A system and method for evaluating dynamic scaling performance of formation near wellbore area

Abstract

The invention provides an evaluation system and method for dynamic scaling performance of a formation near a wellbore, and relates to the technical field of oilfield water injection development. The invention collects formation parameters and formation water samples and performs component analysis on the formation water samples, prepares simulated formation water and representative scaling samples according to the analysis results, prepares scaling agent solution with the simulated formation water, performs compatibility test on the scaling agent solution prepared with the simulated formation water to obtain the compatibility time and the optimal concentration; analyzes the scaling agent solution prepared with the simulated formation water with the optimal concentration under static conditions and generates a static scaling coefficient in combination with the compatibility time; studies the relationship between the volume and permeability of the scaling agent solution during solution injection to generate a variable scaling coefficient, generates a dynamic scaling index through the static scaling coefficient and the variable scaling coefficient, and thereby evaluates the dynamic scaling performance of the formation near a wellbore.

Description

Technical Field

[0001] The invention relates to the technical field of oilfield water injection development, and in particular to an evaluation system and method for dynamic scaling performance of a formation near a wellbore. Background Art

[0002] During the development of oil and gas fields, various mineral scale deposits are often formed in the near-wellbore area of ​​the formation due to the difference in chemical composition between the injected water and the formation water, as well as changes in formation temperature, pressure and other conditions. These scale deposits will reduce the permeability of the formation, affect the flow of oil and gas, thereby reducing the oil and gas recovery rate and increasing production costs. Traditional scale dissolving agent evaluation methods mostly use static testing methods, ignoring the complexity of the dynamic scale dissolving process under actual formation conditions. Although these static testing methods can provide certain scale dissolving agent performance data, the accuracy and reliability of their evaluation results are limited because they cannot simulate the dynamic environment of the near-wellbore area of ​​the actual formation. Therefore, it is urgent to develop a system that can evaluate the dynamic scale dissolving performance of scale dissolving agents under simulated formation conditions, so as to more accurately guide the use of scale dissolving agents in the process of oil and gas field development.

[0003] In the prior art, the publication number CN115950789A discloses a method and device for evaluating the performance of scale inhibitors based on crystallization kinetics, which gradually adds the scale inhibitor to be evaluated to a certain amount of flowing liquid, and obtains the crystallization kinetic coefficient and fluid dynamic coefficient of the flowing liquid at different addition amounts of the scale inhibitor to be evaluated in real time. Based on the obtained crystallization kinetic coefficient and fluid dynamic coefficient, the concentration of the scale inhibitor to be evaluated in the flowing liquid is determined as its critical concentration when the scaling process of the flowing liquid is converted from mass transfer control to surface reaction control; for the flowing liquid, the smaller the critical concentration of the scale inhibitor, the better its scale inhibition performance. This prior art realizes a scientific and accurate quantitative evaluation of the performance of scale inhibitors by comparing the critical concentrations of different scale inhibitors, and provides effective guidance for users in screening scale inhibitors and corresponding dosages for specific liquids. However, this prior art still has shortcomings. First, the variability of the real environment means that the conditions in actual applications are constantly changing. The prior art only considers a specific situation, which leads to its conclusion being too one-sided and lacking the necessary comprehensiveness and universal adaptability. Secondly, in terms of performance evaluation, the existing technical methods only evaluate the effect of scale inhibitors by comparing critical concentrations. This evaluation method is too simplistic and the conclusions drawn are not convincing enough.

[0004] The above information disclosed in the Background section is only for enhancement of understanding of the background of the present disclosure and therefore it may include information that does not constitute the prior art that is already known to one of ordinary skill in the art. Summary of the invention

[0005] The purpose of the present invention is to provide a system and method for evaluating the dynamic scaling performance of a formation near a wellbore, so as to solve the problems raised in the above-mentioned background technology.

