CN113095008A - Corrosion position determination method, device and medium based on flow field analysis in total station - Google Patents
Corrosion position determination method, device and medium based on flow field analysis in total station Download PDFInfo
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Abstract
The application relates to the technical field of natural gas pipeline safety risk evaluation, and discloses a corrosion position determination method, a corrosion position determination device and a corrosion position determination medium based on flow field analysis in a total station, wherein the corrosion position determination method specifically comprises the following steps: establishing a geometric model of the pipeline; introducing the geometric model of the pipeline into a fluid dynamics calculation model to solve and obtain pipeline liquid phase distribution data; and obtaining the corroded pipe section based on the distribution data of the liquid phase of the pipeline. According to the method and the device, the representativeness and the credibility of the detection result can be improved on the premise of controlling the detection cost of the safety state of the natural gas pipeline.
Description
Technical Field
The application relates to the technical field of natural gas pipeline safety risk evaluation, in particular to a corrosion position determination method, a corrosion position determination device and a corrosion position determination medium based on flow field analysis in a total station.
Background
With the rapid development of national economy of China, the demand for natural gas and other energy sources is rapidly increased, and the natural gas industry of China will continue to develop at a high speed in the future. In many gas fields which are developed earlier, the yield of a plurality of natural gas wells is reduced and the water yield is increased rapidly at the last stage of exploitation, when the produced liquid amount exceeds the gas-phase liquid carrying capacity, the produced liquid containing corrosive media can be gathered at the low-lying or special structure part of the gathering and transportation pipeline, and the pipeline accidents such as puncture and rupture are caused by accelerating the corrosion of the pipeline wall surface. In order to ensure the safe operation of the gathering and transportation pipeline and to prevent the occurrence of pipeline accidents, the safety state of the pipeline needs to be regularly detected. In the existing detection method, all parts of the pipeline are difficult to detect due to the limitation of detection cost, but only one or a plurality of high-risk parts are detected, so that potential safety hazards are buried to a certain extent. Since the economic benefit is one of the main factors for limiting the field detection and evaluation effect, the method for predicting and judging the position, which is easy to corrode, of the pipeline is necessary, the representativeness and the credibility of the detection result can be improved on the premise of controlling the detection cost, and the method has certain technical and economic values in the field of pipeline detection.
The position of the pipeline which is easy to be corroded mainly has the following characteristics:
1. the corrosion-susceptible positions of the pipelines can be multiple, and the risk level is divided into a primary part and a secondary part;
2. the self structural characteristics of the pipeline have decisive influence on the pipeline flow field, and the flow field in the pipeline greatly influences the corrosion position and the corrosion strength of the pipeline;
3. the distribution of pipelines in a station yard is extremely complex, wherein buried pipelines are more difficult to carry out comprehensive large-excavation detection, and the low-lying parts of the buried pipelines are usually easy to form accumulated liquid to accelerate corrosion.
At present, in the detection work of the safety state of the natural gas gathering and transportation pipeline, a detection point selection method is single, detection positions mainly comprise structures such as elbows, tees, reducer pipes and the like, and a straight pipe section usually has no detection points or is sparse. After the detection position is selected, a plurality of detection points (generally 4 or 12) are arrayed on the circumference of the wall surface in the direction perpendicular to the flow direction, and the safety state of the pipeline at the detection points is evaluated by detecting the wall thickness value of each point on the wall of the pipeline. On the premise of finishing the detection workload specified by the detection contract, the high-risk parts of the pipeline are difficult to be completely detected and evaluated; the detection positions do not form a uniform standard, and the subdivision formulation of the detection positions is not usually carried out before the detection work is carried out; in addition, a single detection position selection method is difficult to adapt to complex pipeline environments of gathering and transportation stations, high-risk positions can be omitted during detection, and extra cost is also increased during excavation detection.
Disclosure of Invention
Based on the technical problems, the application provides a corrosion position determination method, a corrosion position determination device and a corrosion position determination medium based on flow field analysis in a total station, so that the representativeness and the reliability of a detection result are improved on the premise of controlling the detection cost of the safety state of a natural gas pipeline.
In order to solve the technical problems, the technical scheme adopted by the application is as follows:
the corrosion position judgment method based on the flow field analysis in the total station comprises the following steps: establishing a geometric model of the pipeline; introducing the pipeline geometric model into a fluid dynamics calculation model to solve and obtain pipeline liquid phase distribution data; and obtaining the corroded pipe section based on the distribution data of the liquid phase of the pipeline.
