Experimental device and method for relative permeability and method for determining relative permeability

Abstract

According to the experimental device and method for the relative permeability and the determination method for the relative permeability, the experimental device for the relative permeability is arranged, a test is conducted through the experimental device for the relative permeability, the gas-liquid-sulfur two-phase co-permeation condition under the real reservoir condition can be simulated, accurate parameters can be obtained, and the relative permeability is determined. Therefore, the calculation precision of the relative permeability can be improved.

Description

Technical Field

[0001] The present application relates to the technical field of oil and gas layer physics, and in particular to a relative permeability experimental device and method and a relative permeability determination method. Background Art

[0002] High-sulfur gas reservoirs are distributed all over the world. With the continuous development of oil exploration technology, more and more high-sulfur gas reservoirs have been discovered and developed worldwide. In the process of natural gas extraction, as the gas is produced, the temperature and pressure of the formation decrease, the solubility of sulfur in natural gas decreases, and it aggregates and precipitates. When the temperature is higher than the melting point of sulfur, the sulfur will exist in the form of liquid sulfur. At this time, a multiphase flow of water-hydrogen sulfide gas-sulfur will be formed in the reservoir, and its flow characteristics and seepage laws are complex.

[0003] The study on the relative permeability of liquid sulfur and natural gas in porous media is mainly based on indoor physical experiments, among which the calculation accuracy of liquid sulfur viscosity and the measurement accuracy of liquid sulfur flow rate are crucial to the reliability of the final gas-liquid sulfur relative permeability experimental results.

[0004] Some experimental devices and methods are provided in the related art. In the process of measuring liquid sulfur, it is mostly measured by a high-precision balance. However, in the actual experimental process, due to the simultaneous flow of gas and liquid sulfur at the outlet, the value of the high-precision balance will have data jump segments due to the change in gas flow, resulting in increased measurement errors, making it difficult to stably measure the displacement of liquid sulfur, and unable to accurately test the gas-liquid sulfur phase permeability curve. The related art also provides a high-temperature, high-pressure, high-sulfur gas reservoir gas-liquid sulfur phase permeability curve test device and method, which uses a high-temperature, high-pressure gas-liquid separation device and a high-precision magnetic suspension balance to achieve gas-liquid sulfur separation and liquid sulfur measurement. There are several main implementation methods of high-temperature, high-pressure gas-liquid separation devices: gravity sedimentation, baffle separation, centrifugal separation, packing separation, screen separation, microporous filtration separation, etc. Most of these separation forms cannot resist liquid sulfur and cannot guarantee sufficient gas-liquid sulfur separation efficiency, resulting in a low accuracy in determining the relative permeability of gas-liquid sulfur. Summary of the invention

[0005] In view of the above problems, the present application provides an experimental device and method for relative permeability and a method for determining relative permeability. By conducting experiments using the experimental device, more accurate parameters can be obtained, thereby improving the calculation accuracy of relative permeability.

[0006] The embodiment of the present application provides a relative permeability experimental device, comprising: a gas sample intermediate container, a gas booster pump, a liquid sulfur intermediate container, a constant speed and constant pressure pump, a core clamp, an oven, a confining pressure pump, a confining pressure valve, a back pressure pump, an exhaust gas recovery device, a visualization container, a liquid recovery device, and a gas meter, wherein one end of the gas intermediate container is connected to the gas booster pump through a first valve, the other end of the gas intermediate container is connected to the input end of the core clamp through a second valve and a fourth valve, one end of the liquid sulfur intermediate container is connected to the constant speed and constant pressure pump through a third valve, and the liquid sulfur intermediate container is connected to the constant speed and constant pressure pump through a third valve. The other end of the device is connected with the input end of the core clamp through the fifth valve and the fourth valve, the confining pressure pump is connected with the core clamp through the sixth valve, the output end of the core clamp is connected with the confining pressure valve through the seventh valve, the confining pressure valve is connected with the back pressure pump through the eighth valve, the confining pressure valve is connected with the visualization container, the visualization container is connected with the exhaust gas recovery device through the gas meter, the visualization container is connected with the liquid recovery device through the ninth valve, the gas sample intermediate container, the liquid sulfur intermediate container, the core clamp, the confining pressure valve and the visualization container are arranged in the oven.

[0007] In some embodiments, a first pressure gauge is disposed at the input end of the core holder, and a second pressure gauge is disposed at the output end of the core holder.

[0008] In some embodiments, the relative permeability experimental device further includes: a laser liquid level meter, used to measure the liquid level in the visualization container.

[0009] The present application embodiment provides an experimental method, which is applied to any of the above-mentioned relative permeability experimental devices, including:

[0010] Selecting a core sample, making a target core saturated with formation water based on the core sample, loading the target core saturated with formation water into a core holder, adding a target gas sample into a gas sample intermediate container, and boosting the pressure of the target gas sample to a target fluid pressure by a gas booster pump;

[0011] Adding a preset amount of sulfur powder into the liquid sulfur intermediate container, pressurizing the core holder through a confining pressure pump, and heating the core through an oven so that the confining pressure of the target core in the core holder reaches the formation pressure and the temperature reaches the formation temperature;

[0012] When the oven temperature reaches the formation temperature and is maintained for a preset time to melt the sulfur powder, the pressure of the liquid sulfur is pushed to the target fluid pressure by a constant speed and constant pressure pump, the pressure of the back pressure pump is controlled to gradually decrease with the target fluid pressure, and the flow rate of the liquid sulfur at different times is measured;

[0013] Close all valves and open the ninth valve, control the visualization container to discharge water into the liquid recovery device, and record the quality of the discharged water in the liquid recovery device;

[0014] Open the first valve and the second valve, boost the pressure of the target gas sample to the target fluid pressure through a gas booster pump, open the seventh valve and the fourth valve, continuously record the flow rate of liquid sulfur in the visualization container at different times, and record the gas flow rate at different times through the gas meter.

[0015] The present application provides a method for determining relative permeability, including:

[0016] Obtaining parameters of core samples, viscosity of liquid sulfur at formation temperature and formation pressure, volume coefficient of liquid sulfur at formation temperature and formation pressure, gas flow rate at different times of the target core based on the above experimental method, mass of discharged water and flow rate of liquid sulfur at different times;

[0017] calculating irreducible water saturation of the core sample based on the mass of the discharged water;

[0018] Calculating the liquid sulfur permeability under irreducible water conditions based on the flow rate of the liquid sulfur, parameters of the core sample, viscosity of the liquid sulfur at the formation temperature and formation pressure, volume coefficient of the liquid sulfur at the formation temperature and formation pressure, and the irreducible water saturation;

[0019] Correcting the gas flow rate to obtain a target gas flow rate under the formation pressure and temperature conditions;

[0020] Calculate the effective gas permeability at each moment based on the target gas flow rate;

[0021] Calculating the gas phase relative permeability at each moment based on the gas phase effective permeability at each moment;

[0022] The relative permeability of liquid sulfur at each time point is calculated based on the liquid sulfur permeability under bound water conditions and the flow rate of liquid sulfur.