[0006] To achieve the above object, the present invention provides the following technical solutions:

[0007] An evaluation system for dynamic scaling performance of formation near-wellbore zone, specifically comprising:

[0008] The sample preparation module is used to collect formation parameters and formation water samples from the water injection station, perform component analysis on the formation water samples, and prepare simulated formation water and representative scale samples according to the analysis results; the formation parameters include formation temperature and formation water sample pH;

[0009] A compatibility module is used to prepare a scale dissolving agent solution with simulated formation water, and to perform compatibility test on the scale dissolving agent solution prepared with simulated formation water to obtain the compatibility time and optimal concentration;

[0010] The static test module is used to conduct static scaling experiments on representative scale samples using the optimal concentration of scaling agent solution under the same formation pH conditions to obtain the static scaling rate; the static scaling coefficient is generated through the compatibility time and the static scaling rate;

[0011] The dynamic test module is used to select an artificial core whose core porosity differs from the actual reservoir core porosity by less than 0.01, slowly inject an optimal concentration of scale dissolving agent solution into the artificial core, record the volume of the optimal concentration of scale dissolving agent solution injected and the corresponding permeability, and draw a volume-permeability relationship diagram of the optimal concentration of scale dissolving agent solution injected, obtain the maximum damage injection volume and the optimal recovery permeability according to the volume-permeability relationship diagram of the optimal concentration of scale dissolving agent solution injected, and generate a variable scale dissolving coefficient according to the optimal concentration, the maximum damage injection volume and the optimal recovery permeability;

[0012] The performance evaluation module is used to de-dimensionalize the static scaling coefficient and the variable scaling coefficient, generate a dynamic scaling index, and evaluate the dynamic scaling performance of the formation near the wellbore according to the dynamic scaling index. The larger the dynamic scaling index, the better the dynamic scaling performance of the formation near the wellbore. Furthermore, the specific operation of the compatibility test is: using simulated formation water to prepare scaling agent solutions with concentrations of 15%, 20%, 25%, 30%, 35%, 40%, and 45%, respectively, the solutions are allowed to stand at formation temperature conditions, and the latest time for the first precipitation of each solution is observed. The concentration of the solution with the latest first precipitation is defined as the optimal concentration, and the time for the solution with the latest precipitation is defined as the compatibility time.

[0013] Furthermore, the specific operation of the static scale dissolution experiment is as follows: at the formation temperature, the pH of the optimal concentration of the scale dissolving agent solution is adjusted to the pH of the formation water sample, the filter paper weight M1 is weighed, the representative scale and the filter paper with a mass of M2 are placed in an oven at the formation temperature for drying, and the representative scale sample is placed in the solution at the formation temperature and allowed to react for 72 hours; after the reaction is completed, the solution in the ground-mouth triangular flask is filtered with filter paper, the filtered filter paper is placed in an oven for drying to constant weight, the total mass of the dried filter paper and the representative scale sample M3 is weighed, and the static scale dissolution rate is calculated, and the specific formula based on it is:

[0014]

[0015] Where E is the static scaling rate.

[0016] Furthermore, the specific logic for generating the static scaling coefficient is: the static scaling coefficient is generated by the compatibility time and the static scaling rate, and the specific formula is:

[0017]

[0018] Among them, ET is the static scaling coefficient, T is the compatibility time, and E is the static scaling rate.

[0019] Furthermore, the specific logic for obtaining the maximum harmful injection volume and the optimal recovery permeability is as follows: in the volume-permeability relationship diagram of the scale-dissolving agent solution with the optimal concentration injected, the volume of the scale-dissolving agent solution with the optimal concentration injected when the permeability is the minimum is the maximum harmful injection volume, and among the points where the derivative of the permeability with respect to the volume is greater than or equal to 0, the maximum permeability is the optimal recovery permeability.

[0020] Furthermore, the specific logic for generating the variable scaling coefficient is: generating the variable scaling coefficient according to the optimal concentration, the maximum damage injection volume and the optimal recovery permeability; the specific formula is:

[0021]

[0022] Among them, DE is the variable scaling coefficient, S is the optimal recovery permeability, C is the optimal concentration, and V is the maximum damage injection volume.

