Pipe network operation mode and transformation analysis method and device based on detection and evaluation

Abstract

According to the pipe network operation mode and transformation method and device based on detection and evaluation, key reasons are searched for based on historical pipe network accidents, and main risks causing pipe network leakage or accidents are clarified; classifying the risk generality and personality features based on the pipeline laying position, and constructing scientific evaluation models of different risk categories; based on factors such as pipe network characteristics, service environment and risk characteristics, an evaluation unit is scientifically delimited, and pipe network risk evaluation is carried out; a pipe network risk evaluation result is linked with differentiated operation and maintenance and transformation, and efficient classification and level-to-level management and prevention and control are achieved.

Description

Technical Field

[0001] The present invention relates to the technical field of risk assessment and transformation of urban gas pipeline networks, and in particular to a pipeline network operation mode and transformation method and device based on detection and evaluation. Background Art

[0002] With the continuous construction of urban gas pipelines in my country, many gas pipelines have been in service for a long time. Since urban gas pipelines are usually close to densely populated areas, assessing the risks of gas pipelines and transforming them is an important part of the safe operation of urban gas. At present, the risk assessment methods of gas pipelines are mainly divided into qualitative risk assessment methods, semi-quantitative risk assessment methods and quantitative risk assessment methods. Qualitative risk assessment methods commonly used include safety checklist method, expert on-site inquiry and observation method, and pre-hazard analysis, which are intuitive and simple, easy to master and operate; semi-quantitative risk assessment methods are between qualitative and quantitative risk assessments, mainly including LEC method, six-stage method, neural network evaluation method, etc., which are usually used in production process flow; quantitative risk assessment methods can quantitatively evaluate system risks, mainly including fault tree, event tree and probabilistic hazard assessment method.

[0003] Therefore, there are many gas pipeline network risk assessment methods in the existing technology, but considering the pipeline network characteristics, urban characteristics, service environment, risk category, evaluation method and other factors, the applicability and application value of existing evaluation methods and prevention and control technologies in urban gas pipeline networks need to be further explored, and the connection between risk assessment and operation mode and transformation method needs in-depth research.

[0004] In addition, through statistical analysis of the number of underground pipeline leakage incidents in the past five years, leakage incidents are concentrated in medium and low pressure pipelines, and the number of leakage incidents has a certain growth trend. From the perspective of corrosion, equipment failure, construction and installation, third-party construction damage and other dimensions, the proportion of leakage incidents caused by corrosion each year is greater than 75%, and the corrosion risk has a tendency to increase year by year. In addition, in terms of third-party construction damage, due to the increase in the number of construction in recent years, the number of leakage incidents caused by this has a certain growth trend. Therefore, based on the above background, in order to alleviate the operation and transformation pressure brought about by the leakage of medium and low pressure pipelines in urban gas, it is necessary to more scientifically establish a pipeline operation mode and transformation method and device based on detection and evaluation to achieve efficient classification and grading management and prevention and control. Summary of the invention

[0005] The present invention aims to provide a method and device for analyzing the operation mode and transformation of a pipe network based on detection and evaluation, which overcomes the above-mentioned problems or at least partially solves the above-mentioned problems.

[0006] To achieve the above object, the technical solution of the present invention is specifically implemented as follows:

[0007] One aspect of the present invention provides a method for analyzing a pipe network operation mode and transformation based on detection and evaluation, comprising:

[0008] Determine the corrosion risk level of the detection point to obtain the corrosion risk level of the detection point;

[0009] Determine the pipeline main body condition at the detection point to obtain the pipeline main body condition;

[0010] Performing pipeline leakage determination on the adjacent pipelines of the detection point to obtain pipeline leakage conditions;

[0011] Make environmental structural corrections to the pipe network area and revise the leakage risk assessment results;

[0012] Determine the third-party construction damage risk and obtain the third-party construction damage risk level;

[0013] Establishing a leakage risk differentiation operation model and a construction damage risk differentiation operation model, and using the leakage risk differentiation operation model and the construction damage risk differentiation operation model to perform risk classification on the grid units respectively;

[0014] Develop differentiated operation modes and pipeline network transformation technologies based on risk assessment.