Further, the method for establishing the geometric model of the pipeline comprises the following steps: collecting pipeline basic data, wherein the pipeline basic data comprises a pipeline segmentation single line diagram and pipeline specification data; and establishing a pipeline three-dimensional model based on the pipeline basic data.
Further, the computational fluid dynamics model comprises a multiphase flow model and a turbulence model, and the solving method of the computational fluid dynamics model comprises the following steps: collecting pipeline operation condition data; setting physical properties of a fluid material, boundary conditions and solving modes for solving a multiphase flow model and a turbulence model based on the pipeline operation condition data; carrying out grid division on the pipeline geometric model, and introducing grids into a multiphase flow model and a turbulence model; initializing a flow field and iteratively solving a multiphase flow model and a turbulence model to obtain pipeline liquid phase distribution data.
Further, the main phase of the fluid material is methane, and the secondary phase is water; the multi-phase flow model is a VOF multi-phase flow model; the turbulence model is a standard k-epsilon model; the pipeline operation condition data comprises the pressure, the temperature, the flow, the water yield and the sand yield of the pipeline operation; the solving method adopts coupling solving.
Further, obtaining the corroded pipe section based on the liquid phase distribution data of the pipeline comprises: dividing the pipeline into a plurality of equidistant pipe sections based on a preset length; acquiring the maximum liquid phase volume fraction in the equidistant pipe section and the liquid phase volume fraction at the inlet of the equidistant pipe section based on the liquid phase distribution data of the pipeline; judging whether the ratio of the maximum liquid phase volume fraction to the inlet liquid phase volume fraction is greater than a preset threshold value or not; and if the ratio is larger than a preset threshold value, judging that the equidistant pipe sections are corroded pipe sections.
Further, acquiring the maximum liquid phase volume fraction in the corrosion pipe section and the liquid phase volume fraction at the inlet of the corrosion pipe section based on the pipeline liquid phase distribution data; judging corrosion risk grades based on the ratio of the maximum liquid phase volume fraction to the inlet liquid phase volume fraction, wherein the corrosion risk grades comprise a low corrosion risk, a medium corrosion risk and a high corrosion risk; determining the distribution position of the detection point of the corrosion pipe section based on the corrosion risk grade of the corrosion pipe section and the wall surface liquid phase distribution rule; and arranging detection equipment based on the distribution positions of the detection points to detect and verify the corroded pipe section.
Furthermore, the detection equipment is an ultrasonic thickness gauge, and the ultrasonic side thickness gauge detects the corrosion state of the pipe section by measuring the wall thickness of the pipe section.
In order to solve the above technical problem, the present application further provides a corrosion position determination device based on flow field analysis in a total station field, including:
the model generation module is used for establishing a pipeline geometric model;
the liquid phase distribution acquisition module is used for guiding the pipeline geometric model into a fluid dynamics calculation model to solve and obtain pipeline liquid phase distribution data;
and the corrosion position judging module is used for obtaining a corrosion pipe section based on the pipeline liquid phase distribution data.
In order to solve the technical problem, the present application further provides a computer device, which includes a memory and a processor, where the memory stores a computer program, and the processor implements the steps of the corrosion position determination method based on the full station yard in-flow field analysis when executing the computer program.
In order to solve the technical problem, the present application further provides a computer-readable storage medium, where a computer program is stored, and the computer program, when executed by a processor, implements the steps of the corrosion position determination method based on the flow field analysis in the total station.
Compared with the prior art, the beneficial effects of this application are:
(1) the numerical simulation method has the advantages that numerical simulation of the flow field in the pipeline of the station yard is completed at high speed and high precision, overall control and trend analysis of the on-way liquid holding rate of the pipeline are realized, the position where liquid is easy to accumulate in the pipeline and the corrosion position are determined, and the on-site actual corrosion condition is met with high conformity;
(2) this application is through having good adaptability to the complicated pipeline in different stations, and easy operation cycle is short, and is better with the actual coincidence condition in scene, provides data support for the witnessed inspections, improves witnessed inspections pertinence, reduces detection achievement volume simultaneously.