[0023] Furthermore, the specific logic for generating the dynamic scaling index is as follows: the static scaling coefficient and the variable scaling coefficient are dedimensionalized to generate the dynamic scaling index; the specific formula is as follows:

[0024]

[0025] Among them, DR is the dynamic scaling index, ET is the static scaling coefficient, and DE is the variable scaling coefficient.

[0026] The present invention further provides a method for evaluating the dynamic scaling performance of a formation near the wellbore zone, the method being implemented by the evaluation system for the dynamic scaling performance of a formation near the wellbore zone, and specifically comprising:

[0027] Step 1: Collect formation parameters and formation water samples from the water injection station, analyze the composition of the formation water samples; and prepare simulated formation water and representative scale samples according to the analysis results; the formation parameters include formation temperature and formation water sample pH;

[0028] Step 2: Prepare a scale dissolving agent solution with simulated formation water, and conduct compatibility test on the scale dissolving agent solution prepared with simulated formation water to obtain the compatibility time and optimal concentration;

[0029] Step 3: Under the same pH conditions of the formation, use the optimal concentration of the scale dissolving agent solution to conduct a static scale dissolving experiment on the representative scale sample to obtain the static scale dissolving rate; generate the static scale dissolving coefficient through the compatibility time and the static scale dissolving rate;

[0030] Step 4: Select an artificial core whose core porosity differs from the actual reservoir core porosity by less than 0.01, slowly inject the optimal concentration of the scale dissolving agent solution into the artificial core, record the volume of the optimal concentration of the scale dissolving agent solution injected and the corresponding permeability, and draw a volume-permeability relationship diagram of the scale dissolving agent solution injected with the optimal concentration, and obtain the maximum damage injection volume and the optimal recovery permeability according to the volume-permeability relationship diagram of the scale dissolving agent solution injected with the optimal concentration, and generate a variable scale dissolving coefficient according to the optimal concentration, the maximum damage injection volume and the optimal recovery permeability;

[0031] Step 5: De-dimensionalize the static scaling coefficient and the variable scaling coefficient to generate a dynamic scaling index. The dynamic scaling performance of the formation near the wellbore is evaluated according to the dynamic scaling index. The larger the dynamic scaling index, the better the dynamic scaling performance of the formation near the wellbore.

[0032] Compared with the prior art, the beneficial effect of the present invention is that the present invention takes into account the dynamic changes in the environment during the actual exploitation of the oil field, the injection of solution and the cessation of exploitation, and conducts a detailed analysis of each situation, so that the conclusion drawn is more comprehensive and has the necessary comprehensiveness and universal adaptability.

[0033] The present invention generates a static scaling coefficient under static conditions, which reflects the dissolving ability of the optimal concentration scaling agent solution to the precipitate under static conditions; generates a changing scaling coefficient in the dynamic process of injecting the solution, which reflects the scaling ability of the solution when the volume of the optimal concentration scaling agent solution changes; the two coefficients are combined to form a dynamic scaling index that comprehensively reflects the dynamic scaling ability, and this coefficient can comprehensively reflect the dynamic scaling performance of the formation near the wellbore, making the final result more convincing. BRIEF DESCRIPTION OF THE DRAWINGS

[0034] Figure 1 It is a schematic diagram of the overall system structure of the present invention.

[0035] Figure 2 It is a schematic diagram of the overall method flow of the present invention. DETAILED DESCRIPTION

[0036] In order to make the objectives, technical solutions and advantages of the present invention more clearly understood, the present invention is further described in detail below in conjunction with specific embodiments.

[0037] It should be noted that, unless otherwise defined, the technical terms or scientific terms used in the present invention should be understood by people with ordinary skills in the field to which the present invention belongs. The words "first", "second" and similar words used in the present invention do not indicate any order, quantity or importance, but are only used to distinguish different components. "Include" or "comprise" and similar words mean that the elements or objects appearing before the word include the elements or objects listed after the word and their equivalents, without excluding other elements or objects. "Connect" or "connected" and similar words are not limited to physical or mechanical connections, but may include electrical connections, whether direct or indirect. "Up", "down", "left", "right" and the like are only used to indicate relative positional relationships. When the absolute position of the described object changes, the relative positional relationship may also change accordingly.