[0015] Optionally, determining the corrosion risk level of the detection point to obtain the corrosion risk level of the detection point includes:

[0016] Determine whether there is a corrosion rate test piece;

[0017] If the corrosion rate test piece is available, the corrosion rate is obtained according to the corrosion rate test piece, and the corrosion risk level is determined according to the corrosion rate;

[0018] If there is no corrosion rate test piece, determine whether there is cathodic protection;

[0019] If there is no cathodic protection, the pipe-to-ground potential and the ratio of the pipe-to-ground potential forward offset to the soil resistivity are obtained, and the corrosion risk level is determined according to the pipe-to-ground potential and the ratio of the pipe-to-ground potential forward offset to the soil resistivity;

[0020] If there is cathodic protection, determine whether there is stray current interference. If there is no stray current interference, determine the corrosion risk level according to the power-off potential; if there is stray current interference, determine the corrosion risk level according to the DC interference and AC interference respectively.

[0021] Optionally, the determining the corrosion risk level according to the DC interference and the AC interference respectively includes:

[0022] If there is DC interference, the corrosion risk level is determined according to the time proportion that the pipeline polarization potential is positively offset from the preset value;

[0023] If AC interference exists, the corrosion risk level is determined based on the AC corrosion current density and the cathodic protection polarization potential.

[0024] Optionally, determining the pipeline body condition at the detection point to obtain the pipeline body condition includes:

[0025] The condition of the pipeline body is determined according to the service time, pipe diameter and pipeline type of the pipeline to obtain the condition of the pipeline body.

[0026] Optionally, performing pipeline leakage determination on a pipeline adjacent to the detection point to obtain the pipeline leakage situation includes:

[0027] Based on the service environment of the adjacent pipelines of the detection point, pipeline construction time, cathodic protection measures and interference conditions, the leakage conditions of the pipeline of a preset length within a preset time range are obtained.

[0028] Optionally, the environmental structure correction of the pipe network area and the correction of the leakage risk assessment result include:

[0029] Based on the downstream user situation of the pipeline network area, the infrastructure and personnel situation near the pipeline network, the correction is made on the basis of the corrosion risk level and the pipeline leakage situation.

[0030] Optionally, the grading of the third-party construction damage risk to obtain the third-party construction damage risk level includes:

[0031] The third-party construction damage risk is determined based on the entity risk, construction risk, management risk and environmental risk to obtain the third-party construction damage risk level.

[0032] Optionally, the method further includes: formulating a suspected leakage point review model based on risk assessment.

[0033] Optionally, the formulation of a suspected leakage point review mode based on risk assessment includes:

[0034] According to the leakage risk level, differentiated review strategies and operation modes are formulated.

[0035] Another aspect of the present invention provides a pipeline operation mode and transformation analysis device based on detection and evaluation, which adopts the above-mentioned pipeline operation mode and transformation analysis method based on detection and evaluation to formulate differentiated operation modes and pipeline transformation technologies based on risk assessment.

[0036] It can be seen that through the pipeline operation mode and transformation analysis method and device based on detection and evaluation provided by the present invention, based on historical pipeline accidents, the key causes are found and the main risks leading to pipeline leakage or accidents are clarified; the common and individual characteristics of risks are classified based on the pipeline laying location, and a scientific evaluation model for different risk categories is constructed; based on factors such as pipeline characteristics, service environment, and risk characteristics, the assessment units are scientifically delineated and pipeline risk evaluation is performed; the pipeline risk evaluation results are connected with differentiated operation and maintenance and transformation to achieve efficient classification and grading management and prevention and control. BRIEF DESCRIPTION OF THE DRAWINGS

[0037] In order to more clearly illustrate the technical solutions of the embodiments of the present invention, the accompanying drawings required for use in the description of the embodiments will be briefly introduced below. Obviously, the accompanying drawings described below are only some embodiments of the present invention. For ordinary technicians in this field, other accompanying drawings can be obtained based on these accompanying drawings without paying creative work.

