Method and system for automatically and rapidly generating drilling and completion biological enzyme blocking removal scheme

Abstract

The invention discloses a method and system for automatically and rapidly generating a drilling and completion plug removal scheme, and relates to the technical field of drilling and completion plug removal. According to the scheme, the method comprises the steps of S1, calling basic parameters from a drilling database; s2, outputting a blockage coefficient K by using the classification judgment model and identifying a blockage type; s3, calling a sand prevention and plug removal sequence optimization rule, matching a composite acid, bio-enzyme and surfactant system, and generating an injection scheme through an injection amount calculation formula and a sequence rule; and S4, implementing and verifying. The method has the beneficial effects that the blockage of inorganic scales, organic macromolecules, solid particles and a crude oil mixture can be quickly and accurately judged, and the limitation of empirical judgment is avoided; based on scientific calculation of a pollution coefficient and a treatment radius, reasonable dosing of the medicament is realized; and in combination with sequential optimization of reservoir types and rock cementation indexes and multi-system collaborative injection, the skin coefficient is stably reduced to 0.5 or below, the permeability recovery rate reaches 82%-88% or above, and the blockage removal efficiency and accuracy are remarkably improved.

Description

Technical Field

[0001] This invention relates to the field of drilling, completion and unblocking technology, and in particular to a method and system for automatically and rapidly generating drilling, completion and unblocking solutions. Background Technology

[0002] As oil and gas exploration and development enters the stages of deep, ultra-deep, and unconventional reservoirs, wellbore blockage during drilling and completion has become increasingly prominent. Drilling fluid, after being lost through the wellbore, forms a dense mud cake around the wellbore. The interaction between completion fluid and formation fluids, cuttings, or residual drilling fluid components can also cause blockage of pores, microfractures, and screen perforations. To restore permeability channels and reduce the skin effect, scholars and engineers both domestically and internationally have explored various unblocking techniques, including acidizing, bio-enzymatic degradation, and surfactant dispersion. These technologies can improve permeability to some extent and alleviate some of the damage caused by drilling fluids or polymers, playing a positive role in increasing and stabilizing oil well production.

[0003] However, existing well completion and unclogging technologies still have significant shortcomings. Firstly, most processes still rely on experience and fixed formulations, typically involving the direct injection of a certain amount of acid, enzymes, or surfactants into the wellbore, lacking a correlation with specific well geological parameters. This leads to significant differences in unclogging effectiveness under varying salinity, clay content, permeability, or crude oil viscosity conditions, resulting in excessive dosage and poor economic and environmental performance. Secondly, existing technologies generally lack parameter-based classification mechanisms, making it difficult to promptly distinguish between different types of blockages, such as inorganic scale, solid particles, organic macromolecules, or crude oil mixtures. This often results in "treating the symptoms but not the cause," severely impacting unclogging efficiency. Thirdly, the patent CN102373037A, titled "A Novel Bio-Unblocking Fluid for Well Completion and its Production Method," proposes a compound unblocking fluid made with water as the base fluid, combined with surfactants (2-5%), flow modifiers (1-5%), and bio-enzymes (6-8%). This fluid is primarily used to dissolve the polymer structure in the drilling fluid filter cake, thereby breaking down the filter cake and preventing secondary pollution of the reservoir. However, its drawbacks include the lack of a classification mechanism to determine the type of blockage based on parameters such as reservoir permeability, salinity, and crude oil viscosity in different oil wells; and the inability to distinguish between organic / inorganic or emulsion-type blockages, resulting in a limited "one-size-fits-all" approach. The injection volume is fixed, and quantitative calculations of the contamination radius and concentration are not involved. The injection sequence and sand control strategies are not addressed, lacking systematic process optimization. Furthermore, most existing methods lack quantitative calculations of the contamination radius and clogging intensity, and do not optimize the sequence in conjunction with sand control measures, leading to a high risk of re-clogging after declogging and difficulty in achieving stable production increases. More importantly, there is a lack of a systematic closed-loop feedback mechanism on-site; if the declogging effect is unsatisfactory, repeated operations are often necessary, increasing time and costs. Therefore, in practical applications, existing technologies have failed to truly and efficiently address the industry's need for efficient and precise solutions to well completion clogging.

[0004] Therefore, the core need in the current drilling, completion, and unblocking field lies in: how to establish a new unblocking process that can quickly and accurately determine the blockage conditions based on pre-well data, clarify the blockage type and influencing factors, and thus provide a scientific basis for the selection of unblocking agent systems and the design of injection volumes; at the same time, it is also necessary to comprehensively consider the sequential relationship between sand control and unblocking to form a more rational process flow. In other words, the urgent technical problem to be solved is: how to overcome the limitations of existing processes, such as lack of accurate judgment, lack of targeted system mapping, and lack of quantitative injection volume and sequence optimization, and propose a set of efficient, accurate, and low-volume drilling, completion, and unblocking solutions to significantly improve the success rate and economy of unblocking, and meet the urgent needs of high efficiency, safety, and environmental protection in the development of deep and unconventional oil and gas reservoirs. Summary of the Invention

[0005] Existing well completion unblocking processes typically rely on empirical or fixed formulations, indiscriminately adding acids, enzymes, or surfactants. This lack of differentiated design for various well conditions leads to low unblocking efficiency, high dosage, and low success rates. The main technical problems are: inability to quickly determine the blockage type using pre-well data; lack of matching in unblocking system selection; inaccurate calculation of injection volume and contamination radius; insufficient optimization of the unblocking and sand control sequence; and lack of a closed-loop feedback mechanism for on-site effects. These problems are interdependent and mutually influential: the blockage type determination determines the system selection, the system selection affects the injection volume calculation, the injection volume affects the injection sequence and sand control measures, and feedback on the construction effect requires reverse correction of the determination and parameter settings. To address these difficulties, this invention proposes a well completion bio-enzyme composite system unblocking process based on a well parameter database and classification determination model. By determining the blockage conditions and outputting the blockage coefficient K, it achieves precise screening of the unblocking system, reasonable calculation of the injection volume, and optimization of the sand control and unblocking sequence. Combined with skin coefficient feedback, this overcomes the shortcomings of the existing "one-size-fits-all" approach, significantly improving unblocking efficiency and success rate.