Drawings
The present application will be further explained by way of exemplary embodiments, which will be described in detail by way of the accompanying drawings, in which:
fig. 1 is a schematic flow chart of a corrosion position determination method based on flow field analysis in a total station field.
Fig. 2 is a flow chart of a solving method of the fluid dynamics calculation model.
FIG. 3 is a schematic diagram of a process for obtaining an eroded pipe segment based on pipeline liquid phase distribution data.
Fig. 4 is a schematic view of a field inspection verification process.
FIG. 5 is a schematic diagram of the distribution of the positions of the detection points.
Figure 6 a pipeline single line diagram.
FIG. 7 is a graph of liquid phase distribution in a pipeline.
FIG. 8 is a schematic representation of the corrosion risk rating of a pipe segment.
Detailed Description
In order to make the objects, technical solutions and advantages of the embodiments of the present disclosure more apparent, the technical solutions of the embodiments of the present disclosure will be described clearly and completely with reference to the drawings of the embodiments of the present disclosure. It is to be understood that the embodiments described are only a few embodiments of the present disclosure, and not all embodiments. All other embodiments, which can be derived by a person skilled in the art from the described embodiments of the disclosure without any inventive step, are within the scope of protection of the disclosure.
Referring to fig. 1, in the present embodiment, a corrosion position determination method based on flow field analysis in a total station includes:
s101, establishing a pipeline geometric model;
s102, introducing the geometric model of the pipeline into a fluid dynamics calculation model to solve and obtain pipeline liquid phase distribution data;
in particular, the computational fluid dynamics model may be constructed based on existing fluid dynamics (CFD) software.
And S103, acquiring a corroded pipe section based on the liquid phase distribution data of the pipeline.
In some embodiments, a method of building a geometric model of a pipe comprises: acquiring pipeline basic data, wherein the pipeline basic data comprises a pipeline segmentation single line diagram and pipeline specification data; and establishing a pipeline three-dimensional model based on the pipeline basic data.
As known in the prior art, a pipeline segment single line diagram is a drawing method according to a positive isometric side or oblique two-side projection, and is drawn as a pipeline blank view represented by a single line, and information such as a mark representing the direction of a pipeline, a weld crater number, a pipeline material and the like is arranged on the diagram.
Specifically, the orientation and the size of the single line diagram are drawn according to the data provided by the plan view and the section view.
Specifically, a single line representation of the conduit is shown, for example, in FIG. 6.
Specifically, the three-dimensional pipeline model is drawn through three-dimensional drawing software such as CAD and UG.
Referring to fig. 2, in some embodiments, the computational fluid dynamics model includes a multi-phase flow model and a turbulence model, and the solving method of the computational fluid dynamics model includes:
s201, collecting pipeline operation condition data;
specifically, the pipeline operation condition data includes pressure, temperature, flow, water yield and sand yield of the pipeline operation.
S202, setting physical properties of a fluid material, boundary conditions and solving modes for solving a multiphase flow model and a turbulent flow model based on the pipeline operation condition data;
specifically, the major phase of the fluid material is methane and the minor phase is water.
Specifically, the multiphase flow model is a VOF multiphase flow model.
Specifically, the turbulence model is a standard k-epsilon model.
S203, carrying out grid division on the geometric model of the pipeline, and introducing grids into a multiphase flow model and a turbulence model;
and S204, initializing a flow field, and iteratively solving the multiphase flow model and the turbulence model to obtain pipeline liquid phase distribution data.
Specifically, the solving method adopts coupled solving.
Specifically, the calculation data obtained by solving the fluid dynamics calculation model can be introduced into fluid dynamics (CFD) post-processing software, liquid phase data distributed along a pipeline is derived, and a liquid phase distribution curve along the pipeline flow direction is drawn, so that the pipeline liquid phase distribution data can be conveniently and visually obtained.
Specifically, an example of the liquid phase distribution curve is shown in fig. 7.
Referring to FIG. 3, in some embodiments, obtaining an erosion pipe segment based on pipeline liquid phase distribution data includes:
s301, dividing the pipeline into a plurality of equidistant pipe sections based on a preset length;
s302, acquiring the maximum liquid phase volume fraction in the equidistant pipe section and the liquid phase volume fraction at the inlet of the equidistant pipe section based on the liquid phase distribution data of the pipeline;
s303, judging whether the ratio of the maximum liquid phase volume fraction to the inlet liquid phase volume fraction is greater than a preset threshold value or not;
s304, if the ratio is larger than a preset threshold value, the equidistant pipe sections are judged to be corroded pipe sections.
