Gas well scaling probability evaluation method, device, medium and electronic equipment

Abstract

The present application provides a method, device, medium, and electronic device for evaluating the scaling probability of a gas well. The method provided in the embodiments of the present application combines relative permeability curves to obtain the retained water saturation corresponding to the ratio of gas phase relative permeability to water relative permeability, and measures irreducible water saturation. By subtracting the quantified retained water saturation from the irreducible water saturation, data for quantitatively evaluating the scaling probability of the gas well is obtained. This enables relatively accurate quantitative data evaluation of the scaling probability of the gas well, enabling more precise assistance in natural gas production.

Description

Technical Field

[0001] The present application relates to the field of oil and gas production technology, and in particular to a method, device, medium and electronic equipment for evaluating the scaling probability of a gas well. Background Art

[0002] Currently, scale blockage is a major problem for stable production of high-pressure gas wells. How to evaluate the scaling probability of gas wells is a research topic for many technicians.

[0003] In existing technologies, technicians understand that there is a clear correlation between the saturation of "retained water" in actual production and the degree of scaling. They also know that the higher the saturation of "retained water," the greater the probability of scaling, and vice versa. However, determining the saturation of "retained water" in a reservoir and quantifying the scaling probability of a gas well based on this saturation remain challenges.

[0004] Therefore, a method for evaluating the scaling probability of gas wells is urgently needed to quantitatively evaluate the scaling probability of gas wells by measuring the saturation of “retained water” in the reservoir. Summary of the Invention

[0005] The embodiments of the present application provide a method, device, medium and electronic equipment for evaluating the scaling probability of a gas well, so as to solve the current technical problem of being unable to quantitatively evaluate the scaling probability of a gas well based on the retained water saturation of the reservoir.

[0006] In a first aspect, an embodiment of the present application provides a method for evaluating the scaling probability of a gas well, comprising:

[0007] Obtaining a relative permeability curve of the area to be evaluated, as well as fluid parameters of natural gas and formation water produced in the area to be evaluated;

[0008] Obtain daily gas and water production levels for individual wells;

[0009] Determination of bound water saturation;

[0010] Obtaining a ratio of the relative permeability of the gas phase to the relative permeability of the water phase according to the fluid parameters, the daily gas production level of the single well, the daily water production level, and a preset formula;

[0011] Obtaining the water saturation of the reservoir retained water corresponding to the ratio according to the relative permeability curve;

[0012] The difference between the water saturation of the reservoir retained water and the irreducible water saturation is calculated to evaluate the scaling probability of the gas well based on the difference.

[0013] In a possible design, gas wells without formation water production in the area to be evaluated are determined as evaluation objects.

[0014] In one possible design, whether formation water is produced in each gas well in the area to be evaluated is determined based on the chloride ion content index of the output.

[0015] In one possible design, the fluid parameters of the natural gas and formation water include:

[0016] Natural gas volume coefficient B g , natural gas viscosity μ g , formation water volume coefficient B w and the viscosity of formation water μ w .

[0017] In a possible design, the preset formula is:

[0018]

[0019] Among them, K rg is the relative permeability of the gas phase, K rw is the relative permeability of water, Q g is the daily gas production level of a single well, Q w is the daily water production level of a single well, B g is the volume coefficient of natural gas, B w is the formation water volume coefficient, μ g is the viscosity of natural gas, μ w is the viscosity of formation water.

[0020] In one possible design, determining irreducible water saturation includes:

[0021] The irreducible water saturation is determined by using any one of the indoor experimental methods including centrifugal capillary pressure method, air-displacement water dynamic method and nuclear magnetic resonance method.

[0022] In a possible design, obtaining the water saturation of the reservoir retained water corresponding to the ratio according to the relative permeability curve includes:

[0023] The water saturation of the retained water corresponding to the ratio and the irreducible water saturation are marked on the relative permeability curve to determine the difference between the water saturation and the irreducible water saturation on the relative permeability curve.