[0023] In some embodiments, the method further comprises:

[0024] Calculate the sulfur saturation in the core samples at each time;

[0025] The gas saturation of the core sample at each moment is calculated based on the sulfur saturation and the irreducible water saturation.

[0026] In some embodiments, the calculation of the liquid sulfur permeability under irreducible water conditions based on the flow rate of the liquid sulfur, the parameters of the core sample, the viscosity of the liquid sulfur at the formation temperature and the formation pressure, the volume coefficient of the liquid sulfur at the formation temperature and the formation pressure, and the irreducible water saturation includes:

[0027] The liquid sulfur permeability under irreducible water conditions is calculated using a first calculation formula based on the flow rate of the liquid sulfur, the parameters of the core sample, the viscosity of the liquid sulfur at the formation temperature and the formation pressure, the volume coefficient of the liquid sulfur at the formation temperature and the formation pressure, and the irreducible water saturation, wherein the first calculation formula includes:

[0028]

[0029] Among them, K S is the liquid sulfur permeability under bound water conditions, B S is the liquid sulfur volume coefficient under formation temperature and pressure conditions, q S is the flow rate of liquid sulfur, μ S is the viscosity of liquid sulfur under formation temperature and pressure conditions, L is the length of the core sample, A is the cross-sectional area of ​​the core sample, P1 is the pressure at the inlet end of the core sample, and P2 is the pressure at the outlet end of the core sample.

[0030] In some embodiments, the calculating irreducible water saturation of the core sample based on the mass of the discharged water comprises:

[0031] Based on the mass of the discharged water, the irreducible water saturation of the core sample is calculated using a second calculation formula, wherein the second calculation formula includes:

[0032]

[0033] Among them, Swi is the irreducible water saturation, m1 is the dry core mass, m2 is the core mass after saturation with formation water, and m3 is the discharged water mass.

[0034] In some embodiments, the correcting the gas flow rate to obtain the target gas flow rate under the formation pressure and temperature conditions includes:

[0035] The gas flow rate is corrected based on a third calculation formula to obtain a target gas flow rate under the formation pressure and temperature conditions, wherein the third calculation formula includes:

[0036]

[0037] Where q1 is the target gas flow rate under formation temperature and pressure conditions, Z1 is the gas deviation coefficient under formation temperature and pressure conditions, P3 is the fluid pressure, P atm is the atmospheric pressure, and Z2 is the deviation coefficient of gas under the conditions of atmospheric pressure and formation temperature.

[0038] In some embodiments, the step of calculating the gas phase effective permeability at each moment based on the target gas flow rate includes:

[0039] The gas phase relative permeability at each moment is calculated using a fourth calculation formula based on the target gas flow rate, wherein the fourth calculation formula includes:

[0040]

[0041] Among them, K g is the effective permeability of the gas phase; ug is the viscosity of the gas at the formation temperature and pressure, where P1 and P2 are constants.

[0042] In some embodiments, the step of calculating the gas phase relative permeability at each moment based on the gas phase effective permeability at each moment includes:

[0043] The gas phase relative permeability at each moment is calculated using the fifth calculation formula based on the gas phase effective permeability at each moment, wherein the fifth calculation formula includes:

[0044]

[0045] The relative permeability of liquid sulfur at each moment is calculated based on the liquid sulfur permeability under bound water conditions and the flow rate of liquid sulfur, wherein the sixth calculation formula includes:

[0046]

[0047] In some embodiments, the calculating the sulfur saturation in the core sample at each time comprises:

[0048] The seventh calculation formula is used to calculate the sulfur saturation in the core sample at each time, wherein the seventh calculation formula includes:

[0049]

[0050] Among them, Ss is the sulfur saturation, V Si V is the reading of the liquid sulfur pumped in at the constant speed and pressure at time i. S0 is the reading of the constant speed and constant pressure pump pumping liquid sulfur at the initial moment, Vx is the pipeline loss before the constant speed and constant pressure pump pumps into the core holder;

[0051] The calculating the gas saturation of the core sample at each moment based on the sulfur saturation and the irreducible water saturation includes:

[0052] The gas saturation of the core sample at each moment is calculated using an eighth calculation formula based on the sulfur saturation and the irreducible water saturation, wherein the eighth calculation formula includes:

[0053] S g =1-S wi -S S ;

[0054] Among them, S gis the gas saturation.

[0055] The present application embodiment provides a relative permeability determination device, including:

[0056] An acquisition module is used to obtain parameters of core samples, liquid sulfur viscosity at formation temperature and formation pressure, volume coefficient of liquid sulfur at formation temperature and formation pressure, gas flow rate at different times of the target core obtained based on the above experimental method, discharged water mass and liquid sulfur flow rate at different times;

[0057] A first calculation module, configured to calculate irreducible water saturation of the core sample based on the mass of the discharged water;

[0058] A second calculation module is used to calculate the liquid sulfur permeability under irreducible water conditions based on the flow rate of the liquid sulfur, the parameters of the core sample, the viscosity of the liquid sulfur at the formation temperature and formation pressure, the volume coefficient of the liquid sulfur at the formation temperature and formation pressure, and the irreducible water saturation;

[0059] A correction module, used for correcting the gas flow rate to obtain a target gas flow rate under the formation pressure and temperature conditions;

[0060] A third calculation module is used to calculate the gas phase effective permeability at each moment based on the target gas flow rate;

[0061] A fourth calculation module, used for calculating the gas phase relative permeability at each moment based on the gas phase effective permeability at each moment;

[0062] The fifth calculation module is used to calculate the relative permeability of liquid sulfur at each moment based on the liquid sulfur permeability under the irreducible water condition and the flow rate of liquid sulfur.

[0063] An embodiment of the present application provides an electronic device, including a memory and a processor, wherein a computer program is stored in the memory, and when the computer program is executed by the processor, any one of the relative permeability determination methods described above is executed.

[0064] An embodiment of the present application provides a storage medium, which stores a computer program that can be executed by one or more processors and can be used to implement any of the relative permeability determination methods described above.

[0065] The present application provides a relative permeability experimental device, method and relative permeability determination method. By setting up the relative permeability experimental device and conducting experiments through the relative permeability experimental device, it is possible to simulate the gas-liquid-sulfur two-phase co-permeability under real reservoir conditions and obtain more accurate parameters, thereby improving the calculation accuracy of the relative permeability. BRIEF DESCRIPTION OF THE DRAWINGS

[0066] Hereinafter, the present application will be described in more detail based on embodiments and with reference to the accompanying drawings.