And if the ratio is smaller than a preset threshold value, judging that the equidistant pipe section is not a corroded pipe section.
Referring to fig. 4, in some embodiments, further comprising:
s401, acquiring the maximum liquid phase volume fraction in the corrosion pipe section and the liquid phase volume fraction at the inlet of the corrosion pipe section based on the pipeline liquid phase distribution data; judging the corrosion risk grade based on the ratio of the maximum liquid phase volume fraction to the inlet liquid phase volume fraction;
in particular, the corrosion risk classes include low corrosion risk, medium corrosion risk, and high corrosion risk.
Wherein, the specific judgment standard for the corrosion risk level is shown in the following table 1:
TABLE 1 Corrosion grade criteria List
Specifically, the R values in table 1 above are obtained empirically and are summarized by the testing personnel from long-term practice and experiments.
S402, determining distribution positions of detection point positions of the corrosion pipe section based on the corrosion risk level of the corrosion pipe section and the wall surface liquid phase distribution rule;
the distribution rule of the liquid phase on the wall surface of the corrosion pipe section specifically means that the liquid phase in the pipeline has a certain rule under the action of gravity and under the influence of the section structure of the pipe section, and the position of a section detection point of the corrosion pipe section can be selected according to the distribution rule of the liquid phase on the wall surface.
The gravity reuse and the difference of the section structure of the pipe section can be known, the liquid phase is mainly concentrated at the bottom of the pipeline under the action of gravity, the corrosion risk of the bottom of the pipeline is high, and therefore in the aspect of arrangement of the detection points, the detection points can be arranged on the bottom surface of the pipe section by means of the gravity.
Wherein, according to the section structure of the pipe section, the liquid phase is mainly concentrated at the middle-lower part of the straight pipe section under the action of gravity; at the elbow, the liquid phase is influenced by inertia and gathers on the outer wall surface of the elbow and the extending direction thereof; at the vertical rising elbow, liquid phase is mainly gathered at the outer wall of the elbow and the upper straight pipe section; at the horizontal elbow, the liquid phase is gathered at the bottom and the outer wall of the pipeline due to the centrifugal force and the gravity.
Therefore, in the detection work, the selection of the detection point of the section of the pipe section can be carried out according to the liquid phase distribution rule of the section.
Referring to fig. 5, three types a, B and C are conventional section detection points, the distribution of the detection points in the current pipeline detection work is that the detection points are circumferentially and uniformly distributed on the detection section, and the wall thickness loss of the pipeline section is influenced by the wall liquid phase distribution rule according to the summary of field detection data of detection personnel.
Therefore, in this embodiment, referring to fig. 5, D, E, and F, a point selection method recommended to be used according to a wall liquid phase distribution rule is provided, such a detection point distribution method not only considers differences in cross-section circumferential corrosion degrees and can accurately detect the position of a heavy point, but also reduces detection points at non-key positions and reduces detection workload and detection cost.
And S403, arranging detection equipment to detect and verify the corrosion pipe section based on the distribution positions of the detection points.
Specifically, the detection equipment is an ultrasonic thickness gauge, and the ultrasonic side thickness gauge detects the corrosion state of the pipe section by measuring the wall thickness of the pipe section.
In the above embodiments, in the present application, a pipeline geometric model is established according to natural gas gathering and transportation field data, simulated pipeline operation conditions are set, a flow state of raw material natural gas from a wellhead to a gas-liquid separator is simulated based on fluid dynamics (CFD) software, influences of different operation conditions on effusion conditions at different positions of a pipeline are analyzed by changing parameters such as flow, pressure, and water content, so as to obtain quantitative evaluation results, and finally, field detection data is used for verification, so that a method for predicting and determining a position prone to corrosion in pipeline detection is provided, so that representativeness and credibility of the detection results are improved on the premise of controlling detection cost of a natural gas pipeline safety state.