[0024] In a second aspect, this embodiment further provides a method for evaluating the scaling probability of a gas well, comprising:

[0025] An acquisition module, configured to acquire a relative permeability curve of the area to be evaluated, and fluid parameters of the natural gas and formation water produced in the area to be evaluated;

[0026] The acquisition module is also used to obtain the daily gas production level and daily water production level of a single well;

[0027] A measurement module for measuring bound water saturation;

[0028] a calculation module for obtaining a ratio of the relative permeability of the gas phase to the relative permeability of the water phase based on the fluid parameters, the daily gas production level and the daily water production level of the single well and a preset formula;

[0029] The acquisition module is further configured to obtain the water saturation of the reservoir retained water corresponding to the ratio according to the relative permeability curve;

[0030] The calculation module is further configured to calculate a difference between the water saturation of the reservoir retained water and the irreducible water saturation, so as to evaluate the scaling probability of the gas well based on the difference.

[0031] In one possible design, whether formation water is produced in each gas well in the area to be evaluated is determined based on the chloride ion content index of the output.

[0032] In one possible design, the fluid parameters of the natural gas and formation water include:

[0033] Natural gas volume coefficient B g , natural gas viscosity μ g , formation water volume coefficient B w and the viscosity of formation water μ w .

[0034] In a possible design, the preset formula is:

[0035]

[0036] Among them, K rg is the relative permeability of the gas phase, K rw is the relative permeability of water, Q g is the daily gas production level of a single well, Q w is the daily water production level of a single well, B g is the volume coefficient of natural gas, B w is the formation water volume coefficient, μ g is the viscosity of natural gas, μ w is the viscosity of formation water.

[0037] In one possible design, the determination module is specifically used to:

[0038] The irreducible water saturation S is determined by any indoor experimental method including centrifugal capillary pressure method, gas-driven water dynamic method, and nuclear magnetic resonance method. wi .

[0039] In one possible design, the computing module is specifically configured to:

[0040] The ratio K is marked on the relative permeability curve. rg / K rw The corresponding water saturation S of the reservoir retained water wz And mark the irreducible water saturation S wi , to determine the water saturation S on the relative permeability curve wz and the irreducible water saturation S wi The difference.

[0041] In a third aspect, an embodiment of the present application further provides an electronic device, including:

[0042] processor; and

[0043] a memory for storing a computer program for the processor;

[0044] The processor is configured to implement any one of the gas well scaling probability evaluation methods in the first aspect by executing the computer program.

[0045] In a fourth aspect, an embodiment of the present application further provides a storage medium having a computer program stored thereon, which, when executed by a processor, implements any one of the gas well scaling probability evaluation methods of the first aspect.

[0046] In a fifth aspect, an embodiment of the present application further provides a computer program product, comprising a computer program, which, when executed by a processor, implements any one of the gas well scaling probability evaluation methods in the first aspect.

[0047] Embodiments of the present application provide a method, apparatus, medium, and electronic device for evaluating the scaling probability of a gas well. These methods combine relative permeability curves to obtain the retained water saturation corresponding to the ratio of gas phase relative permeability to water relative permeability, and determine the irreducible water saturation. The method then subtracts the quantified retained water saturation from the irreducible water saturation to obtain data for quantitatively evaluating the scaling probability of the gas well. This method enables relatively accurate quantitative data evaluation of the scaling probability of the gas well, and can more accurately assist in natural gas production. BRIEF DESCRIPTION OF THE DRAWINGS

[0048] In order to more clearly illustrate the embodiments of the present application or the technical solutions in the prior art, a brief introduction will be given below to the drawings required for use in the embodiments or the description of the prior art. Obviously, the drawings described below are some embodiments of the present application. For ordinary technicians in this field, other drawings can be obtained based on these drawings without paying any creative labor.

[0049] Figure 1 A flow chart of a method for evaluating the scaling probability of a gas well is schematically shown;

[0050] Figure 2 is the relative permeability curve of Well H001 in H gas reservoir in a specific example;

[0051] Figure 3 K in the specific example rg / K rw The water saturation S of the reservoir "retained water" corresponding to the value of wz exist Figure 2 The position of

[0052] Figure 4 is the water saturation of the reservoir retained water S wz and bound water saturation S wi The difference corresponds to Figure 2 Instructions in

[0053] Figure 5 The structure diagram of a gas well scaling probability evaluation device is schematically shown;

[0054] Figure 6 The figure schematically shows a structural diagram of an electronic device. DETAILED DESCRIPTION

[0055] To make the purpose, technical solutions, and advantages of the embodiments of this application more clear, the technical solutions in the embodiments of this application will be clearly and completely described below in conjunction with the drawings in the embodiments of this application. Obviously, the described embodiments are part of the embodiments of this application, not all of the embodiments. Based on the embodiments in this application, all other embodiments obtained by ordinary technicians in this field without making creative efforts are within the scope of protection of this application.