[0067] Figure 1 A schematic diagram of the structure of a relative permeability experimental device provided in an embodiment of the present application;

[0068] Figure 2 A schematic diagram of an implementation flow of an experimental method provided for this application example;

[0069] Figure 3 A schematic diagram of a process flow for implementing a method for determining relative permeability provided in an embodiment of the present application;

[0070] Figure 4 A schematic diagram of a gas-liquid sulfur relative permeability curve provided in an embodiment of the present application;

[0071] Figure 5 A schematic diagram of the structure of an electronic device provided in an embodiment of the present application.

[0072] In the drawings, the same reference numerals are used for the same components and the drawings are not drawn to scale. DETAILED DESCRIPTION

[0073] In order to make the purpose, technical solutions and advantages of the present application clearer, the present application will be further described in detail below in conjunction with the accompanying drawings. The described embodiments should not be regarded as limiting the present application. All other embodiments obtained by ordinary technicians in the field without making creative work are within the scope of protection of this application.

[0074] In the following description, reference is made to “some embodiments”, which describe a subset of all possible embodiments, but it will be understood that “some embodiments” may be the same subset or different subsets of all possible embodiments and may be combined with each other without conflict.

[0075] If similar descriptions of "first\second\third" appear in the application documents, the following instructions will be added. In the following description, the terms "first\second\third" involved are merely used to distinguish similar objects and do not represent a specific ordering of the objects. It can be understood that "first\second\third" can be interchanged in a specific order or sequence where permitted, so that the embodiments of the present application described herein can be implemented in an order other than that illustrated or described herein.

[0076] Unless otherwise defined, all technical and scientific terms used herein have the same meaning as those commonly understood by those skilled in the art to which this application belongs. The terms used herein are only for the purpose of describing the embodiments of this application and are not intended to limit this application.

[0077] Embodiment 1

[0078] Based on the problems existing in the related art, the present application provides a relative permeability experimental device. Figure 1 A schematic diagram of a relative permeability experimental device provided in an embodiment of the present application is shown in FIG. Figure 1 As shown, it includes: a gas sample intermediate container 3, a gas booster pump 1, a liquid sulfur intermediate container 23, a constant speed and pressure pump 6, a core holder 11, an oven 20, a confining pressure pump 9, a confining pressure valve 15, a back pressure pump 14, an exhaust gas recovery device 26, a visualization container 18, a liquid recovery device 16, and a gas meter 19. One end of the gas intermediate container 3 is connected to the gas booster pump 1 through a first valve 2, and the other end of the gas intermediate container 3 is connected to the input end of the core holder 11 through a second valve 4 and a fourth valve 8. One end of the liquid sulfur intermediate container 23 is connected to the constant speed and pressure pump 6 through a third valve 7, and the other end of the liquid sulfur intermediate container 23 is connected to the fifth valve 5 and the fifth valve 8. The fourth valve 8 is connected to the input end of the core clamp 11, the confining pressure pump 9 is connected to the core clamp 11 through the sixth valve 10, the output end of the core clamp 11 is connected to the confining pressure valve 15 through the seventh valve 12, the confining pressure valve 15 is connected to the back pressure pump 14 through the eighth valve 13, the confining pressure valve 15 is connected to the visualization container 18, the visualization container 18 is connected to the exhaust gas recovery device 26 through the gas meter 19, the visualization container 18 is connected to the liquid recovery device 16 through the ninth valve 17, and the gas sample intermediate container 3, the liquid sulfur intermediate container 23, the core clamp 11, the confining pressure valve 15 and the visualization container 18 are arranged in the oven 20.

[0079] In the embodiment of the present application, each valve can be opened and closed to connect the corresponding pipeline. In the embodiment of the present application, when connected, the connection is made through the pipeline, and the valve is set on the pipeline to achieve the connection or disconnection of the pipeline.

[0080] In the embodiment of the present application, the oven is used to simulate the formation temperature, and the confining pressure pump is used to simulate the formation pressure. The gas sample intermediate container is used to store the target gas sample, the gas booster pump is used to pressurize the target gas sample, the liquid sulfur intermediate container is used to store sulfur powder, the constant speed and constant pressure pump is used to pressurize the liquefied sulfur powder, the core holder is used to place the core sample, and a closed space can be formed in the core holder. The back pressure pump is used to provide pressure, the exhaust gas recovery device can contain sodium hydroxide to absorb the exhaust gas, the visualization container is used to contain liquid, the liquid recovery device can be a conical flask for recovering liquid, and the gas meter is used to measure the gas flow.

[0081] The test device provided in the embodiment of the present application can simulate formation conditions to conduct experiments, thereby making the obtained parameters more accurate.

[0082] In some embodiments, see Figure 1 A first pressure gauge 21 is provided at the input end of the core holder, and a second pressure gauge 22 is provided at the output end of the core holder.

[0083] In the embodiment of the present application, the first pressure gauge and the second pressure gauge can measure the pressure in the pipeline.

[0084] In some embodiments, the relative permeability experimental device further includes: a laser liquid level meter 24 for measuring the liquid level in the visualization container.

[0085] In the embodiment of the present application, the laser liquid level meter can accurately measure the liquid level in the visualization container.

[0086] In some embodiments, see Figure 1 The relative permeability experimental device also includes: a computer 25, which is communicatively connected with the laser liquid level meter 24 and the gas meter 19.

[0087] Embodiment 2

[0088] Based on the above embodiments, the present application further provides an experimental method, which is applied to a relative permeability experimental device provided in the above embodiments. Figure 2 A schematic diagram of the implementation process of an experimental method provided for this application example, such as Figure 2 As shown, the method includes:

[0089] Step S101, select a core sample, make a target core saturated with formation water based on the core sample, load the target core saturated with formation water into a core holder, add a target gas sample into a gas sample intermediate container, and boost the pressure of the target gas sample to a target fluid pressure through a gas booster pump.

[0090] In the embodiment of the present application, a representative core sample in the formation can be selected, and the core sample can be extracted, cleaned, and dried according to the corresponding standard. After the processing, the length L, diameter d, and core porosity of the core sample can be measured. Permeability K, mass m. According to the on-site water sample data, the formation water corresponding to the mineralization conditions is configured, the core is vacuumed and saturated with formation water as the target core, and the core mass of the target core after saturation with formation water is recorded.

[0091] In the embodiment of the present application, the pressure of the target gas sample is boosted to the target fluid pressure by a gas booster pump and then kept for use.

[0092] Step S102, adding a preset amount of sulfur powder into the liquid sulfur intermediate container, pressurizing the core holder through a confining pressure pump, and heating the core through an oven, so that the confining pressure of the target core in the core holder reaches the formation pressure and the temperature reaches the formation temperature.