[0038] Figure 1 A flow chart of a pipeline network operation mode and transformation analysis method based on detection and evaluation provided in an embodiment of the present invention;

[0039] Figure 2 A corrosion risk level evaluation diagram provided by an embodiment of the present invention;

[0040] Figure 3 A schematic diagram of pipeline body condition determination provided by an embodiment of the present invention;

[0041] Figure 4 A schematic diagram of differentiated technical transformation selection principles provided for an embodiment of the present invention;

[0042] Figure 5 A schematic diagram of the structure of a pipe network operation mode and transformation analysis device based on detection and evaluation provided in an embodiment of the present invention. DETAILED DESCRIPTION

[0043] The exemplary embodiments of the present disclosure will be described in more detail below with reference to the accompanying drawings. Although the exemplary embodiments of the present disclosure are shown in the accompanying drawings, it should be understood that the present disclosure can be implemented in various forms and should not be limited by the embodiments set forth herein. On the contrary, these embodiments are provided to enable a more thorough understanding of the present disclosure and to fully convey the scope of the present disclosure to those skilled in the art.

[0044] Based on the leakage risk composition, the present invention formulates risk level (low, medium, high) determination methods for corrosion risk, pipeline body condition, and adjacent pipeline leakage respectively.

[0045] Specifically, the leakage risk of the present invention is a weighted combination of corrosion risk, pipeline condition and leakage condition. In specific implementation, the leakage risk is obtained by taking the average of the evaluation results of multiple detection points in the unit. In principle, it is recommended that the number of detection points in each evaluation unit should be no less than 2 / km. The corrosion leakage risk evaluation of a single detection point is calculated by the corrosion risk, pipeline condition, and leakage of the nearby 1km pipeline in the past three years, and the environmental structure risk is superimposed for correction. The reason for the above setting is that the corrosion risk represents the corrosion rate to a certain extent, the pipeline condition can estimate the remaining wall thickness, and the adjacent leakage condition represents the previous risk level. Quantitatively calculating the corrosion leakage risk by assigning values ​​will provide an important basis for subsequent differentiated operation and maintenance and transformation. The specific assignments are shown in Table 1:

[0046] Table 1 Leakage risk assignment table

[0047]

[0048] The weight of corrosion risk is set to 0.5, the weight of pipeline condition is set to 0.3, the weight of adjacent pipeline leakage is set to 0.2, and the environmental structure correction threshold is set to no more than 20. The leakage risk score L = 0.5*corrosion risk score + 0.3*construction score + 0.2*leakage score + environmental structure correction value. The corresponding risk levels are shown in Table 2, where the levels shown in Table 2 correspond to differentiated operation and maintenance and transformation options.

[0049] Table 2 Leakage risk classification table

[0050] Leakage risk level Leakage risk score L Leakage risk level V <20 Low risk IV 20≤L<40 Low to medium risk III 40≤L<60 Medium risk II 60≤L<80 Medium to high risk I ≥80 High risk

[0051] Figure 1 A flow chart showing a pipeline network operation mode and transformation analysis method based on detection and evaluation provided by an embodiment of the present invention is shown in FIG. Figure 1 The pipe network operation mode and transformation analysis method based on detection and evaluation provided in the embodiment of the present invention includes:

[0052] S1, determining the corrosion risk level of a detection point to obtain the corrosion risk level of the detection point.

[0053] Specifically, the risk assessment of the medium and low pressure pipeline network of urban gas in the present invention needs to be further split and refined in combination with the existing daily operation grid, and the division principle of the risk assessment unit is formulated. The risk management is refined through the division of the assessment unit, while ensuring that the risk conditions of the pipelines in a single risk assessment unit are as close as possible.

[0054] Taking the medium and low pressure pipeline network as an example, the electrical connectivity of the pipeline is prioritized as one of the division principles, that is, the location of some insulating joints and steel-plastic conversion joints is used as the dividing point of different evaluation units; secondly, based on the geographical location such as pipeline direction distribution and gas supply area distribution, adjacent pipelines are classified into the same evaluation unit.

[0055] Combined with the characteristics of urban gas pipeline networks, medium and low pressure pipeline networks can be divided into courtyard community pipelines and urban road pipelines. Based on the above division principles, the following division methods are formulated after comprehensive consideration: First, courtyard community pipelines, with residential areas and unit users as the minimum evaluation units; second, urban road pipelines, with the same pressure material, similar service time, insulation joint boundaries, the same project or road, and between two branch pipelines as the evaluation unit division boundaries. At the same time, in order to ensure the scientific nature of the evaluation unit and the rationality of management and control, the total length of the pipeline of an evaluation unit is controlled at about 5km.