[0056] The terms "first", "second", "third", "fourth", etc. (if any) in the specification and claims of the present application and the above-mentioned drawings are used to distinguish similar objects and are not necessarily used to describe a specific order or sequential order. It should be understood that the numbers used in this way are interchangeable where appropriate, so that the embodiments of the present application described herein can be implemented in an order other than those illustrated or described herein. In addition, the terms "including" and "having" and any variations thereof are intended to cover non-exclusive inclusions, for example, a process, method, system, product or device that includes a series of steps or units is not necessarily limited to those steps or units clearly listed, but may include other steps or units that are not clearly listed or inherent to these processes, methods, products or devices.

[0057] Figure 1 The following schematically shows a flow chart of a method for evaluating the scaling probability of a gas well. Figure 1 As shown, this embodiment provides a method for evaluating the scaling probability of a gas well, including:

[0058] Step 101: Obtain a relative permeability curve of the area to be evaluated, and fluid parameters of the natural gas and formation water produced in the area to be evaluated.

[0059] Specifically, the area to be evaluated is the production area where the probability of gas well scaling is to be evaluated. The method provided in the embodiment of the present invention is not limited to a specific area and can be widely applied to various areas to be evaluated. The relative permeability curve of the area to be evaluated can be obtained using existing laboratory techniques. The specific laboratory techniques are mastered by technicians and are not described in detail in the embodiment of the present invention. Similarly, relevant fluid parameters of natural gas and formation water can be obtained through laboratory testing, such as the viscosity and volume coefficient of natural gas, and the viscosity and volume coefficient of formation water.

[0060] Step 102: Obtain the daily gas production Qg level and the daily water production Qw level of a single well.

[0061] Specifically, the daily gas production of a single well is Q g 、Nissan Water Q w The level can be obtained by measuring the gas wells in the area to be evaluated using existing single-well metering equipment.

[0062] Step 103: Determine the bound water saturation Swi.

[0063] Specifically, the irreducible water saturation S can be determined by any one of the centrifugal capillary pressure method, the air-displacement water dynamic method, and the nuclear magnetic resonance method in an indoor experiment. wi The above-mentioned centrifugal capillary pressure method, air-displacement water dynamic method, and nuclear magnetic resonance method are technologies referred to by technicians and are not described in detail in the embodiments of the present invention.

[0064] Step 104 : Obtain the ratio Krg / Krw of the relative permeability Krg of the gas phase to the relative permeability Krw of the water phase according to the fluid parameters, the daily gas production Qg level of the single well, the daily water production Qw level, and a preset formula.

[0065] Specifically, the preset formula can be selected as a suitable formula based on the calculation experience or habits of the technician, and the parameters in the above steps 101-103 need to be used.

[0066] Step 105: Obtain the water saturation Swz of the reservoir retained water corresponding to the ratio Krg / Krw according to the relative permeability curve.

[0067] Specifically, the ratio K is calculated rg / K rw The corresponding reservoir "retained water" water saturation S wz Afterwards, the water saturation S of the reservoir "retained water" can be obtained by fitting with the relative permeability curve. wzThe corresponding numerical values ​​and specific fitting methods are also known to technicians.

[0068] Step 106: Calculate the difference ΔSw between the retained water saturation Swz and the irreducible water saturation Swi, and evaluate the scaling probability of the gas well based on the difference ΔSw.

[0069] Specifically, the water saturation S of the reservoir “retained water” is wz and the irreducible water saturation S wi Do the difference and get the difference ΔS w It can represent the amount of water that may be produced during the production process of a gas well. As the water production increases, the scaling probability of the gas well will increase. Therefore, the water saturation S of the “retained water” in the reservoir is wz and bound water saturation S wi The difference ΔS w It is directly proportional to the scaling probability of the gas well.