[0006] To achieve the above-mentioned objectives and address the aforementioned technical problems, this invention provides a well completion and drilling combined unblocking system with a process for unblocking and increasing production, comprising the following steps: S1 collects basic parameters of oil wells and oil reservoirs and performs standardized preprocessing; S2 uses the classification judgment model based on the basic parameters to determine the classification conditions and outputs the corresponding congestion coefficient K; S3 calls the sand-prevention and unblocking sequence optimization rules, calls the unblocking composite system matched by the classification conditions, the injection volume calculation formula, the injection sequence rules, and generates an injection plan that includes the unblocking composite system, the injection volume and sequence of each system; S4 performs automatic feasibility verification and parameter backtracking optimization of the injection scheme to achieve closed-loop control for unblocking.

[0007] Preferably, the basic parameters are derived from the basic parameters of oil wells and oil reservoirs in the data parameter database collected in the early stage of oil wells, including at least oil well permeability, salinity, clay content, crude oil viscosity, horizontal well section length or vertical / inclined well perforation section thickness, porosity, reservoir parameters, and skin coefficient.

[0008] Preferably, the classification and determination model in step S2 performs multi-condition cross-determination on the standardized preprocessed basic parameters according to the following rules and outputs the blockage condition type and blockage coefficient K; Condition C1: Mineralization ≥ 20000 mg / L or (Ca 2+ +Mg 2+ ≥500mg / L or permeability >1000mD or clay content ≥20%; Condition C2: Permeability is between 100 and 1000 mD; Condition C3: Crude oil viscosity is between 500 and 5000 mPa·s; When a certain condition is met, it is recorded as a valid blocking condition; the blocking coefficient K is the number of all valid blocking conditions, and its value ranges from 0 to 3; Here, K=0 indicates no blockage, K≥1 indicates blockage, and the larger the K value, the more conditions there are.

[0009] Preferably, in condition C1, when the mineralization is ≥20000 mg / L or (Ca... 2+ +Mg 2+ When the concentration of minerals is ≥500 mg / L, it is defined as inorganic scale blockage; when the permeability is ≥1000 mD or the mud content is ≥20%, it is defined as solid particle blockage; condition C2 is defined as organic macromolecular blockage; condition C3 is defined as crude oil mixture blockage.

[0010] Preferably, step 2 further comprises: When the congestion coefficient K≥1, proceed to step 3; Preferably, the optimization rule for the sand-blocking and unclogging sequence in step S3 is as follows: For clastic rock reservoirs, the approach is to first prevent sand from entering the reservoir and then unblock it. Carbonate / igneous / metamorphic rock reservoirs: adopt the approach of first preventing sand blockage and then unblocking; For sandstone reservoirs with a rock cementation index ≤ 0.5: adopt the approach of first controlling sand and then unblocking. For sandstone reservoirs with a cementation index > 0.5: adopt the approach of first unblocking and then preventing sand accumulation; Preferably, the mapping relationship model of the unblocking composite system includes C1 mapping to a composite acid unblocking system; C2 mapping to a biological enzyme unblocking system; and C3 mapping to a biological surfactant unblocking system. Preferably, the injection volume of the unblocking system is calculated using the following formula:

[0011] in: -Injection volume, m³; -Pollution coefficient; - Processing radius, m; - Length of horizontal well section or thickness of perforated section in vertical or inclined well, in meters; -Porosity, % When condition C1 is met: pollution coefficient 1.1~1.3, treatment radius 1~2m; When condition C2 is met: pollution coefficient 1.3–1.6, treatment radius 1.2–2.5m; When condition C3 is met: pollution coefficient 1.0~1.5, treatment radius 1.5~3m; In the aforementioned bio-enzyme composite unblocking system, the concentration of the composite acid used is 2000–4000 ppm, the concentration of the bio-enzyme used on-site is 1000–3000 ppm, and the concentration of the biosurfactant used on-site is 3000–5000 ppm. Preferably, the injection sequence of the composite unblocking system in step S3 is as follows: (1) When K=1, only the unblocking system corresponding to the conditions is injected to replace the formation water, soak it, and then drain it back; (2) When K>1, follow the established sequence of injecting biosurfactant system → injecting bioenzyme system → injecting compound acid system. Each injection is used to replace formation water and maintain soaking, and finally drain back. Preferably, in step S3, the injection process is as follows: (1) The blockage type is inorganic scale blockage and solid particulate blockage. The designed amount of composite acid system is injected to replace 10m³ of formation water. 3 Soak for 6-12 hours and then drain. (2) The blockage type is organic macromolecular blockage. The designed amount of biological enzyme system is injected to replace 10m³ of formation water. 3 Soak for 12–24 hours and then drain. (3) The blockage type is crude oil mixture blockage. The designed amount of biosurfactant system is injected to replace 10m³ of formation water. 3 Soak for 24–48 hours without backflow; (4) The blockage types are inorganic scale blockage, solid particulate blockage, and organic macromolecular blockage. First, inject the designed amount of biological enzyme to replace 10m³ of formation water. 3 Soak for 12–24 hours and then drain; then inject the designed amount of composite acid to displace 10m³ of formation water. 3 Soak for 6–12 hours, then drain. (5) The blockage type is organic macromolecular blockage and crude oil mixture blockage. First, inject the designed amount of biosurfactant system to replace 10m of formation water. 3 Soak for 24–48 hours without backflushing; then inject the designed amount of bio-enzymes to replace 10m³ of formation water. 3 Soak for 12–24 hours and then drain. (6) The blockage types are inorganic scale blockage, solid particulate blockage, and crude oil mixture blockage. First, inject a biosurfactant system to replace 10m of formation water. 3 Soak for 24–48 hours without backflushing; then inject compound acid to displace 10m of formation water. 3 Soak for 6–12 hours, then drain. (7) The blockage types are inorganic scale blockage, solid particulate blockage, organic macromolecular blockage, and crude oil mixture blockage. First, inject a biosurfactant system to replace 10m of formation water. 3 Soak for 24–48 hours without backflushing; then inject bio-enzymes to replace 10m³ of formation water. 3 After soaking for 12-24 hours, the water is drained back; finally, a 10m³ compound acid is injected to displace the formation water. 3 Soak for 6-12 hours and then drain.

[0012] Preferably, the verification of the implementation results in step S4 uses the skin coefficient after well unblocking as the judgment index: (1) When the skin coefficient is ≤0.5, the blockage is considered successfully resolved and normal production resumes; (2) When the skin coefficient is >0.5, call and check the construction site process to find the cause.

[0013] This invention also provides an automatic and rapid generation system for well unblocking schemes after drilling and completion, comprising: an oil well parameter acquisition module for acquiring basic oil well parameters after drilling and completion; a blockage type determination module for determining the blockage type based on the oil well parameters; a unblocking system matching module for matching a corresponding composite unblocking system according to the blockage type; a process path generation module for generating a corresponding injection sequence and dosage scheme according to the matched unblocking system; and an effect feedback module for acquiring wellbore response data during and after the unblocking process and evaluating the unblocking effect.