[0056] As an optional implementation manner of the embodiment of the present invention, determining the corrosion risk level of the detection point to obtain the corrosion risk level of the detection point includes:

[0057] Determine whether there is a corrosion rate test piece;

[0058] If the corrosion rate test piece is available, the corrosion rate is obtained according to the corrosion rate test piece, and the corrosion risk level is determined according to the corrosion rate;

[0059] If there is no corrosion rate test piece, determine whether there is cathodic protection;

[0060] If there is no cathodic protection, the pipe-to-ground potential and the ratio of the pipe-to-ground potential forward offset to the soil resistivity are obtained, and the corrosion risk level is determined according to the pipe-to-ground potential and the ratio of the pipe-to-ground potential forward offset to the soil resistivity;

[0061] If there is cathodic protection, determine whether there is stray current interference. If there is no stray current interference, determine the corrosion risk level according to the power-off potential; if there is stray current interference, determine the corrosion risk level according to the DC interference and AC interference respectively.

[0062] Wherein, determining the corrosion risk level according to the DC interference and the AC interference respectively includes:

[0063] If there is DC interference, the corrosion risk level is determined according to the time proportion that the pipeline polarization potential is positively offset from the preset value;

[0064] If AC interference exists, the corrosion risk level is determined based on the AC corrosion current density and the cathodic protection polarization potential.

[0065] Specifically, the corrosion risk level evaluation of the present invention is as follows: Figure 2 As shown in the figure, it is an assessment of the corrosion rate of a test point of a service pipeline. Therefore, the priority is whether the test point has a corrosion rate test piece, followed by the cathodic protection situation, and finally the stray current situation. Finally, the corrosion risk level of the test point is obtained and assigned according to Table 1.

[0066] S2, determining the pipeline main body condition at the detection point to obtain the pipeline main body condition.

[0067] As an optional implementation manner of the embodiment of the present invention, the determining the condition of the pipeline body at the detection point to obtain the pipeline body condition includes: determining the condition of the pipeline body according to the service time, pipe diameter and pipeline type of the pipeline to obtain the pipeline body condition.

[0068] Specifically, the pipeline body condition is determined, such as Figure 3 As shown in the figure, it is an assessment of the remaining wall thickness of the pipeline. Therefore, the design wall thickness of the pipeline and the historical thinning amount are mainly considered. Based on this, the pipe diameter, pressure level system and service time are taken as key factors. For the pipe diameter, by statistically analyzing the relationship between pipe diameter and leakage in recent years, it is found that nearly 70% of leakage incidents occur below the pipe diameter DN200. One of the reasons is that the pipe diameter decreases with the decrease of the design wall thickness. For the pressure level system, low pressure is mostly courtyard community pipelines, and the cathodic protection coverage rate is low compared with medium pressure, and the corrosion risk is high. For the service time, CJJ95 "Technical Code for Corrosion Control of Buried Steel Pipelines of Urban Gas" pointed out in 2003 that "low-pressure pipelines with a nominal diameter greater than or equal to 200mm must adopt a corrosion control system with an anti-corrosion layer supplemented by cathodic protection". After being revised in 2013, it stipulates that "new pipelines should adopt a corrosion control system with an anti-corrosion layer supplemented by cathodic protection", which improves the corrosion control requirements for pipelines with a diameter less than 200mm. Therefore, the service time of 10 years and 20 years can be used as the judgment threshold. Finally, the situation of the pipeline body at this location is obtained and the value is assigned according to Table 1.

[0069] S3, performing pipeline leakage determination on the adjacent pipelines of the detection point to obtain pipeline leakage conditions.

[0070] As an optional implementation manner of an embodiment of the present invention, the pipeline leakage judgment is performed on the adjacent pipeline of the detection point to obtain the pipeline leakage situation, including: based on the service environment of the adjacent pipeline of the detection point, the pipeline construction time, cathodic protection measures and interference conditions, obtaining the leakage situation of the pipeline of a preset length within a preset time range.

[0071] Specifically, based on the similar service environment of the adjacent pipelines of the detection point, the similar construction time of the pipelines, the small difference in cathodic protection measures, and the basically similar interference conditions, the leakage of the pipelines within 1 km in the past three years can represent the degree of leakage risk in the past to a certain extent. Finally, the values ​​are assigned according to Table 1 based on the statistical results.