[0038] Example:

[0039] See also Figure 1 , the present invention provides a technical solution:

[0040] An evaluation system for dynamic scaling performance of formation near-wellbore zone, specifically comprising:

[0041] The sample preparation module is used to collect formation parameters and formation water samples from the water injection station, perform component analysis on the formation water samples, and prepare simulated formation water and representative scale samples according to the analysis results; the formation parameters include formation temperature and formation water sample pH;

[0042] According to SY / T5523-2016 "Oilfield Water Analysis Method", the water samples were subjected to CL - , Ca 2 + Mg 2+ , Sr 2+ / Ba 2+ 、Na + / K + , mineralization, water type and ten indexes are analyzed, and a water sample with ten indexes equal to those of the formation water sample is prepared as simulated formation water. The representative scale sample is a pure scale sample composed of the largest content of acid radical ions and metal cations.

[0043] A compatibility module is used to prepare a scale dissolving agent solution with simulated formation water, and to perform compatibility test on the scale dissolving agent solution prepared with simulated formation water to obtain the compatibility time and optimal concentration;

[0044] The specific operation of the compatibility test is: use simulated formation water to prepare scale dissolving agent solutions with concentrations of 15%, 20%, 25%, 30%, 35%, 40%, and 45%, respectively, let the solutions stand under formation temperature conditions, observe the time when precipitation first appears in each solution, define the concentration of the solution with the latest precipitation as the optimal concentration, and define the time when precipitation first appears the latest as the compatibility time.

[0045] The static test module is used to conduct static scaling experiments on representative scale samples using the optimal concentration of scaling agent solution under the same formation pH conditions to obtain the static scaling rate; the static scaling coefficient is generated through the compatibility time and the static scaling rate;

[0046] The specific operation of the static scale dissolution experiment is as follows: at the formation temperature, the pH of the optimal concentration of the scale dissolving agent solution is adjusted to the pH of the formation water sample, the filter paper weight M1 is weighed, the representative scale with a mass of M2 and the filter paper are placed in an oven at the formation temperature for drying, and the representative scale sample is placed in the solution at the formation temperature and allowed to react for 72 hours; after the reaction is completed, the solution in the ground-mouth triangular flask is filtered with filter paper, the filtered filter paper is placed in an oven for drying to constant weight, the total mass of the dried filter paper and the representative scale sample M3 is weighed, and the static scale dissolution rate is calculated, and the specific formula based on it is:

[0047]

[0048] Wherein, E is the static scaling rate. The static scaling rate E reflects the dissolution effect of the optimal concentration scaling agent solution on the precipitate under static conditions. The larger the value, the better the dissolution effect of the optimal concentration scaling agent solution on the precipitate under static conditions.

[0049] The specific logic for generating the static scaling coefficient is: the static scaling coefficient is generated by the compatibility time and the static scaling rate, and the specific formula is:

[0050]

[0051] Among them, ET is the static scaling coefficient, T is the compatibility time, and E is the static scaling rate. The static scaling coefficient ET reflects the ability of the optimal concentration scale dissolving agent solution to dissolve precipitation under static conditions. The larger its value, the stronger the ability of the optimal concentration scale dissolving agent solution to dissolve precipitation; the stronger the scaling ability under static conditions, the stronger the scaling ability under dynamic conditions. The generation of the static scaling coefficient can provide an important basis for the subsequent evaluation of dynamic scaling ability. The compatibility time T reflects the precipitation of the solution itself. The larger its value, the less likely the solution itself will produce precipitation.