[0014] The beneficial effects of the technical solution provided by this invention are as follows: (1) Fast and accurate blockage identification By establishing a parameter retrieval and standardized processing mechanism based on pre-well data, this invention can directly determine blockage conditions without resampling. A classification and determination model is used to cross-determine multiple parameters such as permeability, salinity, crude oil viscosity, and mud content, outputting a blockage coefficient K. This allows for precise differentiation of different blockage types, including inorganic scale, organic macromolecules, solid particles, and crude oil mixtures. This approach avoids the shortcomings of traditional processes that rely on experience or single-indicator judgments, making blockage type determination more scientific and objective.

[0015] (2) Targeted matching of congestion relief system with congestion type Based on the judgment results, the system automatically maps to a complex acid system, a bio-enzyme system, and a biosurfactant system, and combines them according to the clogging conditions. This method ensures that the type of reagent matches the physicochemical properties of the blockage; for example, acid preferentially dissolves inorganic scale, bio-enzymes specifically degrade polymeric residues, and surfactants effectively demulsify and disperse crude oil micelles. This targeted matching avoids the limitations of traditional processes that attempt to solve all blockages with a single reagent, ensuring multi-dimensional resolution of complex blockages from a mechanistic perspective.

[0016] (3) Scientific calculation of injection volume based on pollution coefficient This invention incorporates the contamination coefficient, treatment radius, reservoir thickness, and porosity into its calculations, enabling the quantification of injection requirements under different blockage conditions. The contamination coefficient reflects the intensity of the blockage, while the treatment radius reflects the extent of the contamination's impact. The combination of these two factors ensures that the dosage of reagents avoids both incomplete deblocking due to insufficient dosage and secondary damage or resource waste due to excessive dosage. Compared to traditional methods relying on experience-based dosage, this approach achieves higher deblocking efficiency and more stable reservoir recovery.

[0017] (4) Sequence optimization and multi-system synergy In process design, this invention combines reservoir type and rock cementation index to propose an optimized sequence rule of either sand control followed by unblocking or unblocking followed by sand control. Furthermore, it sets an injection sequence of biosurfactant → bioenzyme → acid for multi-system injection. This sequence design is based on mechanistic considerations: first, surfactants are used to demulsify and reduce oil-water interfacial tension, loosening the blockage; then, bioenzymes catalytically degrade organic components; and finally, acid is used to dissolve residual inorganic scale. The synergistic effect of multiple systems allows various types of blockages to be gradually eliminated, resulting in a significant decrease in the skin factor.

[0018] (5) Significant effect of congestion relief technology Through the combined effects of database access, classification and judgment, scientific application, and sequence optimization, the unblocking effect is manifested in a stable reduction of the skin coefficient to ≤0.5, with most wells dropping below 0.1, and a stable permeability recovery rate of ≥82% to 88%. Compared with traditional empirical processes, this invention achieves more thorough restoration of seepage channels and a more lasting production increase effect, fully demonstrating the effectiveness of the technical solution of this invention in solving the problem of combined blockage during drilling and completion. Attached Figure Description

[0019] Figure 1 This is a diagram illustrating the method steps of an embodiment of the present invention; Figure 2 This is a system block diagram of an embodiment of the present invention; Figure 3 This is a flowchart of an embodiment of the present invention. Detailed Implementation

[0020] To make the objectives, technical solutions, and advantages of this invention clearer, the invention will be further described in detail below with reference to embodiments. Of course, the specific embodiments described herein are merely illustrative and not intended to limit the invention.

[0021] Example 1 A certain block in Shengli Oilfield belongs to a sandstone reservoir. Well LA is a vertical well with a reservoir temperature of 55℃ and geological reserves of 2.3×10⁻⁶. 5 t, porosity 30.2%, pressure 10.5 MPa, average permeability 780 mD, crude oil viscosity 560 mPa·s, salinity 12000 mg / L, Ca 2+ +Mg 2+ The reservoir contained 356 mg / L of minerals, 15% clay, and had a thickness of 8.6 m and a rock cementation index of 0.8. After drilling fluid backflow, the reservoir became clogged, and the well skin coefficient was measured to be 3.1. The method for automatically and rapidly generating a drilling, completion, and unclogging solution according to this invention is described below: (1) Retrieve basic parameters of oil wells and oil reservoirs from the drilling database. Average permeability 780 mD, crude oil viscosity 560 mPa·s, salinity 12000 mg / L, Ca 2+ +Mg 2+ Content 356mg / L, mud content 15%.

[0022] (2) Based on the basic parameters, the classification judgment model is used to determine the classification type as conditions C2 and C3, and the oil well blockage is defined as organic macromolecule blockage and crude oil mixture blockage, and the corresponding blockage coefficient K=2 is output.

[0023] (3) Call the sand control and unblocking sequence optimization rule: Sandstone reservoir, rock cementation index 0.8, adopt the method of unblocking first and then sand control.

[0024] (4) Screening of composite unblocking systems The composite unblocking system combines a bio-enzyme system and a bio-surfactant system. The bio-enzyme system consists of amylase and mannanase in a 1:1 mass ratio, which degrades organic macromolecules. The bio-surfactant system consists of lipopeptides, which demulsify the crude oil and remove blockages from the crude oil mixture.

[0025] (5) Determination of injection volume and injection process for composite unblocking system The injection volume of the composite unblocking system is calculated by a formula. Because it meets the C2 and C3 conditions, there is a combination of organic macromolecular blockage and crude oil blockage. The C2 contamination coefficient is 1.3, and the treatment radius r2 is 1.2m; the C3 contamination coefficient... e The contamination coefficient is 1.0, and the treatment radius r3 is 1.5m. The reservoir thickness is 8.6m, and the porosity is 30.2%. Definitions: The contamination coefficient of C1 is represented by α, and the treatment radius is r1; the contamination coefficient of C2 is represented by β, and the treatment radius is r2; the contamination coefficient of C3 is... e This indicates that the processing radius is r3.

[0026] Calculate the injection volume of the biological enzyme system:

[0027] =1.3 × 3.14 × 1.2 2 ×8.6×0.302 =15.3m 3 Calculate the injection volume of the biosurfactant unblocking system:

[0028] =1.0 × 3.14 × 1.5 2 ×8.6×0.302 =18.3m 3 The concentration of the bio-enzyme used on-site is 1000 ppm, the concentration of the biosurfactant used on-site is 3000 ppm, the indoor catalytic degradation rate is 97%, and the permeability recovery rate is 85%.