[0072] S4, make environmental structure corrections to the pipeline network area and revise the leakage risk assessment results.

[0073] As an optional implementation of an embodiment of the present invention, the environmental structure correction of the pipeline area and the correction of the leakage risk assessment result include: based on the downstream user conditions corresponding to the pipeline area, the infrastructure and personnel conditions adjacent to the pipeline, the correction is made on the basis of the corrosion risk level and the pipeline leakage situation.

[0074] Specifically, based on the downstream user conditions corresponding to the area where the pipeline is located, and the infrastructure and personnel conditions adjacent to the pipeline, further corrections are needed based on the above-mentioned leakage risks to reasonably upgrade the level of risk assessment results.

[0075] Table 3 Environment structure assignment table

[0076]

[0077]

[0078] S5, determining the third-party construction damage risk and obtaining the third-party construction damage risk level.

[0079] As an optional implementation manner of an embodiment of the present invention, the grading of the third-party construction damage risk to obtain the third-party construction damage risk level includes: determining the third-party construction damage risk according to the entity risk, construction risk, management risk and environmental risk to obtain the third-party construction damage risk level.

[0080] Specifically, the risk of third-party construction damage to gas pipelines is mainly determined by entity risk, construction risk, management risk and environmental risk, among which environmental risk is a deduction item. The higher the sum of the above four risk scores, the lower the third-party damage risk level. Quantitatively calculating the third-party construction damage risk by assigning values ​​will provide an important basis for subsequent differentiated operation and maintenance. The specific assignments are shown in Table 3.

[0081] Table 4 Third-party construction damage risk assignment table

[0082]

[0083] S6, establishing a leakage risk differentiation operation model and a construction damage risk differentiation operation model, and using the leakage risk differentiation operation model and the construction damage risk differentiation operation model to perform risk classification on the grid units.

[0084] Specifically, based on the characteristics of urban gas, two key prevention and control targets, leakage risk and third-party construction damage risk, were identified, and risk classification for grid units was achieved based on their respective risk assessment models; the ultimate goal is to complete the classification and grading of risks, that is, differentiated operation modes and pipeline network transformation technologies based on risk assessment. Through differentiated operation modes, pipeline network risk control is more refined, hidden danger inspection is more timely, and operation and maintenance are more economical; through differentiated pipeline network transformation, the transformation area is more reasonable and the transformation method is more scientific.

[0085] The current pipeline inspection and testing mode is single, and no differentiated operating rules are formulated based on risk assessment results, lacking the pertinence of pipeline risk investigation. Currently, daily inspections are conducted twice a week, trolley leakage detection is conducted twice a year, and high-precision leakage detection is conducted nine times a year. Based on the leakage risk level and the third-party construction damage risk level, the existing operation mode needs to be further optimized. The adjustment principle is to increase the inspection and testing of high-risk levels, appropriately reduce the inspection and testing of low-risk levels, and improve the efficiency of pipeline operation and maintenance and the timeliness of discovering hidden dangers. The specific operation modes are shown in Tables 5 and 6.

[0086] Table 5 Leakage risk differentiation operation model

[0087]

[0088] Table 6 Differentiated operation modes of construction damage risk

[0089] Construction damage risk level Operation Mode I ≥1 time / day II ≥ 2 times / week III ≥1 time / two weeks

[0090] S7. Develop differentiated operation modes and pipeline network transformation technologies based on risk assessment.

[0091] As an optional implementation of the embodiment of the present invention, the pipe network operation mode and transformation analysis method based on detection and evaluation provided by the embodiment of the present invention also includes: formulating a suspected leakage point review mode based on risk assessment. Wherein, the formulating of the suspected leakage point review mode based on risk assessment includes: formulating differentiated review strategies and operation modes according to the leakage risk level.