[0093] The preset amount of sulfur powder in the embodiment of the present application can be set according to the actual measured sulfur content in the selected formation.

[0094] In the embodiment of the present application, the sixth valve can be opened and then the confining pressure pump can be put into operation. When the confining pressure pump is working, the confining pressure is increased step by step, so that the target core is placed under the confining pressure conditions of the simulated formation.

[0095] In the embodiment of the present application, the oven is also turned on during this process, and the temperature is raised step by step to the formation temperature.

[0096] In the embodiments of the present application, both the formation temperature and the formation pressure can be measured by measuring the formation where the core sample is located.

[0097] Step S103, when the oven temperature reaches the formation temperature and is maintained for a preset time to melt the sulfur powder, the pressure of the liquid sulfur is pushed to the target fluid pressure by a constant speed and constant pressure pump, the pressure of the back pressure pump is controlled to gradually decrease with the target fluid pressure, and the flow rate of the liquid sulfur at different times is measured.

[0098] In the embodiment of the present application, the preset time length may be 120 minutes, within which the sulfur powder can be completely melted, and the sulfur powder exists in the form of liquid sulfur after melting.

[0099] In the embodiment of the present application, the third valve and the fifth valve can be opened. At this time, the pressure of liquid sulfur is pushed to the target fluid pressure by the constant speed and constant pressure pump. At this time, the fourth valve is opened until the pressure value of the constant speed and constant pressure pump increases to the target fluid pressure.

[0100] In an embodiment of the present application, pure NaOH liquid can be added to the waste gas recovery device and the waste liquid recovery device. At this time, the seventh valve and the eighth valve are opened, and the pressure of the back pressure pump is controlled to gradually decrease with the target fluid pressure. The bound water saturation is established by liquid sulfur driving water. First, liquid sulfur is driven by a low pressure difference, and then the displacement pressure difference is gradually increased until no water is driven to 10 times the pore volume, and the liquid sulfur content in the visualization container is recorded regularly by a laser level meter.

[0101] Step S104, close all valves and open the ninth valve, control the visualization container to discharge water into the liquid recovery device, and record the mass of the discharged water in the liquid recovery device.

[0102] After recording, close the ninth valve.

[0103] Step S105, open the first valve and the second valve, boost the pressure of the target gas sample to the target fluid pressure through a gas booster pump, open the seventh valve and the fourth valve, continuously record the flow rate of liquid sulfur in the visualization container at different times, and record the gas flow rate at different times through the gas meter.

[0104] In the embodiment of the present application, by opening the first valve and the second valve, the pressure of the target gas sample is increased to the target fluid pressure by a gas booster pump, and the seventh valve and the fourth valve are opened, thereby achieving gas-driven liquid sulfur.

[0105] In the embodiment of the present application, the content of liquid sulfur at different times can be measured by a laser level meter, and the gas flow rate at different times can be recorded by a gas meter.

[0106] In the embodiments of the present application, the experiment can be terminated after the gas phase relative permeability is lower than 0.005.

[0107] In the embodiment of the present application, relatively accurate flow rates of liquid sulfur at different times, gas flow rates at different times, and discharged water masses can be obtained through experiments, thereby improving the calculation accuracy of relative permeability.

[0108] Embodiment 3

[0109] Based on the above embodiments, the present application further provides a relative permeability determination method, which is applied to electronic devices, such as computers, mobile terminals, etc. The functions implemented by the relative permeability determination method provided in the present application embodiment can be implemented by calling program codes by a processor of the electronic device, wherein the program codes can be stored in a computer storage medium.

[0110] Figure 3 A schematic diagram of a method for determining relative permeability provided in an embodiment of the present application is shown in FIG. Figure 3 As shown, including:

[0111] Step S301, obtaining the parameters of the core sample, the viscosity of liquid sulfur at formation temperature and formation pressure, the volume coefficient of liquid sulfur at formation temperature and formation pressure, the gas flow rate at different times of the target core based on the above experimental method, the mass of discharged water and the flow rate of liquid sulfur at different times.

[0112] In the embodiment of the present application, the flow rate of liquid sulfur at different times, the parameters of the core sample, the viscosity of liquid sulfur at the formation temperature and formation pressure, the volume coefficient of liquid sulfur at the formation temperature and formation pressure, the gas flow rate and the discharged water mass at different times can be obtained through the input of the input device.

[0113] In an embodiment of the present application, the electronic device can be connected to a gas meter in a relative permeability experimental device for communication, and the gas flow rate at different times can be obtained through the gas meter. The electronic device can also be connected to a laser liquid level meter for communication, and the flow rate of liquid sulfur and the quality of discharged water at different times can be obtained through the laser liquid level meter.

[0114] In the embodiments of the present application, the gas flow rate at different times, the liquid sulfur flow rate at different times and the discharged water quality are obtained by conducting experiments using the above-mentioned relative permeability test device according to the experimental method provided in the above-mentioned embodiments.

[0115] Step S302: calculating irreducible water saturation of the core sample based on the mass of the discharged water.

[0116] In the embodiment of the present application, the calculating of the irreducible water saturation of the core sample based on the mass of the discharged water includes:

[0117] Based on the mass of the discharged water, the irreducible water saturation of the core sample is calculated using a second calculation formula, wherein the second calculation formula includes:

[0118]

[0119] Among them, Swi is the irreducible water saturation, m1 is the dry core mass, m2 is the core mass after saturation with formation water, and m3 is the discharged water mass.

[0120] Step S303, calculating the liquid sulfur permeability under irreducible water conditions based on the flow rate of the liquid sulfur, the parameters of the core sample, the viscosity of the liquid sulfur at the formation temperature and formation pressure, the volume coefficient of the liquid sulfur at the formation temperature and formation pressure, and the irreducible water saturation.

[0121] In the embodiment of the present application, the calculation of the liquid sulfur permeability under irreducible water conditions based on the flow rate of the liquid sulfur, the parameters of the core sample, the viscosity of the liquid sulfur at the formation temperature and the formation pressure, the volume coefficient of the liquid sulfur at the formation temperature and the formation pressure, and the irreducible water saturation includes:

[0122] The liquid sulfur permeability under irreducible water conditions is calculated using a first calculation formula based on the flow rate of the liquid sulfur, the parameters of the core sample, the viscosity of the liquid sulfur at the formation temperature and the formation pressure, the volume coefficient of the liquid sulfur at the formation temperature and the formation pressure, and the irreducible water saturation, wherein the first calculation formula includes:

[0123]

[0124] Among them, K S is the liquid sulfur permeability under bound water conditions, B S is the liquid sulfur volume coefficient under formation temperature and pressure conditions, q S is the flow rate of liquid sulfur, μS is the viscosity of liquid sulfur under formation temperature and pressure conditions, L is the length of the core sample, A is the cross-sectional area of ​​the core sample, P1 is the pressure at the inlet end of the core sample, and P2 is the pressure at the outlet end of the core sample.