[0029] (6) On-site application and effect tracking analysis In the field application, the biosurfactant system was first injected at a depth of 18.3 m. 3 Displaced 10m of formation water 3 Soak for 24 hours without backflushing; then inject the designed amount of bio-enzyme 15.3mg. 3 Displaced 10m of formation water 3The sample was soaked for 12 hours and then drained. The skin coefficient after treatment was measured to be 0.1. The well was then put into production with a fluid volume of 25 t / d and an oil volume of 12 t / d, resulting in an input-output ratio of 1:18.

[0030] Example 2 A certain block in Shengli Oilfield belongs to a sandstone reservoir. Well LB is a vertical well with a reservoir temperature of 67℃ and geological reserves of 5.8 × 10⁻⁶. 5 t, porosity 31%, pressure 11.5 MPa, average permeability 720 mD, crude oil viscosity 5668 mPa·s, salinity 24000 mg / L, Ca 2+ +Mg 2+ The reservoir contained 540 mg / L of minerals, 16% clay, and had a thickness of 3.7 m and a rock cementation index of 0.85. After drilling fluid backflow, the reservoir became clogged, and the well skin coefficient was measured to be 5.8. The method for automatically and rapidly generating a drilling, completion, and unclogging solution according to this invention is described below: (1) Retrieve basic parameters of oil wells and oil reservoirs from the drilling database. Average permeability 720 mD, crude oil viscosity 5668 mPa·s, salinity 24000 mg / L, Ca 2+ +Mg 2+ The content is 540 mg / L, the clay content is 16%, and the well skin coefficient is 5.8.

[0031] (2) Based on the basic parameters, the classification judgment model is used to determine the classification type as conditions C1 and C3, and the oil well blockage type is defined as inorganic scale blockage and organic macromolecular blockage, and the corresponding blockage coefficient K=2 is output. (3) Call the sand control and unblocking sequence optimization rule: Sandstone reservoir, rock cementation index 0.85, adopt the method of unblocking first and then sand control.

[0032] (4) The composite unblocking system is matched with the composite acid and bio-enzyme system. The composite acid system is composed of hydrofluoric acid and fruit acid in a mass ratio of 1:1, which removes inorganic scale blockage; the bio-enzyme system is composed of cellulase and amide polymer decomposing enzyme in a mass ratio of 2:1, which degrades organic macromolecules.

[0033] (5) Determination of injection process for composite unblocking system The injection volume of the composite unblocking system is calculated using a formula. Because it meets conditions C1 and C3, it exhibits a combination of inorganic scale blockage and organic macromolecular blockage, with a contamination coefficient α of 1.1 and a treatment radius r1 of 1.5 m; the contamination coefficient β is 1.4 and the treatment radius r2 is 1.5 m. The reservoir thickness is 3.7 m, and the porosity is 31%. The contamination coefficient and treatment radius are defined as in Example 1.

[0034] Calculate the injection volume of the composite acid unblocking system:

[0035] =1.1 × 3.14 × 1.5 2 ×3.7×0.31 =8.9m 3 Calculate the injection volume of the biological enzyme system:

[0036] =1.4 × 3.14 × 1.5 2 ×3.7×0.31 =11.3m 3 The bio-enzyme composite unblocking system uses a composite acid concentration of 2000 ppm and a bio-enzyme concentration of 1500 ppm on-site. The indoor catalytic degradation rate is 95%, and the permeability recovery rate is 82%.

[0037] (6) On-site application and effect tracking analysis For on-site application, the biological enzyme system is first injected at a depth of 11.3m. 3 Displaced 10m of formation water 3 Soak for 24 hours and then drain; then inject 8.9m of a compound acid system. 3 Displaced 10m of formation water 3 After soaking for 6 hours, the solution was backflowed. The skin coefficient after treatment was measured to be 0.05. Then, the oil well was started for production, with a fluid volume of 15t / d and an oil volume of 8t / d, resulting in an input-output ratio of 1:19.

[0038] Example 3 A certain block in Shengli Oilfield belongs to a sandstone reservoir. The LC well is a vertical well, the reservoir temperature is 71℃, and the geological reserves are 10.2×10⁻⁶. 5 t, porosity 30.5%, pressure 11MPa, average permeability 450mD, crude oil viscosity 260mPa.s, salinity 45000mg / L, Ca 2+ +Mg 2+ The reservoir contained 610 mg / L of sediment, 12% clay, and had a thickness of 5.2 m. After drilling fluid backflow, the reservoir became clogged, and the well skin coefficient was measured to be 4.3. The method for automatically and rapidly generating a drilling, completion, and unclogging solution according to this invention is described below: (1) Retrieve basic parameters of oil wells and oil reservoirs from the drilling database. Average permeability 450 mD, crude oil viscosity 260 mPa·s, salinity 45000 mg / L, Ca 2+ +Mg 2+ The content is 610 mg / L, the clay content is 12%, and the well skin coefficient is 4.3.

[0039] (2) Based on the basic parameters, the classification judgment model is used to determine the classification type as conditions C1, C2, and C3, and the well blockage type is defined as inorganic scale blockage, organic macromolecular blockage, and crude oil mixture blockage, and the corresponding blockage coefficient K=3 is output. (3) Call the optimization rule for sand control and unblocking sequence: Sandstone reservoir with rock cementation index of 0.78, adopt the method of unblocking first and then sand control.

[0040] (4) The composite unblocking system is matched with a composite acid, bio-enzyme and bio-surfactant system. The composite acid system is composed of hydrochloric acid and sulfinic acid in a mass ratio of 1:1, which removes inorganic scale blockage; the bio-enzyme is composed of amylase and β-glucanase (2:1), which removes organic macromolecular blockage; the bio-surfactant system is composed of lipopeptides and rhamnolipids (ratio), which demulsifies crude oil and removes blockage of crude oil mixture.

[0041] (5) Determination of injection process for composite unblocking system The injection volume of the composite unblocking system is calculated by a formula. Because it meets conditions C1, C2, and C3, for inorganic scale blockage, organic macromolecular blockage, and combined blockage of crude oil mixtures, the contamination coefficient α is 1.3, and the treatment radius r1 is 2m; the contamination coefficient β is 1.6, and the treatment radius r2 is 2.5m; the contamination coefficient for crude oil mixture blockage... e The concentration factor is 1.5, and the treatment radius r3 is 3m. The reservoir thickness is 5.2m, the porosity is 30.5%, and the contamination factor and treatment radius are defined as in Example 1.