[0092] At present, most urban gas pipeline leak detection relies on high-precision leak detection vehicles. Through detection, a list of suspected leak points is formed, and then manual review is performed on the suspected leak points. The manual review method is mainly to use handheld gas detection equipment to detect suspected leak points. However, due to the high detection accuracy of vehicle-mounted equipment, there will be relatively more interference sources in the environment. The number of suspected leak points reported by vehicle-mounted leak detection equipment is at least 2-3 times more than that of traditional methods. There will also be some false alarm information, which increases the amount of manual review and capital investment. In view of the problem of a large number of suspected leak points given by vehicle-mounted leak detection equipment, the suspected leak points are graded according to the leakage risk level, which reduces the workload of manual review.

[0093] The suspected leakage points generated by the high-precision leak detection vehicle are mapped to the corresponding evaluation units. Differentiated review strategies and operation modes are formulated according to the leakage risk level of the evaluation unit, as shown in Table 6.

[0094] Table 7 Suspected Leakage Point Review Strategy Table

[0095]

[0096]

[0097] At present, there are two types of pipeline reconstruction technologies used in the industry: excavation reconstruction and trenchless reconstruction technology. Excavation reconstruction mainly includes continuous excavation PE pipe replacement and repair, continuous excavation impressed current cathodic protection, and local excavation sacrificial anode cathodic protection. PE pipe replacement and repair refers to excavating near the steel pipe to be reconstructed to replace the pipe in situ; supplementary cathodic protection technology refers to applying cathodic protection current to the steel pipe to be reconstructed to control or reduce the risk of leakage and extend the service life of the pipeline network.

[0098] Trenchless renovation technologies mainly include on-site PE folded lining (U-insert) method and flip lining method. The U-insert method welds and folds the independent pressure-bearing polyethylene liner pipe into a "U" or "C" shape on site and then pulls it into the in-service pipeline. The folded pipe is restored to its original shape and size through heating and pressurization. It has the advantages of short construction period and low cost. The flip lining method uses compressed air as the power, impregnates the tubular composite lining material with adhesive, flips it and pushes it into the old pipeline. After curing, it forms a lining layer that is tightly bonded to the inner wall of the pipeline. The advantage is that it has good bending ability.

[0099] Renovation principles were formulated based on the leakage risk level, as shown in Table 7. Pipelines at risk levels I and II need to be included in the renovation plan and undergo timely technical transformation, and differentiated technical transformation plans must be selected; pipelines at risk levels III and IV must strictly implement inspection and testing cycles and can continue to operate; pipelines at risk level V are at low risk and temporarily meet safety operation requirements.

[0100] Table 8 Renovation principles based on risk assessment

[0101]

[0102] It can be seen from Table 7 that when the leakage risk level (leakage risk level = 0.5*corrosion risk + 0.3*main body condition + 0.2*leakage condition + environmental structure correction value) is in I or II, it is necessary to renovate the pipeline network. Check the risk level of single corrosion and pipeline body in I or II, and Figure 4 Choose differentiated technical transformation plans.

[0103] It can be seen that through the pipeline operation mode and transformation analysis method based on detection and evaluation provided by the embodiment of the present invention, based on historical pipeline accidents, the key causes are found and the main risks leading to pipeline leakage or accidents are clarified; the common and individual characteristics of risks are classified based on the pipeline laying location, and a scientific evaluation model for different risk categories is constructed; based on factors such as pipeline characteristics, service environment, and risk characteristics, the assessment units are scientifically delineated and pipeline risk evaluation is performed; the pipeline risk evaluation results are connected with differentiated operation and maintenance and transformation to achieve efficient classification and grading management and prevention and control.

[0104] Figure 5 The schematic diagram of the structure of the pipe network operation mode and transformation analysis device based on detection and evaluation provided by an embodiment of the present invention is shown. The pipe network operation mode and transformation analysis device based on detection and evaluation applies the above method. The following is only a brief description of the structure of the pipe network operation mode and transformation analysis device based on detection and evaluation. For other matters not covered, please refer to the relevant description in the pipe network operation mode and transformation analysis method based on detection and evaluation. Figure 5 The pipeline operation mode and transformation analysis device based on detection and evaluation provided in the embodiment of the present invention adopts the above-mentioned pipeline operation mode and transformation analysis method based on detection and evaluation to formulate differentiated operation modes and pipeline transformation technologies based on risk assessment.

