinity of the injected water, while P0 represents the salinity of the original formation water. During the flooding process, the contact ratio between the injected water and the rock formation water is Pe= .

7. The method for calculating the resistivity and saturation of a water-flooded layer mixture according to claim 1, characterized in that, In S4, the salinity of the rock sample = (SALT 注入水 (k)+ SALT 岩石水 (k))-SALT 驱替水 (k).

8. The method for calculating the resistivity and saturation of a water-flooded layer mixture according to claim 1, characterized in that, In S6, the total mineralization of the rock sample is PPT(k) = SALT Sw (k) / S w (k)); the above ; The Alzi formula is: ; Where T is the ambient temperature in degrees Fahrenheit, a and b are lithology coefficients, and R is the lithology coefficient. wz R represents the total resistivity of the mixed liquid in the formation pores. t denoted as ρ, where φ is the formation resistivity, φ is the formation porosity, m is the cementation index, and n is the saturation index.

9. An electronic device, characterized in that, The electronic device includes: Memory, which stores executable instructions; A processor that executes the executable instructions in the memory to implement the method for calculating the resistivity and saturation of the water-flooded layer mixture according to any one of claims 1-8.

10. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores a computer program that, when executed by a processor, implements a method for calculating the resistivity and saturation of the water-flooded layer mixture according to any one of claims 1-8.

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