[0042] Calculate the injection volume of the composite acid unblocking system:

[0043] =1.3×3.14×2 2 ×5.2×0.305 =25.9m 3 Calculate the injection volume of the biological enzyme system:

[0044] =1.6 × 3.14 × 2.5 2 ×5.2×0.305 =49.8m 3 Calculate the injection volume of the biosurfactant unblocking system:

[0045] =1.5×3.14×3 2 ×5.2×0.305 =67.2m 3 The bio-enzyme composite unblocking system uses a composite acid concentration of 3000 ppm, a bio-enzyme concentration of 2000 ppm, and a biosurfactant concentration of 3000 ppm. The indoor catalytic degradation rate is 97%, and the permeability recovery rate is 88%.

[0046] (6) On-site application and effect tracking analysis In the field application, 67m of the biosurfactant system was first injected. 3 Displaced 10m of formation water 3 Soak for 24 hours without backflushing; then inject 49.8 ml of the bio-enzyme system. 3 Displaced 10m of formation water 3 After soaking for 24 hours, the solution was drained; finally, a 25.9m³ compound acid system was injected. 3 Displaced 10m of formation water 3 After soaking for 6 hours, the solution was backflowed. The skin coefficient after treatment was measured to be 0.02. Then, the oil well was started for production, with a fluid volume of 21t / d and an oil volume of 15t / d, resulting in an input-output ratio of 1:21.

[0047] Example 4 A certain block in Shengli Oilfield belongs to a sandstone reservoir. The LD well is a horizontal well, the reservoir temperature is 65℃, and the geological reserves are 3.7×10⁻⁶. 5 t, porosity 30.5%, pressure 10.2 MPa, average permeability 670 mD, crude oil viscosity 7550 mPa·s, salinity 13000 mg / L, Ca 2+ +Mg 2+ The content was 320 mg / L, the clay content was 11%, the horizontal perforation length was 80 m, and the rock cementation index was 0.84. After drilling fluid backflow, the reservoir was blocked, and the well skin coefficient was measured to be 6.8. The blockage was removed using a drilling and completion bio-enzyme composite system unblocking process according to this invention. The specific steps are as follows: (1) Retrieve basic parameters of oil wells and oil reservoirs from the drilling database. Average permeability 670 mD, crude oil viscosity 7550 mPa·s, salinity 13000 mg / L, Ca 2+ +Mg 2+ The content is 320 mg / L, the clay content is 11%, and the well skin coefficient is 6.8.

[0048] (2) Based on the basic parameters, the classification judgment model is used to determine the classification type as condition C2, and the well blockage type is defined as organic macromolecular blockage, and the corresponding blockage coefficient K=1 is output.

[0049] (3) Call the optimization rule for sand prevention and unblocking sequence: Sandstone reservoir with rock cementation index of 0.84, adopt the method of unblocking first and then sand prevention.

[0050] (4) Screening of composite unblocking systems The composite unblocking system is matched with a bio-enzyme system. The bio-enzyme system consists of amide polymer-degrading enzymes and mannanase in a 1:1 mass ratio, which removes blockages caused by large organic molecules.

[0051] (5) Determination of injection process for composite unblocking system The injection volume of the composite unblocking system is calculated by a formula. Due to the presence of organic macromolecular blockage under C2 conditions, the pollution coefficient β is 1.3, and the treatment radius r2 is 1.2m. The horizontal perforation length is 80m, and the porosity is 30.5%. The pollution coefficient and treatment radius are defined as in Example 1.

[0052] Calculate the injection volume of the biological enzyme system:

[0053] =1.3 × 3.14 × 1.2 2 ×80×0.305 =143.4m 3 The concentration of the bio-enzyme used on-site is 2000 ppm, with an indoor catalytic degradation rate of 96% and a permeability recovery rate of 88%.

[0054] (6) On-site application and effect tracking analysis For on-site application, the biological enzyme system was first injected at a concentration of 143.4 m³. 3 Displaced 10m of formation water 3 The sample was soaked for 24 hours and then drained. The skin coefficient after treatment was measured to be 0.01. The oil well was then put into production with a fluid volume of 56 t / d and an oil volume of 30 t / d, resulting in an input-output ratio of 1:25.

[0055] Example 5 A certain block in Shengli Oilfield belongs to a carbonate reservoir. Well LE is a vertical well with a reservoir temperature of 55℃ and geological reserves of 7.8×10⁻⁶. 5 t, porosity 31%, pressure 10.7 MPa, average permeability 1670 mD, crude oil viscosity 7460 mPa·s, salinity 53000 mg / L, Ca 2+ +Mg 2+ The reservoir contained 821 mg / L of sediment, 18% clay, and had a thickness of 7.5 m. After drilling fluid backflow, the reservoir became clogged, and the well skin coefficient was measured to be 4.8. The method for automatically and rapidly generating a drilling, completion, and unclogging solution according to this invention is described below: (1) Retrieve basic parameters of oil wells and oil reservoirs from the drilling database. Average permeability 1670 mD, crude oil viscosity 7460 mPa·s, salinity 53000 mg / L, Ca 2+ +Mg 2+The content is 821 mg / L, the clay content is 18%, and the well skin coefficient is 4.8.

[0056] (2) Based on the basic parameters, the classification judgment model is used to determine the classification type as condition C1, and the blockage type is defined as inorganic scale blockage and solid particulate blockage, and the corresponding blockage coefficient K=1 is output.

[0057] (3) Call the sand prevention and unblocking sequence optimization rule: for carbonate reservoirs, adopt the method of sand prevention first and then unblocking to prevent well wall collapse.

[0058] (4) The composite unblocking system is matched with the composite acid system. The composite acid system is composed of hydrochloric acid, hydrofluoric acid and phytic acid in a mass ratio of 1:1:1, which can remove inorganic scale blockage and solid particulate blockage.

[0059] (5) Determination of the injection process for the bio-enzyme composite unblocking system The injection volume of the composite unblocking system is calculated by a formula. Because it meets conditions C1 and C3, it exhibits both inorganic scale blockage and solid particulate blockage, with a contamination coefficient α of 1.2 and a treatment radius r1 of 2 m. The reservoir thickness is 7.5 m, and the porosity is 31%. The contamination coefficient and treatment radius are defined as in Example 1.

[0060] Calculate the injection volume of the composite acid unblocking system:

[0061] =1.2×3.14×2 2 ×7.5×0.31 =35m 3 The concentration of the compound acid used in the bio-enzyme composite unblocking system is 4000 ppm, with an indoor catalytic degradation rate of 96% and a permeability recovery rate of 83%.