[0105] Specifically include:

[0106] A first determination module is used to determine the corrosion risk level of the detection point to obtain the corrosion risk level of the detection point;

[0107] The second determination module is used to determine the pipeline body condition at the detection point to obtain the pipeline body condition;

[0108] A third determination module is used to perform pipeline leakage determination on the adjacent pipelines of the detection point to obtain pipeline leakage conditions;

[0109] The correction module is used to correct the environmental structure of the pipe network area and correct the leakage risk assessment results;

[0110] The fourth determination module is used to determine the third-party construction damage risk and obtain the third-party construction damage risk level;

[0111] A classification module, used to establish a leakage risk differentiation operation model and a construction damage risk differentiation operation model, and to perform risk classification on grid units using the leakage risk differentiation operation model and the construction damage risk differentiation operation model respectively;

[0112] Develop a module for developing differentiated operation modes and pipeline network transformation technologies based on risk assessment.

[0113] As an optional implementation of the embodiment of the present invention, the first determination module determines the corrosion risk level of the detection point in the following manner to obtain the corrosion risk level of the detection point:

[0114] Determine whether there is a corrosion rate test piece;

[0115] If the corrosion rate test piece is available, the corrosion rate is obtained according to the corrosion rate test piece, and the corrosion risk level is determined according to the corrosion rate;

[0116] If there is no corrosion rate test piece, determine whether there is cathodic protection;

[0117] If there is no cathodic protection, the pipe-to-ground potential and the ratio of the pipe-to-ground potential forward offset to the soil resistivity are obtained, and the corrosion risk level is determined according to the pipe-to-ground potential and the ratio of the pipe-to-ground potential forward offset to the soil resistivity;

[0118] If there is cathodic protection, determine whether there is stray current interference. If there is no stray current interference, determine the corrosion risk level according to the power-off potential; if there is stray current interference, determine the corrosion risk level according to the DC interference and AC interference respectively.

[0119] As an optional implementation manner of the embodiment of the present invention, the first determination module determines the corrosion risk level according to the DC interference and the AC interference respectively in the following manner:

[0120] If there is DC interference, the corrosion risk level is determined according to the time proportion that the pipeline polarization potential is positively offset from the preset value;

[0121] If AC interference exists, the corrosion risk level is determined based on the AC corrosion current density and the cathodic protection polarization potential.

[0122] As an optional implementation of the embodiment of the present invention, the second determination module determines the pipeline body condition at the detection point in the following manner to obtain the pipeline body condition:

[0123] The condition of the pipeline body is determined according to the service time, pipe diameter and pipeline type of the pipeline to obtain the condition of the pipeline body.

[0124] As an optional implementation of the embodiment of the present invention, the third determination module performs pipeline leakage determination on the adjacent pipelines of the detection point to obtain the pipeline leakage situation in the following manner:

[0125] Based on the service environment of the adjacent pipelines of the detection point, pipeline construction time, cathodic protection measures and interference conditions, the leakage conditions of the pipeline of a preset length within a preset time range are obtained.

[0126] As an optional implementation of the embodiment of the present invention, the correction module corrects the environmental structure of the pipe network area and corrects the risk assessment result in the following manner:

[0127] Based on the downstream user situation of the pipeline network area, the infrastructure and personnel situation near the pipeline network, the correction is made on the basis of the corrosion risk level and the pipeline leakage situation.

[0128] As an optional implementation of the embodiment of the present invention, the fourth determination module grades the third-party construction damage risk in the following manner to obtain the third-party construction damage risk level:

[0129] The third-party construction damage risk is determined based on the entity risk, construction risk, management risk and environmental risk to obtain the third-party construction damage risk level.

[0130] As an optional implementation of the embodiment of the present invention, the formulation module is also used to formulate a suspected leakage point review mode based on risk assessment.

[0131] As an optional implementation of the embodiment of the present invention, the formulation module formulates a suspected leakage point review mode based on risk assessment in the following manner: according to the leakage risk level, a differentiated review strategy and operation mode are formulated.

[0132] It can be seen that through the pipeline operation mode and transformation analysis device based on detection and evaluation provided by the embodiment of the present invention, based on historical pipeline accidents, the key causes are found and the main risks leading to pipeline leakage or accidents are clarified; the common and individual characteristics of risks are classified based on the pipeline laying location, and a scientific evaluation model for different risk categories is constructed; based on factors such as pipeline characteristics, service environment, and risk characteristics, the assessment units are scientifically delineated and pipeline risk evaluation is performed; the pipeline risk evaluation results are connected with differentiated operation and maintenance and transformation to achieve efficient classification and grading management and prevention and control.