[0052] The dynamic test module is used to select an artificial core whose core porosity differs from the actual reservoir core porosity by less than 0.01, slowly inject an optimal concentration of scale dissolving agent solution into the artificial core, record the volume of the optimal concentration of scale dissolving agent solution injected and the corresponding permeability, and draw a volume-permeability relationship diagram of the optimal concentration of scale dissolving agent solution injected, obtain the maximum damage injection volume and the optimal recovery permeability according to the volume-permeability relationship diagram of the optimal concentration of scale dissolving agent solution injected, and generate a variable scale dissolving coefficient according to the optimal concentration, the maximum damage injection volume and the optimal recovery permeability;

[0053] The specific logic for obtaining the maximum harmful injection volume and the optimal recovery permeability is as follows: in the volume-permeability relationship diagram of the scale-dissolving agent solution with the optimal concentration injected, the volume of the scale-dissolving agent solution with the optimal concentration injected when the permeability is the minimum is the maximum harmful injection volume, and among the points where the derivative of the permeability with respect to the volume is greater than or equal to 0, the maximum permeability is the optimal recovery permeability.

[0054] The specific logic for generating the variable scaling coefficient is: generating the variable scaling coefficient according to the optimal concentration, the maximum damage injection volume and the optimal recovery permeability; the specific formula is:

[0055]

[0056] Among them, DE is the variable scale dissolution coefficient, S is the optimal recovery permeability, C is the optimal concentration, and V is the maximum damage injection volume. The variable scale dissolution coefficient DE reflects the scale dissolution ability of the solution when the volume of the optimal concentration scale dissolving agent solution changes. The smaller its value, the stronger the scale dissolution ability of the solution when it is continuously injected. The generation of this coefficient can provide an important basis for the evaluation of dynamic scale dissolution. The optimal recovery permeability S reflects the highest level of permeability that the solution can restore. The larger its value, the higher the degree of permeability recovery; the maximum damage injection volume V reflects the decrease in permeability when the core has not adapted to the solution at the initial stage of solution injection. The smaller its value, the faster the core adapts to the solution; the optimal concentration C reflects the concentration required for the solution to achieve the best effect. The smaller its value, the lower the cost of mining, and the stronger the ability of the scale dissolving agent itself to play a scale dissolving role.

[0057] The performance evaluation module is used to dedimensionalize the static scaling coefficient and the variable scaling coefficient to generate a dynamic scaling index. The dynamic scaling performance of the formation near the wellbore is evaluated based on the dynamic scaling index. The larger the dynamic scaling index, the better the dynamic scaling performance of the formation near the wellbore.

[0058] The specific logic for generating the dynamic scaling index is: the static scaling coefficient and the dynamic scaling coefficient are dedimensionalized to generate the dynamic scaling index; the specific formula is:

[0059]

[0060] Among them, DR is the dynamic scaling index, ET is the static scaling coefficient, and DE is the variable scaling coefficient. The dynamic scaling index DR reflects the dynamic scaling ability of the solution during the entire mining process. The larger the value, the stronger the dynamic scaling ability of the solution during the mining process; the dynamic scaling index DR can provide an important basis for evaluating the dynamic scaling performance of the near-wellbore area of ​​the formation.

[0061] See also Figure 2 The present invention further provides a method for evaluating the dynamic scaling performance of a formation near the wellbore zone, the method being implemented by the evaluation system for the dynamic scaling performance of a formation near the wellbore zone, and specifically comprising:

[0062] Step 1: Collect formation parameters and formation water samples from the water injection station, analyze the composition of the formation water samples; and prepare simulated formation water and representative scale samples according to the analysis results; the formation parameters include formation temperature and formation water sample pH;

[0063] Step 2: Prepare a scale dissolving agent solution with simulated formation water, and conduct a compatibility test on the scale dissolving agent solution prepared with simulated formation water to obtain the compatibility time and the optimal concentration;

[0064] Step 3: Under the same pH conditions of the formation, use the optimal concentration of the scale dissolving agent solution to conduct a static scale dissolving experiment on the representative scale sample to obtain the static scale dissolving rate; generate the static scale dissolving coefficient through the compatibility time and the static scale dissolving rate;