[0062] (6) On-site application and effect tracking analysis For on-site application, first inject 35m of the compound acid system. 3 Displaced 10m of formation water 3 The sample was soaked for 6 hours and then drained. The skin coefficient after treatment was measured to be 0.15. The well was then put into production with a fluid volume of 26 t / d and an oil volume of 12 t / d, resulting in an input-output ratio of 1:17.

[0063] Example 6 A certain block in Shengli Oilfield belongs to a sandstone reservoir. Well LF is a vertical well with a reservoir temperature of 69℃ and geological reserves of 4.7×10⁻⁶. 5 t, porosity 30.4%, pressure 11.5 MPa, average permeability 780 mD, crude oil viscosity 350 mPa·s, salinity 75000 mg / L, Ca 2+ +Mg 2+The reservoir contained 660 mg / L of minerals, 11% clay, and had a thickness of 15 m and a rock cementation index of 0.82. After drilling fluid backflow, the reservoir became clogged, and the well skin coefficient was measured to be 3.7. The method for automatically and rapidly generating a drilling, completion, and unclogging solution according to this invention is described below: (1) Retrieve basic parameters of oil wells and oil reservoirs from the drilling database. Average permeability 780 mD, crude oil viscosity 350 mPa·s, salinity 75000 mg / L, Ca 2+ +Mg 2+ The content is 660 mg / L, the clay content is 11%, and the well skin coefficient is 3.7. (2) Based on the basic parameters, the classification judgment model is used to determine the classification type as conditions C1, C2 and C3, and the blockage type is defined as inorganic scale blockage, organic macromolecule blockage and crude oil mixture blockage, and the corresponding blockage coefficient K=3 is output.

[0064] (3) Call the sand control and unblocking sequence optimization rule: Sandstone reservoir, rock cementation index 0.82, adopt the method of unblocking first and then sand control.

[0065] (4) The composite unblocking system is matched with a composite acid system, a bio-enzyme system and a biosurfactant system. The composite acid system is composed of sulfonic acid and sulfinic acid in a mass ratio of 1:1, which removes inorganic scale blockage; the bio-enzyme system is composed of amylase and cellulase in a mass ratio of 3:1, which removes organic macromolecular blockage; the biosurfactant system is composed of lipopeptides and rhamnolipids in a mass ratio of 1:1, which demulsifies crude oil and removes blockage of crude oil mixtures.

[0066] (5) Determination of injection process for composite unblocking system The injection volume of the composite unblocking system is calculated by a formula. Because it meets conditions C1, C2, and C3, it involves inorganic scale blockage, organic macromolecular blockage, and composite blockage of crude oil mixtures. The contamination coefficient α is 1.1, and the treatment radius r1 is 1m; the contamination coefficient β is 1.3, and the treatment radius r2 is 1.2m; the contamination coefficient for crude oil mixture blockage is... e The value is 1, and the treatment radius r3 is 1.5m. The reservoir thickness is 15m, the porosity is 30.4%, and the contamination factor and treatment radius are defined as in Example 1.

[0067] Calculate the injection volume of the composite acid unblocking system:

[0068] =1.1×3.14×1 2 ×15×0.304 =15.8m 3 Calculate the injection volume of the biological enzyme system:

[0069] =1.3 × 3.14 × 1.2 2 ×15×0.304 =26.8m 3 Calculate the injection volume of the biosurfactant unblocking system:

[0070] =1×3.14×1.5 2 ×15×0.304 =32.2m 3 The bio-enzyme composite unblocking system uses a composite acid concentration of 2000 ppm, a bio-enzyme concentration of 1000 ppm, and a biosurfactant concentration of 3000 ppm. The indoor catalytic degradation rate is 97%, and the permeability recovery rate is 85%.

[0071] (6) On-site application and effect tracking analysis In the field application, the biosurfactant system was first injected into a 32.2m³ container. 3 Displaced 10m of formation water 3 Soak for 30 hours without backflushing; then inject 26.8 ml of the bio-enzyme system. 3 Displaced 10m of formation water 3 After soaking for 24 hours, the solution was drained; finally, a 15.8m³ compound acid system was injected. 3 Displaced 10m of formation water 3 After soaking for 8 hours, the solution was backflowed. The skin coefficient after treatment was measured to be 0.05. Then, the oil well was started for production, with a fluid volume of 43t / d and an oil volume of 28t / d, resulting in an input-output ratio of 1:20.

[0072] Example 7 A certain block in Shengli Oilfield belongs to a sandstone reservoir. Well LG is an inclined well with a reservoir temperature of 80℃ and geological reserves of 6.4×10⁻⁶. 5 t, porosity 31.4%, pressure 11 MPa, average permeability 80 mD, crude oil viscosity 50 mPa·s, salinity 12000 mg / L, Ca 2+ +Mg 2+ The reservoir contained 276 mg / L of minerals, 8% clay, and had a thickness of 6 m and a rock cementation index of 0.92. After drilling fluid backflow, the reservoir became clogged, and the well skin coefficient was measured to be 3.8. The method for automatically and rapidly generating a drilling, completion, and unclogging solution according to this invention involves the following steps: (1) Determine the type of blockage based on well parameters Average permeability 80 mD, crude oil viscosity 50 mPa·s, salinity 12000 mg / L, Ca 2+ +Mg2+ The content is 276 mg / L, the clay content is 8%, and the oil well skin coefficient is 3.8; (2) Based on the basic parameters, the classification judgment model is used to determine the classification type as condition C3, and the well blockage type is defined as crude oil mixture blockage, and the corresponding blockage coefficient K=1 is output.

[0073] (3) Call the sand control and unblocking sequence optimization rule: Sandstone reservoir, rock cementation index 0.92, adopt the method of unblocking first and then sand control.

[0074] (4) The composite unblocking system is matched with the biosurfactant system. The biosurfactant system is composed of rhamnolipids, which demulsifies the crude oil and removes the blockage of the crude oil mixture.

[0075] (5) Determination of injection process for composite unblocking system The injection volume of the composite unblocking system is calculated by a formula. Because it meets condition C1, there is a composite blockage caused by a crude oil mixture. The crude oil mixture blockage pollution coefficient... e The contamination factor is 1.2, and the treatment radius r3 is 2m. The reservoir thickness is 6m, the porosity is 31.4%, and the contamination factor and treatment radius are defined as in Example 1.

[0076] Calculate the injection volume of the biosurfactant unblocking system:

[0077] =1.2×3.14×2 2 ×6×0.314 =28.4m 3 The biosurfactant was used at a concentration of 3000 ppm on-site, with an indoor catalytic degradation rate of 96% and a permeability recovery rate of 87%.