[0070] The method for evaluating the scaling probability of a gas well provided by the embodiment of the present invention obtains the gas phase relative permeability K by combining the relative permeability curve. rg and the relative permeability of water K rw The ratio K rg / K rw The corresponding water saturation S of the “retained water” in the reservoir wz , and determination of bound water saturation S wi and by quantifying the water saturation S of the reservoir "retained water" wz and the irreducible water saturation S wi By making a difference, we can obtain data for quantitative evaluation of the scaling probability of gas wells, so that the evaluation of the scaling probability of gas wells can reach a relatively accurate quantitative data level, which can more accurately assist the production of natural gas.

[0071] In a specific implementation, a gas well without formation water production in the area to be evaluated is selected as an evaluation object.

[0072] Specifically, in order to make the water saturation S of the reservoir "retained water" obtained by the method provided in the embodiment of the present invention wz and bound water saturation S wi The difference ΔS w More representatively, in the data acquisition stage before the above calculations, it is necessary to ensure that the data are obtained from gas wells without formation water production in the area to be evaluated.

[0073] In a specific implementation, whether the gas well produces formation water can be determined based on the chloride ion content of the output. That is, by analyzing parameters such as chloride ion content, it can be determined that the produced water is not formation water at the structural edge.

[0074] In a specific implementation, the relevant fluid parameters of natural gas and formation water include:

[0075] Natural gas volume coefficient B g , natural gas viscosity μ g , formation water volume coefficient B w , the viscosity of formation water μ w .

[0076] The preset formula in the above embodiment is:

[0077]

[0078] K rg is the relative permeability of the gas phase, K rw is the relative permeability of water, Q g is the daily gas production level of a single well, Q w is the daily water production level of a single well, B g is the volume coefficient of natural gas, B w is the formation water volume coefficient, μ g is the viscosity of natural gas, μ w is the viscosity of formation water

[0079] Among them, Q in the formula g is the daily gas production of a single well obtained in step 102, Q w is the daily water production of a single well obtained in step 102 above.

[0080] In the specific implementation, the above method is used to obtain the ratio K according to the obtained data using the above formula. rg / K rw Then, the ratio K can be obtained by fitting with the relative permeability curve rg / K rw The corresponding reservoir "retained water" water saturation S wz At this time, we can mark the relative permeability curve by marking the ratio K rg / K rw The corresponding reservoir "retained water" water saturation S wz And mark the irreducible water saturation S wi , to show the water saturation S on the graph of the relative permeability curve wz and the irreducible water saturation S wi The difference ΔS w The difference ΔS can be obtained more intuitively. w The size of the difference ΔS is known by the above method. w It is directly proportional to the scaling probability of the gas well and can quickly determine the scaling probability of the gas well in the area to be evaluated.

[0081] In addition, the present invention also provides an example of using the above method to evaluate the scaling probability of a gas well:

[0082] The H gas reservoir in the evaluated area is a high-pressure dry gas reservoir with edge water. The natural gas volume coefficient B g 0.002537, natural gas viscosity μ g 0.0178mPa.s, formation water volume coefficient B w The viscosity of formation water is 0.10265 μ w H001 is a production well located in the high part of the gas reservoir structure. The measured relative permeability curve of the target layer core is shown in Figure 1 .

[0083] (1) Using single well metering equipment, the daily gas production Q of well H001 was approved. g =30.0×10 4 m 3 / d, daily water Q w =5.0m 3 / d, and with the help of parameters such as chloride ion content, it is determined that the produced water is not formation water at the structural edge.

[0084] (2) Centrifugal capillary pressure experiments were conducted using cores from the target layer of Well H001 to determine the irreducible water saturation S wi is 35%.

[0085] (3) Calculate K using known parameters rg / K rw value.

[0086]

[0087] (4) Figure 2 is the relative permeability curve of H001 well in H gas reservoir in a specific example, Figure 3 K in the specific example rg / K rw The water saturation S of the reservoir "retained water" corresponding to the value of wz exist Figure 2 The position of Figure 3 As shown, combined with the relative permeability curve of this gas well, K is determined rg / K rw The water saturation S of the reservoir "retained water" corresponding to the value of wz is 45%.

[0088] (5) Figure 4 is the water saturation of the reservoir retained water S wz and bound water saturation S wi The difference corresponds to Figure 2 In the instructions, such as Figure 4 As shown, Krg / K rw =22 corresponding to the water saturation of the reservoir "retained water" S wz and bound water saturation S wi The difference ΔS w =10%, which is the amount of water that may be produced during the gas well production process.