[0125] In the examples of the present application, the method for determining the viscosity of liquid sulfur is as follows:

[0126]

[0127] in:

[0128] p1=-15.714; p2=-2632.7; p3=31.7693; p4=10.2424; p5=160.609; p6=-86.011;

[0129] p7=12.0568; p8=160.697; p9=11.4134; p10=-5.7979; p11=171790;

[0130] p12 = -1745064.2427; μ S It is mPa·s.

[0131] The viscosity of liquid sulfur calculated by this method at 143°C is 8.86 mPa·s, while the value in the published literature is 8.78 mPa·s. The value calculated in the related art is 0.00744 cp. The unit of the formula in the related art should be Pa·s, while the unit in the actual patent is mPa·s, which is 1000 times different. After correcting the unit of liquid sulfur viscosity, the calculated viscosity of liquid sulfur is 7.44 mPa·s, which is still lower than the accuracy calculated by the method for determining the viscosity of liquid sulfur provided in the embodiment of the present application.

[0132] Step S304, correcting the gas flow rate to obtain a target gas flow rate under the formation pressure and temperature conditions.

[0133] In the embodiment of the present application, the gas flow rate is corrected based on a third calculation formula to obtain a target gas flow rate under the formation pressure and temperature conditions, wherein the third calculation formula includes:

[0134]

[0135] Where q1 is the target gas flow rate under formation temperature and pressure conditions, Z1 is the gas deviation coefficient under formation temperature and pressure conditions, P3 is the fluid pressure, P atm is the atmospheric pressure, and Z2 is the deviation coefficient of gas under the conditions of atmospheric pressure and formation temperature.

[0136] In the embodiment of the present application, the gas deviation coefficient is solved by the DAK method:

[0137]

[0138]

[0139]

[0140] in:

[0141] A1=0.3265; A2=-1.07; A3=-0.5339; A4=0.01569; A5=-0.05165; A6=0.5475; A7=-0.7361; A8=0.1844; A9=0.1056; A10=0.6134; A11=0.721.

[0142] Step S305, calculating the gas phase effective permeability at each moment based on the target gas flow rate.

[0143] In the embodiment of the present application, the calculation of the gas phase effective permeability at each moment based on the target gas flow rate includes:

[0144] The gas phase relative permeability at each moment is calculated using a fourth calculation formula based on the target gas flow rate, wherein the fourth calculation formula includes:

[0145]

[0146] Among them, K g is the effective permeability of the gas phase; ug is the viscosity of the gas at the formation temperature and pressure, where P1 and P2 are constants.

[0147] In the embodiment of the present application, the viscosity of the gas can be determined by the Dempsey method:

[0148]

[0149] μ g1 =(1.709×10 -5 -2.062×10 -6 γ g )(1.8T+32)+8.188×10 -3 -6.15×10 -3 lg(γ g )

[0150] B0=-2.4621182; B1=2.97054714; B2=-0.286264054; B3=0.00805420522; B4= 2.80860949; B5=-3.49803305; B6=0.36037302; B7=-0.0104432413; B8=-0.7 93385684; B9=1.39643306; B10=-0.149144925; B11=0.00441015512; B12=0. 0839387178; B13=-0.186408846; B14=0.0203367881; B15=-0.000609579263.

[0151] μg1——Gas viscosity at atmospheric pressure and any temperature, mPa·s;

[0152] γg——relative density of gas.

[0153] Step S306, calculating the gas phase relative permeability at each moment based on the gas phase effective permeability at each moment.

[0154] In the embodiment of the present application, the gas phase relative permeability at each moment is calculated using the fifth calculation formula based on the gas phase effective permeability at each moment, wherein the fifth calculation formula includes:

[0155]

[0156] Step S307, calculating the relative permeability of liquid sulfur at each moment based on the liquid sulfur permeability under irreducible water conditions and the flow rate of liquid sulfur.

[0157] The relative permeability of liquid sulfur at each moment is calculated based on the liquid sulfur permeability under bound water conditions and the flow rate of liquid sulfur, wherein the sixth calculation formula includes:

[0158]

[0159] In some embodiments, the method further comprises:

[0160] Step S308, calculating the sulfur saturation in the core sample at each time.

[0161] In the embodiment of the present application, the seventh calculation formula is used to calculate the sulfur saturation in the core sample at each time, wherein the seventh calculation formula includes:

[0162]

[0163] Among them, Ss is the sulfur saturation, V Si V is the reading of the liquid sulfur pumped in at the constant speed and pressure at time i. S0is the reading of the constant speed and constant pressure pump pumping liquid sulfur at the initial moment, and Vx is the pipeline loss before the constant speed and constant pressure pump pumps into the core holder.

[0164] Step S309, calculating the gas saturation of the core sample at each moment based on the sulfur saturation and the irreducible water saturation.

[0165] In the embodiment of the present application, the gas saturation of the core sample at each moment is calculated using the eighth calculation formula based on the sulfur saturation and the irreducible water saturation, wherein the eighth calculation formula includes:

[0166] S g =1-S wi -S S ;

[0167] Among them, S g is the gas saturation.

[0168] Figure 4 A schematic diagram of a gas-liquid sulfur relative permeability curve provided in an embodiment of the present application is shown in FIG. Figure 4 shown.

[0169] The method provided in the embodiment of the present application, by setting up a relative permeability experimental device and conducting experiments through the relative permeability experimental device, can simulate the gas-liquid-sulfur two-phase co-permeability under real reservoir conditions and can obtain more accurate parameters, thereby improving the calculation accuracy of the relative permeability.

[0170] Embodiment 4

[0171] Based on the foregoing embodiments, the embodiments of the present application provide a device for determining relative permeability. The modules included in the device and the units included in the modules can be implemented by a processor in a computer device; of course, they can also be implemented by a specific logic circuit; in the implementation process, the processor can be a central processing unit (CPU), a microprocessor (MPU), a digital signal processor (DSP) or a field programmable gate array (FPGA), etc.