[0078] (6) On-site application and effect tracking analysis In the field application, the biosurfactant system was first injected in a volume of 28.4 m³. 3 Displaced 10m of formation water 3 Soaking for 48 hours does not require backflow. The skin coefficient after treatment was measured to be 0.1. Then, the oil well was started for production, with a fluid volume of 15t / d and an oil volume of 9t / d, resulting in an input-output ratio of 1:17.

[0079] Example 8 A certain block in Shengli Oilfield belongs to a sandstone reservoir. Well LH is a vertical well with a reservoir temperature of 69℃ and geological reserves of 4.7×10⁻⁶. 5 t, porosity 30.4%, pressure 11.5 MPa, average permeability 350 mD, crude oil viscosity 610 mPa·s, salinity 8000 mg / L, Ca 2+ +Mg 2+The reservoir contained 180 mg / L of minerals, 15% clay, and had a thickness of 2.4 m and a rock cementation index of 0.86. After drilling fluid backflow, the reservoir became clogged, and the well skin coefficient was measured to be 2.7. The method for automatically and rapidly generating a drilling, completion, and unclogging solution according to this invention is described below: (1) Retrieve basic parameters of oil wells and oil reservoirs from the drilling database. Average permeability 350 mD, crude oil viscosity 610 mPa·s, salinity 8000 mg / L, Ca 2+ +Mg 2+ The content is 180 mg / L, the clay content is 15%, the reservoir thickness is 2.4 m, and the well skin coefficient is 2.7.

[0080] (2) Based on the basic parameters, the classification judgment model is used to determine the classification type as conditions C2 and C3, and the blockage type is defined as organic macromolecule blockage and crude oil mixture blockage, and the corresponding blockage coefficient K=2 is output.

[0081] (3) Call the sand control and unblocking sequence optimization rule: Sandstone reservoir, rock cementation index 0.86, adopt the method of unblocking first and then sand control.

[0082] (4) The composite unblocking system is matched with the bio-enzyme system and the bio-surfactant system. The bio-enzyme system consists of cellulase and β-glucanase in a mass ratio of 1:1, which removes the blockage of organic macromolecules; the bio-surfactant system consists of rhamnolipid and sophorolipid in a 1:1 ratio, which demulsifies the crude oil and removes the blockage of the crude oil mixture.

[0083] (5) Determination of injection process for composite unblocking system The injection volume of the composite unblocking system is calculated by a formula. Because it meets conditions C2 and C3, it involves both organic macromolecular blockage and crude oil mixture blockage, with a contamination coefficient β of 1.5 and a treatment radius r2 of 2m. The contamination coefficient for crude oil mixture blockage is... e The concentration factor is 1.3, and the treatment radius r3 is 2m. The reservoir thickness is 2.4m, the porosity is 30.4%, and the contamination factor and treatment radius are defined as in Example 1.

[0084] Calculate the injection volume of the biological enzyme system:

[0085] =1.5×3.14×2 2 ×2.4×0.304 =13.7m 3 Calculate the injection volume of the biosurfactant unblocking system:

[0086] =1.3×3.14×2 2×2.4×0.304 =11.9m 3 The bio-enzyme composite unblocking system uses a bio-enzyme concentration of 2000 ppm and a biosurfactant concentration of 3000 ppm on-site. The indoor catalytic degradation rate is 97%, and the permeability recovery rate is 88%.

[0087] (6) On-site application and effect tracking analysis In the field application, the biosurfactant system was first injected in a volume of 11.9 m. 3 Displaced 10m of formation water 3 Soak for 24 hours without backflushing; then inject 13.7 ml of the bio-enzyme system. 3 Displaced 10m of formation water 3 After soaking for 24 hours, the water was drained back into the well. The skin coefficient after treatment was measured to be 0.15. Then the well was put into production with a fluid volume of 20t / d and an oil volume of 16t / d, resulting in an input-output ratio of 1:19.

[0088] Comparative Example 1 Well type: LM well (sandstone reservoir, vertical well); Formation temperature: 72 ℃; Formation pressure: 10.8 MPa; Porosity: 30.1%; Average permeability: 520 mD; Crude oil viscosity: 680 mPa·s; Mineralization: 43000 mg / L; Ca 2+ +Mg 2+ 590 mg / L; clay content: 10%; reservoir thickness: 5.0 m; rock cementation index: 0.80; initial skin index: 4.1.

[0089] According to the determination rules of this invention, this well should be judged as: C1 (mineralization ≥ 20000 mg / L or Ca 2+ +Mg 2+ (≥500mg / L) is valid; C2 (penetration rate 100–1000 mD) holds true; C3 (crude oil viscosity 500–5000 mPa·s) holds true; Therefore, K=3 (complex blockage: inorganic scale + organic macromolecules + crude oil mixture).

[0090] In actual field conditions, no multi-condition judgments or K-value outputs were performed: field experience determined that "inorganic scale was the main component," ignoring organic / emulsification factors.

[0091] System mapping and sequence optimization were not employed: direct acidification was performed first, and no biological enzymes or surfactants were prepared.

[0092] Quantitative injection not within the prescribed range: The composite acid was injected quantitatively based on experience: The composite acid system consists of hydrochloric acid and sulfinic acid in a mass ratio of 1:1, with an injection volume of 24 m³. According to the formula Q=π·r²·h·φ, r=1.0 m (both lower than the recommended lower limit for C1 / C2 / C3 in this invention), the effective concentration of the working solution is 1000 ppm (lower than the range of this invention).

[0093] The sandstone sequence rule was not followed: The cementation index of this well is 0.80, and it should be "unblocking first and then sand control", but the ratio is still "acid first, without sand control".

[0094] Construction and monitoring: Inject 24m³ of compound acid in one go → shut in the well for 6 hours → backflow.

[0095] Result: Epidermal coefficient after treatment: 1.9 (>0.5, not meeting the success criterion).

[0096] The penetration rate recovery rate is approximately 58%; the criteria for successful unblocking are not met, and the unblocking attempt has failed.

[0097] Comparative Example 2 LM well, sandstone reservoir, vertical well; formation temperature 68℃; porosity 30.0%; average permeability 620 mD; crude oil viscosity 980 mPa·s; salinity 18000 mg / L, Ca 2+ +Mg 2+ 420 mg / L; mud content 14%; effective thickness h = 4.5 m; initial skin coefficient S = 3.9; rock cementation index 0.86 (unblocking first, then sand control). According to the present invention, it meets C2 (100–1000 mD) and C3 (500–5000 mPa·s), K = 2, and is a composite blockage of "organic macromolecules + crude oil mixture".