[0089] (6) According to ΔS w The value of , indicates that there is a risk of scale plugging in the later production of Well H001.

[0090] Figure 5 The following schematically shows the structure of a gas well scaling probability evaluation device. Figure 5 As shown, the gas well scaling probability evaluation device 200 provided in this embodiment includes:

[0091] An acquisition module 201 is used to acquire a relative permeability curve of a region to be evaluated, and fluid parameters of natural gas and formation water produced in the region to be evaluated;

[0092] The acquisition module 201 is also used to obtain the daily gas production Q of a single well. g Level and daily water Q w level;

[0093] Determination module 202, for determining irreducible water saturation S wi ;

[0094] The calculation module 203 is used to obtain the relative permeability K of the gas phase according to the fluid parameters, the daily gas production Qg level of the single well, the daily water production Qw level and the preset formula. rg and the relative permeability of water K rw The ratio K rg / K rw ;

[0095] The acquisition module 201 is further used to obtain the ratio K according to the relative permeability curve. rg / K rw The corresponding reservoir retention water saturation S wz ;

[0096] The calculation module 203 is also used to calculate the water saturation S of the reservoir retained water. wz and the irreducible water saturation S wi The difference ΔS w , by the difference ΔS w Evaluate the scaling probability of gas wells.

[0097] In one possible design, whether formation water is produced in each gas well in the area to be evaluated is determined based on the chloride ion content index of the output.

[0098] In one possible design, the fluid parameters of the natural gas and formation water include:

[0099] Natural gas volume coefficient B g , natural gas viscosity μ g , formation water volume coefficient B w and the viscosity of formation water μ w .

[0100] In a possible design, the preset formula is:

[0101]

[0102] Among them, K rg is the relative permeability of the gas phase, K rw is the relative permeability of water, Q g is the daily gas production level of a single well, Q w is the daily water production level of a single well, B g is the volume coefficient of natural gas, B w is the formation water volume coefficient, μ g is the viscosity of natural gas, μ w is the viscosity of formation water.

[0103] In one possible design, the determination module 202 is specifically configured to:

[0104] The irreducible water saturation S is determined by any indoor experimental method including centrifugal capillary pressure method, gas-driven water dynamic method, and nuclear magnetic resonance method. wi .

[0105] In one possible design, the calculation module 203 is specifically configured to:

[0106] The ratio K is marked on the relative permeability curve. rg / K rw The corresponding water saturation S of the reservoir retained water wz And mark the irreducible water saturation S wi , to determine the water saturation S on the relative permeability curve wz and the irreducible water saturation S wi The difference.

[0107] The device provided in this embodiment can be used to perform the steps in the above method embodiment. For details not disclosed in the device embodiment of this application, please refer to the method embodiment of this application.

[0108] Figure 6 The following schematically shows a structural diagram of an electronic device. Figure 6As shown, this embodiment provides an electronic device 300, including:

[0109] processor 301; and,

[0110] Memory 302, for storing executable instructions of the processor, which may also be flash memory;

[0111] The processor 301 is configured to execute each step of the above method by executing the executable instructions.

[0112] Optionally, the memory 302 may be independent or integrated with the processor 301 .

[0113] When the memory 302 is a device independent of the processor 301, the electronic device 300 may further include:

[0114] The bus 303 is used to connect the processor 301 and the memory 302 .

[0115] This embodiment further provides a readable storage medium, in which a computer program is stored. When at least one processor of an electronic device executes the computer program, the electronic device executes each step in the above method.

[0116] This embodiment further provides a program product, which includes a computer program stored in a readable storage medium. At least one processor of an electronic device can read the computer program from the readable storage medium, and at least one processor executes the computer program to cause the electronic device to implement each step of the above method.

[0117] Those skilled in the art will appreciate that all or part of the steps in the above-described method embodiments can be implemented using hardware associated with program instructions. The aforementioned program can be stored in a computer-readable storage medium. When executed, the program performs the steps of the above-described method embodiments. The aforementioned storage medium includes various media capable of storing program code, such as ROM, RAM, magnetic disks, or optical disks.

[0118] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present application, rather than to limit them. Although the present application has been described in detail with reference to the aforementioned embodiments, those skilled in the art should understand that they can still modify the technical solutions described in the aforementioned embodiments, or replace some or all of the technical features therein with equivalents. However, these modifications or replacements do not cause the essence of the corresponding technical solutions to deviate from the scope of the technical solutions of the embodiments of the present application.