[0133] The above are only embodiments of the present application and are not intended to limit the present application. For those skilled in the art, the present application may have various changes and variations. Any modification, equivalent replacement, improvement, etc. made within the spirit and principle of the present application should be included within the scope of the claims of the present application.

Claims

1. A pipeline network operation mode and transformation analysis method based on detection and evaluation, characterized in that: include: Determine the corrosion risk level of the detection point to obtain the corrosion risk level of the detection point; Determine the pipeline main body condition at the detection point to obtain the pipeline main body condition; Performing pipeline leakage determination on the adjacent pipelines of the detection point to obtain pipeline leakage conditions; Make environmental structural corrections to the pipe network area and revise the leakage risk assessment results; Determine the third-party construction damage risk and obtain the third-party construction damage risk level; Establishing a leakage risk differentiation operation model and a construction damage risk differentiation operation model, and using the leakage risk differentiation operation model and the construction damage risk differentiation operation model to perform risk classification on the grid units respectively; Develop differentiated operation modes and pipeline network transformation technologies based on risk assessment.

2. The method according to claim 1, characterized in that Determining the corrosion risk level of the detection point to obtain the corrosion risk level of the detection point includes: Determine whether there is a corrosion rate test piece; If the corrosion rate test piece is available, the corrosion rate is obtained according to the corrosion rate test piece, and the corrosion risk level is determined according to the corrosion rate; If there is no corrosion rate test piece, determine whether there is cathodic protection; If there is no cathodic protection, the pipe-to-ground potential and the ratio of the pipe-to-ground potential forward offset to the soil resistivity are obtained, and the corrosion risk level is determined according to the pipe-to-ground potential and the ratio of the pipe-to-ground potential forward offset to the soil resistivity; If there is cathodic protection, determine whether there is stray current interference. If there is no stray current interference, determine the corrosion risk level according to the power-off potential; if there is stray current interference, determine the corrosion risk level according to the DC interference and AC interference respectively.

3. The method according to claim 2, characterized in that Determining the corrosion risk level according to the DC interference and the AC interference respectively includes: If there is DC interference, the corrosion risk level is determined according to the time proportion that the pipeline polarization potential is positively offset from the preset value; If AC interference exists, the corrosion risk level is determined based on the AC corrosion current density and the cathodic protection polarization potential.

4. The method according to claim 1, characterized in that The determining of the pipeline body condition at the detection point to obtain the pipeline body condition includes: The condition of the pipeline body is determined according to the service time, pipe diameter and pipeline type of the pipeline to obtain the condition of the pipeline body.

5. The method according to claim 1, characterized in that The performing pipeline leakage determination on the adjacent pipeline of the detection point to obtain the pipeline leakage situation comprises: Based on the service environment of the adjacent pipelines of the detection point, pipeline construction time, cathodic protection measures and interference conditions, the leakage conditions of the pipeline of a preset length within a preset time range are obtained.

6. The method according to claim 1, characterized in that The environmental structure correction of the pipe network area and the correction of the leakage risk assessment results include: Based on the downstream user conditions corresponding to the area where the pipeline network is located, the infrastructure and personnel conditions adjacent to the pipeline network, corrections are made based on the corrosion risk level and the pipeline leakage conditions.

7. The method according to claim 1, characterized in that The third-party construction damage risk is graded to obtain the third-party construction damage risk level including: The third-party construction damage risk is determined based on the entity risk, construction risk, management risk and environmental risk to obtain the third-party construction damage risk level.

8. The method according to claim 1, characterized in that Also includes: Develop a review model for suspected leakage points based on risk assessment.

9. The method according to claim 8, characterized in that The suspected leakage point review model formulated based on risk assessment includes: According to the leakage risk level, differentiated review strategies and operation modes are formulated.

10. A pipe network operation mode and transformation analysis device based on detection and evaluation, characterized in that: By adopting the pipeline operation mode and transformation analysis method based on detection and evaluation as described in any one of claims 1 to 9, differentiated operation modes and pipeline transformation technologies based on risk assessment are formulated.

Images