[0065] Step 4: Select an artificial core whose core porosity differs from the actual reservoir core porosity by less than 0.01, slowly inject the optimal concentration of the scale dissolving agent solution into the artificial core, record the volume of the optimal concentration of the scale dissolving agent solution injected and the corresponding permeability, and draw a volume-permeability relationship diagram of the scale dissolving agent solution injected with the optimal concentration, and obtain the maximum damage injection volume and the optimal recovery permeability according to the volume-permeability relationship diagram of the scale dissolving agent solution injected with the optimal concentration, and generate a variable scale dissolving coefficient according to the optimal concentration, the maximum damage injection volume and the optimal recovery permeability;

[0066] Step 5: De-dimensionalize the static scaling coefficient and the variable scaling coefficient to generate a dynamic scaling index. The dynamic scaling performance of the formation near the wellbore is evaluated according to the dynamic scaling index. The larger the dynamic scaling index, the better the dynamic scaling performance of the formation near the wellbore.

[0067] The above formulas are all dimensionless and numerical calculations. The formula is a formula for the most recent real situation obtained by collecting a large amount of data and performing software simulation. The preset parameters in the formula are set by technicians in this field according to actual conditions.

[0068] The above embodiments may be implemented in whole or in part by software, hardware, firmware or any other combination thereof. When implemented by software, the above embodiments may be implemented in whole or in part in the form of a computer program product. Those skilled in the art may appreciate that the units and algorithm steps of each example described in conjunction with the embodiments disclosed herein may be implemented by electronic hardware, or a combination of computer software and electronic hardware. Whether these functions are performed by hardware or software methods depends on the specific application and design constraints of the technical solution.

[0069] The units described as separate components may or may not be physically separated, and the components shown as units may or may not be physical units, and 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 solution of this embodiment.

[0070] The above description is only a specific implementation manner of the present application, but the protection scope of the present application is not limited thereto. Any technician familiar with the 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.