[0172] The embodiment of the present application provides a relative permeability determination device, and the relative permeability determination device includes:

[0173] An acquisition module is used to obtain parameters of core samples, liquid sulfur viscosity at formation temperature and formation pressure, volume coefficient of liquid sulfur at formation temperature and formation pressure, gas flow rate at different times of the target core obtained based on the above experimental method, discharged water mass and liquid sulfur flow rate at different times;

[0174] A first calculation module, configured to calculate irreducible water saturation of the core sample based on the mass of the discharged water;

[0175] A second calculation module is used to calculate the liquid sulfur permeability under irreducible water conditions based on the flow rate of the liquid sulfur, the parameters of the core sample, the viscosity of the liquid sulfur at the formation temperature and formation pressure, the volume coefficient of the liquid sulfur at the formation temperature and formation pressure, and the irreducible water saturation;

[0176] A correction module, used for correcting the gas flow rate to obtain a target gas flow rate under the formation pressure and temperature conditions;

[0177] A third calculation module is used to calculate the gas phase effective permeability at each moment based on the target gas flow rate;

[0178] A fourth calculation module, used for calculating the gas phase relative permeability at each moment based on the gas phase effective permeability at each moment;

[0179] The fifth calculation module is used to calculate the relative permeability of liquid sulfur at each moment based on the liquid sulfur permeability under the irreducible water condition and the flow rate of liquid sulfur.

[0180] In some embodiments, the relative permeability determination device is further used to:

[0181] Calculate the sulfur saturation in the core samples at each time;

[0182] The gas saturation of the core sample at each moment is calculated based on the sulfur saturation and the irreducible water saturation.

[0183] In some embodiments, the calculation of the liquid sulfur permeability under irreducible water conditions based on the flow rate of the liquid sulfur, the parameters of the core sample, the viscosity of the liquid sulfur at the formation temperature and the formation pressure, the volume coefficient of the liquid sulfur at the formation temperature and the formation pressure, and the irreducible water saturation includes:

[0184] The liquid sulfur permeability under irreducible water conditions is calculated using a first calculation formula based on the flow rate of the liquid sulfur, the parameters of the core sample, the viscosity of the liquid sulfur at the formation temperature and the formation pressure, the volume coefficient of the liquid sulfur at the formation temperature and the formation pressure, and the irreducible water saturation, wherein the first calculation formula includes:

[0185]

[0186] Among them, K Sis the liquid sulfur permeability under bound water conditions, B S is the liquid sulfur volume coefficient under formation temperature and pressure conditions, q S is the flow rate of liquid sulfur, μ S is the viscosity of liquid sulfur under formation temperature and pressure conditions, L is the length of the core sample, A is the cross-sectional area of ​​the core sample, P1 is the pressure at the inlet end of the core sample, and P2 is the pressure at the outlet end of the core sample.

[0187] In some embodiments, the calculating irreducible water saturation of the core sample based on the mass of the discharged water comprises:

[0188] Based on the mass of the discharged water, the irreducible water saturation of the core sample is calculated using a second calculation formula, wherein the second calculation formula includes:

[0189]

[0190] Among them, Swi is the irreducible water saturation, m1 is the dry core mass, m2 is the core mass after saturation with formation water, and m3 is the discharged water mass.

[0191] In some embodiments, the correcting the gas flow rate to obtain the target gas flow rate under the formation pressure and temperature conditions includes:

[0192] The gas flow rate is corrected based on a third calculation formula to obtain a target gas flow rate under the formation pressure and temperature conditions, wherein the third calculation formula includes:

[0193]

[0194] Where q1 is the target gas flow rate under formation temperature and pressure conditions, Z1 is the gas deviation coefficient under formation temperature and pressure conditions, P3 is the fluid pressure, P atm is the atmospheric pressure, and Z2 is the deviation coefficient of gas under the conditions of atmospheric pressure and formation temperature.

[0195] In some embodiments, the step of calculating the gas phase effective permeability at each moment based on the target gas flow rate includes:

[0196] The gas phase relative permeability at each moment is calculated using a fourth calculation formula based on the target gas flow rate, wherein the fourth calculation formula includes:

[0197]

[0198] Among them, K g is the effective permeability of the gas phase; ug is the viscosity of the gas at the formation temperature and pressure, where P1 and P2 are constants.

[0199] In some embodiments, the step of calculating the gas phase relative permeability at each moment based on the gas phase effective permeability at each moment includes:

[0200] The gas phase relative permeability at each moment is calculated using the fifth calculation formula based on the gas phase effective permeability at each moment, wherein the fifth calculation formula includes:

[0201]

[0202] The relative permeability of liquid sulfur at each moment is calculated based on the liquid sulfur permeability under bound water conditions and the flow rate of liquid sulfur, wherein the sixth calculation formula includes:

[0203]

[0204] In some embodiments, the calculating the sulfur saturation in the core sample at each time comprises:

[0205] The seventh calculation formula is used to calculate the sulfur saturation in the core sample at each time, wherein the seventh calculation formula includes:

[0206]

[0207] Among them, Ss is the sulfur saturation, V Si V is the reading of the liquid sulfur pumped in at the constant speed and pressure at time i. S0 is the reading of the constant speed and constant pressure pump pumping liquid sulfur at the initial moment, Vx is the pipeline loss before the constant speed and constant pressure pump pumps into the core holder;

[0208] The calculating the gas saturation of the core sample at each moment based on the sulfur saturation and the irreducible water saturation includes:

[0209] The gas saturation of the core sample at each moment is calculated using an eighth calculation formula based on the sulfur saturation and the irreducible water saturation, wherein the eighth calculation formula includes:

[0210] S g =1-S wi -S S ;

[0211] Among them, S g is the gas saturation.

[0212] It should be noted that in the embodiments of the present application, if the above-mentioned method for determining relative permeability is implemented in the form of a software function module and sold or used as an independent product, it can also be stored in a computer-readable storage medium. Based on this understanding, the technical solution of the embodiment of the present application can be essentially or partly reflected in the form of a software product that contributes to the prior art. The computer software product is stored in a storage medium, including several instructions for a computer device (which can be a personal computer, server, or network device, etc.) to execute all or part of the methods described in each embodiment of the present application. The aforementioned storage medium includes: various media that can store program codes, such as a U disk, a mobile hard disk, a read-only memory (ROM, Read Only Memory), a magnetic disk or an optical disk. In this way, the embodiments of the present application are not limited to any specific combination of hardware and software.

[0213] Accordingly, an embodiment of the present application provides a storage medium having a computer program stored thereon, characterized in that when the computer program is executed by a processor, the steps in the relative permeability determination method provided in the above embodiment are implemented.

[0214] Embodiment 5

[0215] An embodiment of the present application provides an electronic device; Figure 5 A schematic diagram of the structure of an electronic device provided in an embodiment of the present application is shown in FIG. Figure 5 As shown, the electronic device 700 includes: a processor 701, at least one communication bus 702, a user interface 703, at least one external communication interface 704, and a memory 705. The communication bus 702 is configured to realize connection and communication between these components. The user interface 703 may include a display screen, and the external communication interface 704 may include a standard wired interface and a wireless interface. The processor 701 is configured to execute the program of the relative permeability determination method stored in the memory to implement the steps in the relative permeability determination method provided in the above embodiment.