[0098] System selection: Biological enzyme system: amylase:mannanase = 1:1; Biosurfactant system: lipopeptides; Injection sequence: surfactant → bioenzyme, on-site concentration of the agent (3000ppm for biosurfactant system, 2000ppm for bioenzyme system).

[0099] The injection volume calculated from this (Q=π·r²·h·φ) is: According to this invention, the content should be: bioenzyme Q2 = 13.36 m³ (β = 1.4, r2 = 1.5 m); surfactant Q3 = 15.12 m³ (ε = 1.1, r3 = 1.8 m); total 28.48 m³.

[0100] The actual amount used in this comparative example was: bio-enzyme Q2′=9.54m³; surfactant Q3′=9.54m³; totaling 19.08m³, which is only 67% of the amount used in this invention.

[0101] On-site execution and results: First, inject surfactant and soak for 24 hours; then inject bio-enzyme, soak for 12 hours, and then return to the source.

[0102] Results: The skin coefficient decreased from 3.9 to 1.2, and the pressure drop curve showed that the outer edge of the near-wellbore zone was still a high-resistivity zone; the permeability recovery rate of the differential pressure recovery test was ≈55%, which did not meet the criteria for successful unblocking, and the unblocking failed.

[0103] The above description is only a preferred embodiment of the present invention and is not intended to limit the present invention. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of the present invention should be included within the protection scope of the present invention.

Claims

1. A method for automatically and quickly generating a drilling and completion biological enzymatic plugging solution, comprising the following steps: S1: retrieving basic parameters of oil wells and oil layers from a drilling database; S2: determining a classification type based on the basic parameters using a classification determination model and outputting a corresponding plugging coefficient K; S3: calling sand control and plugging removal sequence optimization rules, calling a plugging removal composite system matched with the classification type, an injection amount calculation formula, and an injection sequence rule to generate an injection scheme including the plugging removal composite system, injection amounts of each system, and an injection sequence; S4: implementing the injection scheme and verifying the implementation results.

2. The method for automatic and rapid generation of a drilling and completion biogenic enzymatic plug solution according to claim 1, characterized in that, The basic parameters are derived from basic parameters of oil wells and oil layers in a data parameter library collected from oil wells, and at least include oil well permeability, salinity, shale content, crude oil viscosity, horizontal well section length or straight and inclined well perforated section thickness, porosity, and reservoir parameters.

3. The method for automatic and rapid generation of a drilling and completion biogenic enzymatic plug solution according to claim 1, characterized in that, The classification determination model of step S2 performs multi-condition cross determination on the standardized preprocessed basic parameters according to the following rules and outputs a plugging condition type and a plugging coefficient K; Condition C1: salinity > 20 000 mg / L or (Ca 2+ + Mg 2+ ) > 500 mg / L or permeability > 1 000 mD or shaliness > 20%; Condition C2: permeability is 100-1000 mD; Condition C3: crude oil viscosity is 500-5000 mPa·s; When a condition is true, it is recorded as an effective plugging condition; the plugging coefficient K is the number of all effective plugging conditions, and the value range is 0-3; Wherein, K=0 indicates no plugging, K≥1 indicates that there is plugging, and the larger the K value, the more conditions.

4. The method for automatic and rapid generation of a drilling and completion biogenic enzymatic plug solution according to claim 3, characterized in that, Step 2 is further: When the plugging coefficient K≥1, step 3 is executed.

5. The method for automatic and rapid generation of a drilling and completion biogenic enzymatic plug solution according to claim 4, characterized in that, The reservoir parameters at least include oil layer types and rock cementation indexes, and the oil layer types at least include clastic rock reservoirs, carbonate rocks, igneous rocks, metamorphic rock reservoirs, and sandstone oil reservoirs. The sand control and plugging removal sequence optimization rules in step S3 are as follows: For clastic rock reservoirs, sand control is performed first and then plugging removal; For carbonate rock / igneous rock / metamorphic rock reservoirs, sand control is performed first and then plugging removal; For sandstone oil reservoirs, when the rock cementation index is ≤0.5, sand control is performed first and then plugging removal; 6. The method for automatic and rapid generation of a drilling and completion biogenic enzymatic plug solution according to claim 4, characterized in that, For sandstone oil reservoirs, when the rock cementation index is >0.5, plugging removal is performed first and then sand control.

7. The method for automatic and rapid generation of completion biogenic enzymatic block dissolution solutions of claim 5, wherein, The plugging removal composite system mapping relationship model includes C1 mapping composite acid plugging removal system, C2 mapping biological enzyme plugging removal system, and C3 mapping biological surfactant plugging removal system. wherein: - injection volume, m3; - pollution coefficient; - treatment radius, m; - horizontal well section length or straight and inclined well perforation section thickness, m; - porosity, %; The plugging removal system injection amount is calculated according to the following formula: When condition C1 is met: pollution coefficient 1.1-1.3, treatment radius 1-2 m; When condition C2 is met: pollution coefficient 1.3-1.6, treatment radius 1.2-2.5 m; When condition C3 is met: pollution coefficient 1.0-1.5, treatment radius 1.5-3 m; 8. The method for automatic and rapid generation of a drilling and completion biogenic enzymatic plug solution according to claim 7, characterized in that, The biological enzyme composite plugging removal system uses a composite acid concentration of 2000-4000 ppm, a biological enzyme field use concentration of 1000-3000 ppm, and a biological surfactant field use concentration of 3000-5000 ppm. The injection sequence of the composite plugging removal system in step S3 is as follows: (1) When K=1, only inject the plugging removal system corresponding to the condition, displace the formation water, soak, and flow back; (2) When K>1, follow the established order of biosurfactant system injection→biological enzyme system injection→complex acid system injection, each injection is used to displace formation water and maintain soaking, and finally flow back.

9. The method for automatic and rapid generation of a bioenzymatic solution for drilling and completion plugging according to claim 1, characterized in that, The implementation results are verified in step S4 to take skin factor after oil well plugging removal as a determination index: (1) When skin factor ≤0.5, it is determined that plugging removal is successful and normal production is converted; (2) When skin factor >0.5, the construction site process check reason is called and checked.

10. A system for automatically and quickly generating a drilling and completion biogenic enzymatic plug solution, characterized in that, It includes: An oil well parameter acquisition module for acquiring oil well basic parameters after drilling and completion; A plugging type determination module for determining the plugging type based on the oil well related parameters; A plugging removal system matching module for matching a corresponding complex plugging removal system according to the plugging type; A process path generation module for generating a corresponding injection sequence and dosage scheme according to the matched plugging removal system; An effect feedback module for collecting wellbore response data during and after plugging removal and evaluating the plugging removal effect.

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