Claims

1. A method for evaluating the scaling probability of a gas well, characterized in that: include: Obtain the relative permeability curve of the area to be evaluated, as well as the fluid parameters of the natural gas and formation water produced in the area to be evaluated, the fluid parameters of the natural gas and formation water include: natural gas volume coefficient B g , natural gas viscosity μ g , formation water volume coefficient B w and the viscosity of formation water μ w ; Obtain daily gas and water production levels for individual wells; Determination of bound water saturation; Obtaining a ratio of the relative permeability of the gas phase to the relative permeability of the water phase according to the fluid parameters, the daily gas production level of the single well, the daily water production level, and a preset formula; The preset formula is: in, is the relative permeability of the gas phase, is the relative permeability of water, is the daily gas production level of a single well, is the daily water production level of a single well, is the natural gas volume coefficient, is the formation water volume coefficient, is the viscosity of natural gas, μ w is the viscosity of formation water; Obtaining the water saturation of the reservoir retained water corresponding to the ratio by fitting the relative permeability curve; calculating a difference between the water saturation of the reservoir retained water and the irreducible water saturation, so as to evaluate the scaling probability of the gas well based on the difference; The step of obtaining the water saturation of the reservoir retained water corresponding to the ratio by fitting the relative permeability curve includes: The water saturation of the retained water corresponding to the ratio and the irreducible water saturation are marked on the relative permeability curve to determine the difference between the water saturation and the irreducible water saturation on the relative permeability curve.

2. The method for evaluating the scaling probability of a gas well according to claim 1, wherein: The gas wells without formation water production in the area to be evaluated are determined as evaluation objects.

3. The method for evaluating the scaling probability of a gas well according to claim 2, wherein: The chloride ion content index of the output is used to determine whether each gas well in the evaluated area has formation water output.

4. The method for evaluating the scaling probability of a gas well according to any one of claims 1 to 3, wherein: The method of determining irreducible water saturation comprises: The irreducible water saturation is determined by using any one of the indoor experimental methods including centrifugal capillary pressure method, air-displacement water dynamic method and nuclear magnetic resonance method.

5. A gas well scaling probability evaluation device, characterized in that: include: The acquisition module is used to obtain the relative permeability curve of the area to be evaluated, as well as the fluid parameters of the natural gas and formation water produced in the area to be evaluated. The fluid parameters of the natural gas and formation water include: the natural gas volume coefficient B g , natural gas viscosity μ g , formation water volume coefficient B w and the viscosity of formation water μ w ; The acquisition module is also used to obtain the daily gas production level and daily water production level of a single well; A measurement module for measuring bound water saturation; a calculation module for obtaining a ratio of the relative permeability of the gas phase to the relative permeability of the water phase based on the fluid parameters, the daily gas production level and the daily water production level of the single well and a preset formula; The preset formula is: in, is the relative permeability of the gas phase, is the relative permeability of water, is the daily gas production level of a single well, is the daily water production level of a single well, is the natural gas volume coefficient, is the formation water volume coefficient, is the viscosity of natural gas, μ w is the viscosity of formation water; The acquisition module is further configured to obtain the water saturation of the reservoir retained water corresponding to the ratio by fitting the relative permeability curve; The calculation module is further configured to calculate a difference between the water saturation of the reservoir retained water and the irreducible water saturation, so as to evaluate the scaling probability of the gas well based on the difference; The acquisition module is specifically configured to mark the water saturation of the retained water in the reservoir corresponding to the ratio and the irreducible water saturation on the relative permeability curve, so as to determine the difference between the water saturation and the irreducible water saturation on the relative permeability curve.

6. An electronic device, characterized in that: include: processor; as well as a memory for storing a computer program for the processor; The processor is configured to implement the gas well scaling probability evaluation method according to any one of claims 1 to 4 by executing the computer program.

7. A computer-readable storage medium having a computer program stored thereon, characterized in that: When the computer program is executed by a processor, the gas well scaling probability evaluation method according to any one of claims 1 to 4 is implemented.

8. A computer program product having a computer program stored thereon, characterized in that: When the computer program is executed by a processor, the gas well scaling probability evaluation method according to any one of claims 1 to 4 is implemented.

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