[0216] The description of the above electronic device and storage medium embodiments is similar to the description of the above method embodiments, and has similar beneficial effects as the method embodiments. For technical details not disclosed in the computer device and storage medium embodiments of this application, please refer to the description of the method embodiments of this application for understanding.

[0217] It should be understood that "one embodiment" or "an embodiment" mentioned throughout the specification means that specific features, structures or characteristics related to the embodiment are included in at least one embodiment of the present application. Therefore, "in one embodiment" or "in an embodiment" appearing throughout the specification does not necessarily refer to the same embodiment. In addition, these specific features, structures or characteristics can be combined in one or more embodiments in any suitable manner. It should be understood that in various embodiments of the present application, the size of the sequence number of the above-mentioned processes does not mean the order of execution, and the execution order of each process should be determined by its function and internal logic, and should not constitute any limitation on the implementation process of the embodiments of the present application. The above-mentioned sequence numbers of the embodiments of the present application are only for description and do not represent the advantages and disadvantages of the embodiments.

[0218] It should be noted that, in this article, the terms "include", "comprises" or any other variations thereof are intended to cover non-exclusive inclusion, so that a process, method, article or device including a series of elements includes not only those elements, but also other elements not explicitly listed, or also includes elements inherent to such process, method, article or device. In the absence of further restrictions, an element defined by the sentence "comprises a ..." does not exclude the existence of other identical elements in the process, method, article or device including the element.

[0219] In the several embodiments provided in the present application, it should be understood that the disclosed devices and methods can be implemented in other ways. The device embodiments described above are only schematic. For example, the division of the units is only a logical function division. There may be other division methods in actual implementation, such as: multiple units or components can be combined, or can be integrated into another system, or some features can be ignored or not executed. In addition, the coupling, direct coupling, or communication connection between the components shown or discussed can be through some interfaces, and the indirect coupling or communication connection of the devices or units can be electrical, mechanical or other forms.

[0220] The units described above as separate components may or may not be physically separated, and the components displayed as units may or may not be physical units; they may be located in one place or distributed on multiple network units; some or all of the units may be selected according to actual needs to achieve the purpose of the present embodiment.

[0221] In addition, all functional units in the embodiments of the present application may be integrated into one processing unit, or each unit may be a separate unit, or two or more units may be integrated into one unit; the above-mentioned integrated units may be implemented in the form of hardware or in the form of hardware plus software functional units.

[0222] A person of ordinary skill in the art can understand that: all or part of the steps of implementing the above-mentioned method embodiment can be completed by hardware related to program instructions, and the aforementioned program can be stored in a computer-readable storage medium. When the program is executed, it executes the steps of the above-mentioned method embodiment; and the aforementioned storage medium includes: mobile storage devices, read-only memories (ROM, Read Only Memory), disks or optical disks, etc. Various media that can store program codes.

[0223] Alternatively, if the above-mentioned integrated unit of the present application is implemented in the form of a software function module and sold or used as an independent product, it can also be stored in a computer-readable storage medium. Based on this understanding, the technical solution of the embodiment of the present application can essentially or in other words, the part that contributes to the prior art can be embodied in the form of a software product, which is stored in a storage medium and includes a number of instructions for a controller to execute all or part of the methods described in each embodiment of the present application. The aforementioned storage medium includes: various media that can store program codes, such as mobile storage devices, ROMs, magnetic disks, or optical disks.

[0224] The above is only an implementation method of the present application, but the protection scope of the present application is not limited thereto. Any person skilled in the art who is familiar with the present technical field can easily think of changes or substitutions within the technical scope disclosed in the present application, which should be included in the protection scope of the present application. Therefore, the protection scope of the present application should be based on the protection scope of the claims.

Claims

1. A relative permeability experimental device, characterized in that: include: A gas sample intermediate container, a gas booster pump, a liquid sulfur intermediate container, a constant speed and pressure pump, a core clamp, an oven, a confining pressure pump, a confining pressure valve, a back pressure pump, a waste gas recovery device, a visualization container, a liquid recovery device, and a gas meter. One end of the gas intermediate container is connected to the gas booster pump through a first valve, and the other end of the gas intermediate container is connected to the input end of the core clamp through a second valve and a fourth valve. One end of the liquid sulfur intermediate container is connected to the constant speed and pressure pump through a third valve, and the other end of the liquid sulfur intermediate container is connected to the fifth valve, The fourth valve is connected to the input end of the core clamp, the confining pressure pump is connected to the core clamp through the sixth valve, the output end of the core clamp is connected to the confining pressure valve through the seventh valve, the confining pressure valve is connected to the back pressure pump through the eighth valve, the confining pressure valve is connected to the visualization container, the visualization container is connected to the exhaust gas recovery device through the gas meter, the visualization container is connected to the liquid recovery device through the ninth valve, and the gas sample intermediate container, liquid sulfur intermediate container, core clamp, confining pressure valve and visualization container are arranged in the oven.

2. The relative permeability experimental device according to claim 1, characterized in that: The input end of the core holder is provided with a first pressure gauge, and the output end of the core holder is provided with a second pressure gauge.

3. The relative permeability experimental device according to claim 1, characterized in that: The relative permeability experimental device also includes: a laser liquid level meter, which is used to measure the liquid level in the visualization container.

4. An experimental method, characterized in that The relative permeability experimental device used in any one of claims 1 to 3 comprises: Selecting a core sample, making a target core saturated with formation water based on the core sample, loading the target core saturated with formation water into a core holder, adding a target gas sample into a gas sample intermediate container, and boosting the pressure of the target gas sample to a target fluid pressure by a gas booster pump; Adding a preset amount of sulfur powder into the liquid sulfur intermediate container, pressurizing the core holder through a confining pressure pump, and heating the core through an oven so that the confining pressure of the target core in the core holder reaches the formation pressure and the temperature reaches the formation temperature; When the oven temperature reaches the formation temperature and is maintained for a preset time to melt the sulfur powder, the pressure of the liquid sulfur is pushed to the target fluid pressure by a constant speed and constant pressure pump, the pressure of the back pressure pump is controlled to gradually decrease with the target fluid pressure, and the flow rate of the liquid sulfur at different times is measured; Close all valves and open the ninth valve, control the visualization container to discharge water into the liquid recovery device, and record the quality of the discharged water in the liquid recovery device; Open the first valve and the second valve, boost the pressure of the target gas sample to the target fluid pressure through a gas booster pump, open the seventh valve and the fourth valve, continuously record the flow rate of liquid sulfur in the visualization container at different times, and record the gas flow rate at different times through the gas meter.