Claims

1. An evaluation system for dynamic scaling performance of formation near wellbore zone, characterized in that: Specifically include: The sampling module is used to collect formation parameters and formation water samples from the water injection station and perform composition analysis on the formation water samples; and preparing simulated formation water and representative scale samples according to the analysis results; the formation parameters include formation temperature and formation water sample pH; A compatibility module is used to prepare a scale dissolving agent solution with simulated formation water, and to perform compatibility test on the scale dissolving agent solution prepared with simulated formation water to obtain the compatibility time and optimal concentration; The static test module is used to conduct static scaling experiments on representative scale samples using the optimal concentration of scaling agent solution under the same formation pH conditions to obtain the static scaling rate; the static scaling coefficient is generated through the compatibility time and the static scaling rate; The dynamic test module is used to select an artificial core whose core porosity differs from the actual reservoir core porosity by less than 0.01, slowly inject an optimal concentration of scale dissolving agent solution into the artificial core, record the volume of the optimal concentration of scale dissolving agent solution injected and the corresponding permeability, and draw a volume-permeability relationship diagram of the optimal concentration of scale dissolving agent solution injected, obtain the maximum damage injection volume and the optimal recovery permeability according to the volume-permeability relationship diagram of the optimal concentration of scale dissolving agent solution injected, and generate a variable scale dissolving coefficient according to the optimal concentration, the maximum damage injection volume and the optimal recovery permeability; The performance evaluation module is used to de-dimensionalize the static scaling coefficient and the variable scaling coefficient to generate a dynamic scaling index. The dynamic scaling performance of the formation near the wellbore is evaluated according to the dynamic scaling index. The larger the dynamic scaling index, the better the dynamic scaling performance of the formation near the wellbore. The specific operation of the compatibility test is: using simulated formation water to prepare scale dissolving agent solutions with concentrations of 15%, 20%, 25%, 30%, 35%, 40%, and 45%, respectively, leaving the solutions to stand at formation temperature, observing the time when precipitation first appears in each solution, defining the concentration of the solution with the latest precipitation as the optimal concentration, and defining the time when precipitation first appears in the latest solution as the compatibility time; The specific operation of the static scale dissolution experiment is as follows: at the formation temperature, the pH of the optimal concentration of the scale dissolving agent solution is adjusted to the pH of the formation water sample, the filter paper weight M1 is weighed, the representative scale with a mass of M2 and the filter paper are placed in an oven at the formation temperature for drying, and the representative scale sample is placed in the solution at the formation temperature and allowed to react for 72 hours; after the reaction is completed, the solution in the ground-mouth triangular flask is filtered with filter paper, the filtered filter paper is placed in an oven for drying to constant weight, the total mass of the dried filter paper and the representative scale sample M3 is weighed, and the static scale dissolution rate is calculated, and the specific formula based on it is: Wherein, E is the static scaling rate; The specific logic for generating the static scaling coefficient is: the static scaling coefficient is generated by the compatibility time and the static scaling rate, and the specific formula is: Among them, ET is the static scaling coefficient, T is the compatibility time, and E is the static scaling rate; The specific logic for obtaining the maximum harmful injection volume and the best recovery permeability is as follows: in the volume-permeability relationship diagram of the scale dissolving agent solution with the best concentration injected, the volume of the scale dissolving agent solution with the best concentration injected when the permeability is the smallest is the maximum harmful injection volume, and the maximum permeability among the points where the derivative of the permeability to the volume is greater than or equal to 0 is the best recovery permeability; The specific logic for generating the variable scaling coefficient is: generating the variable scaling coefficient according to the optimal concentration, the maximum damage injection volume and the optimal recovery permeability; the specific formula is: Among them, DE is the variable scale dissolution coefficient, S is the optimal recovery permeability, C is the optimal concentration, and V is the maximum damage injection volume; The specific logic for generating the dynamic scaling index is: the static scaling coefficient and the variable scaling coefficient are dedimensionalized to generate the dynamic scaling index; the specific formula is: Among them, DR is the dynamic scaling index, ET is the static scaling coefficient, and DE is the variable scaling coefficient.

2. A method for evaluating the dynamic scaling performance of a formation near a wellbore, characterized in that: The method is implemented by the evaluation system for dynamic scaling performance of the formation near the wellbore area according to claim 1, and specifically comprises: Step 1: Collect formation parameters and formation water samples from the water injection station, analyze the composition of the formation water samples; and prepare simulated formation water and representative scale samples according to the analysis results; the formation parameters include formation temperature and formation water sample pH; Step 2: Prepare a scale dissolving agent solution with simulated formation water, and conduct compatibility test on the scale dissolving agent solution prepared with simulated formation water to obtain the compatibility time and optimal concentration; Step 3: Under the same pH conditions of the formation, use the optimal concentration of the scale dissolving agent solution to conduct a static scale dissolving experiment on the representative scale sample to obtain the static scale dissolving rate; generate the static scale dissolving coefficient through the compatibility time and the static scale dissolving rate; Step 4: Select an artificial core whose core porosity differs from the actual reservoir core porosity by less than 0.01, slowly inject the optimal concentration of the scale dissolving agent solution into the artificial core, record the volume of the optimal concentration of the scale dissolving agent solution injected and the corresponding permeability, and draw a volume-permeability relationship diagram of the scale dissolving agent solution injected with the optimal concentration, and obtain the maximum damage injection volume and the optimal recovery permeability according to the volume-permeability relationship diagram of the scale dissolving agent solution injected with the optimal concentration, and generate a variable scale dissolving coefficient according to the optimal concentration, the maximum damage injection volume and the optimal recovery permeability; Step 5: De-dimensionalize the static scaling coefficient and the variable scaling coefficient to generate a dynamic scaling index. The dynamic scaling performance of the formation near the wellbore is evaluated according to the dynamic scaling index. The larger the dynamic scaling index, the better the dynamic scaling performance of the formation near the wellbore.

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