5. A method for determining relative permeability, characterized in that: include: Obtaining parameters of core samples, viscosity of liquid sulfur at formation temperature and formation pressure, volume coefficient of liquid sulfur at formation temperature and formation pressure, gas flow rate at different times of the target core obtained based on the experimental method in claim 4, mass of discharged water and flow rate of liquid sulfur at different times; calculating irreducible water saturation of the core sample based on the mass of the discharged water; Calculating the liquid sulfur permeability under irreducible water conditions based on the flow rate of the liquid sulfur, parameters of the core sample, viscosity of the liquid sulfur at the formation temperature and formation pressure, volume coefficient of the liquid sulfur at the formation temperature and formation pressure, and the irreducible water saturation; Correcting the gas flow rate to obtain a target gas flow rate under the formation pressure and temperature conditions; Calculate the effective gas permeability at each moment based on the target gas flow rate; Calculating the gas phase relative permeability at each moment based on the gas phase effective permeability at each moment; The relative permeability of liquid sulfur at each time point is calculated based on the liquid sulfur permeability under bound water conditions and the flow rate of liquid sulfur.

6. The method according to claim 5, characterized in that The method further comprises: Calculate the sulfur saturation in the core samples at each time; The gas saturation of the core sample at each moment is calculated based on the sulfur saturation and the irreducible water saturation.

7. The method according to claim 6, characterized in that The method of calculating the liquid sulfur permeability under irreducible water conditions based on the flow rate of the liquid sulfur, the parameters of the core sample, the viscosity of the liquid sulfur at the formation temperature and the formation pressure, the volume coefficient of the liquid sulfur at the formation temperature and the formation pressure, and the irreducible water saturation comprises: The liquid sulfur permeability under irreducible water conditions is calculated using a first calculation formula based on the flow rate of the liquid sulfur, the parameters of the core sample, the viscosity of the liquid sulfur at the formation temperature and the formation pressure, the volume coefficient of the liquid sulfur at the formation temperature and the formation pressure, and the irreducible water saturation, wherein the first calculation formula includes: Among them, K S is the liquid sulfur permeability under bound water conditions, B S is the liquid sulfur volume coefficient under formation temperature and pressure conditions, q S is the flow rate of liquid sulfur, μ S is the viscosity of liquid sulfur under formation temperature and pressure conditions, L is the length of the core sample, A is the cross-sectional area of ​​the core sample, P1 is the pressure at the inlet end of the core sample, and P2 is the pressure at the outlet end of the core sample.

8. The method according to claim 7, characterized in that The step of calculating irreducible water saturation of the core sample based on the mass of the discharged water comprises: Based on the mass of the discharged water, the irreducible water saturation of the core sample is calculated using a second calculation formula, wherein the second calculation formula includes: Among them, Swi is the irreducible water saturation, m1 is the dry core mass, m2 is the core mass after saturation with formation water, and m3 is the discharged water mass.

9. The method according to claim 8, characterized in that The correcting the gas flow to obtain the target gas flow under the formation pressure and temperature conditions includes: The gas flow rate is corrected based on a third calculation formula to obtain a target gas flow rate under the formation pressure and temperature conditions, wherein the third calculation formula includes: Where q1 is the target gas flow rate under formation temperature and pressure conditions, Z1 is the gas deviation coefficient under formation temperature and pressure conditions, P3 is the fluid pressure, P atm is the atmospheric pressure, and Z2 is the deviation coefficient of gas under the conditions of atmospheric pressure and formation temperature.

10. The method according to claim 9, characterized in that The method of calculating the gas phase effective permeability at each moment based on the target gas flow rate includes: The gas phase relative permeability at each moment is calculated using a fourth calculation formula based on the target gas flow rate, wherein the fourth calculation formula includes: Among them, K g is the effective permeability of the gas phase; ug is the viscosity of the gas at the formation temperature and pressure, where P1 and P2 are constants.

11. The method according to claim 10, characterized in that The step of calculating the gas phase relative permeability at each moment based on the gas phase effective permeability at each moment comprises: The gas phase relative permeability at each moment is calculated using the fifth calculation formula based on the gas phase effective permeability at each moment, wherein the fifth calculation formula includes: The relative permeability of liquid sulfur at each moment is calculated based on the liquid sulfur permeability under bound water conditions and the flow rate of liquid sulfur, wherein the sixth calculation formula includes:

12. The method according to claim 11, characterized in that The calculation of sulfur saturation in the core sample at each time comprises: The seventh calculation formula is used to calculate the sulfur saturation in the core sample at each time, wherein the seventh calculation formula includes: Among them, Ss is the sulfur saturation, V Si V is the reading of the liquid sulfur pumped in at the constant speed and pressure at time i. S0 is the reading of the constant speed and constant pressure pump pumping liquid sulfur at the initial moment, Vx is the pipeline loss before the constant speed and constant pressure pump pumps into the core holder; The calculating the gas saturation of the core sample at each moment based on the sulfur saturation and the irreducible water saturation includes: The gas saturation of the core sample at each moment is calculated using an eighth calculation formula based on the sulfur saturation and the irreducible water saturation, wherein the eighth calculation formula includes: S g =1-S wi -S S ; Among them, S g is the gas saturation.

13. A relative permeability determination device, characterized in that: include: An acquisition module, used to obtain parameters of a core sample, viscosity of liquid sulfur at formation temperature and formation pressure, volume coefficient of liquid sulfur at formation temperature and formation pressure, gas flow rate at different times of the target core obtained based on the experimental method in claim 4, mass of discharged water and flow rate of liquid sulfur at different times; A first calculation module, configured to calculate irreducible water saturation of the core sample based on the mass of the discharged water; A second calculation module is used to calculate the liquid sulfur permeability under irreducible water conditions based on the flow rate of the liquid sulfur, the parameters of the core sample, the viscosity of the liquid sulfur at the formation temperature and formation pressure, the volume coefficient of the liquid sulfur at the formation temperature and formation pressure, and the irreducible water saturation; A correction module, used for correcting the gas flow rate to obtain a target gas flow rate under the formation pressure and temperature conditions; A third calculation module is used to calculate the gas phase effective permeability at each moment based on the target gas flow rate; A fourth calculation module, used for calculating the gas phase relative permeability at each moment based on the gas phase effective permeability at each moment; The fifth calculation module is used to calculate the relative permeability of liquid sulfur at each moment based on the liquid sulfur permeability under the irreducible water condition and the flow rate of liquid sulfur.

14. An electronic device, characterized in that: The invention comprises a memory and a processor, wherein a computer program is stored in the memory, and when the computer program is executed by the processor, the method for determining relative permeability as claimed in any one of claims 5 to 12 is executed.

15. A storage medium, characterized in that: The computer program stored in the storage medium can be executed by one or more processors and can be used to implement the relative permeability determination method as claimed in any one of claims 5 to 12.

Images