Referring to fig. 6 to 8, the corrosion position determination method of the present application will be described with reference to specific examples:
wherein, the pipeline single line diagram is as shown in fig. 6, and a pipeline three-dimensional model can be constructed based on the pipeline single line diagram and the pipeline specification data in fig. 6;
the method comprises the steps of introducing a three-dimensional pipeline model into fluid dynamics (CFD) software, selecting a VOF model for a multiphase flow model, selecting a standard k-epsilon model for a turbulence model, selecting methane for a main phase fluid, selecting water for a secondary phase fluid, selecting a speed inlet and a pressure outlet for boundary conditions, setting the wall type as a standard, initializing a flow field, selecting a solving mode to be coupled solving, carrying out iterative computation until the result is converged, and obtaining a computation result of pipeline liquid phase distribution data obtained through simulation.
The calculation results were introduced into fluid dynamics (CFD) post-processing software, and the liquid phase distribution data of the pipe along the pipeline was derived, and a liquid phase distribution curve along the pipe flow direction as shown in fig. 7 was plotted. Specifically, the pipeline is divided into 1m equidistant pipe sections, the length of the pipe sections in partial areas can be properly reduced, and a liquid content rate change curve of each pipe section is drawn.
As can be seen from FIG. 7, the liquid contents of the pipe sections 14-17, 31-34 and 53-57 are increased to different extents, wherein the liquid contents of the pipe sections 53-57 are increased most obviously. The corrosion grade of each pipe section was evaluated according to the criteria of table 1 above, and a ladder diagram of the corrosion grade of each pipe section was drawn.
As can be seen from FIG. 8, the pipe sections 33-34, 52-53 and 58-59 belong to a II-grade moderate corrosion area, and the pipe sections 54-57 belong to a III-grade easy corrosion area, according to the on-site detection data, the loss of the pipe wall thickness of the pipe section 57 is 2-3 times that of other straight pipe sections without liquid accumulation, and obviously, in the on-site detection, the positions where liquid accumulation is easy to occur should be included in the routine detection work.
To solve the above technical problem, in some embodiments, the present application further provides an erosion position determination device based on an analysis of a flow field in a total station, including:
the model generation module is used for establishing a pipeline geometric model;
the liquid phase distribution acquisition module is used for guiding the pipeline geometric model into a fluid dynamics calculation model to solve and obtain pipeline liquid phase distribution data;
and the corrosion position judging module is used for obtaining a corrosion pipe section based on the pipeline liquid phase distribution data.
The computer device can be a desktop computer, a notebook, a palm computer, a cloud server and other computing devices. The computer equipment can be in man-machine interaction with a user through a keyboard, a mouse, a remote controller, a touch panel or voice control equipment and the like.
The memory includes at least one type of readable storage medium including a flash memory, a hard disk, a multi-media card, a card-type memory (e.g., SD or D interface display memory, etc.), a Random Access Memory (RAM), a Static Random Access Memory (SRAM), a read-only memory (ROM), an electrically erasable programmable read-only memory (EEPROM), a programmable read-only memory (PROM), a magnetic memory, a magnetic disk, an optical disk, etc. In some embodiments, the storage may be an internal storage unit of the computer device, such as a hard disk or a memory of the computer device. In other embodiments, the memory may also be an external storage device of the computer device, such as a plug-in hard disk, a Smart Media Card (SMC), a Secure Digital (SD) Card, a Flash memory Card (Flash Card), and the like provided on the computer device. Of course, the memory may also include both internal and external storage devices of the computer device. In this embodiment, the memory is commonly used for storing an operating system and various types of application software installed in the computer device, such as program codes of a corrosion position determination method based on flow field analysis in a total station. In addition, the memory may also be used to temporarily store various types of data that have been output or are to be output.
The processor may be a Central Processing Unit (CPU), controller, microcontroller, microprocessor, or other data Processing chip in some embodiments. The processor is typically used to control the overall operation of the computer device. In this embodiment, the processor is configured to execute the program code stored in the memory or process data, for example, execute the program code of the corrosion position determination method based on the flow field analysis in the total station.
In order to solve the technical problem, in some embodiments, the present application further provides a computer device, including a memory and a processor, where the memory stores a computer program, and the processor implements the steps of the corrosion position determination method based on flow field analysis in a total station field when executing the computer program.
In order to solve the technical problem, the present application further provides a computer-readable storage medium, where a computer program is stored, and the computer program, when executed by a processor, implements the steps of the corrosion position determination method based on the flow field analysis in the total station.
The above is an embodiment of the present application. The embodiments and specific parameters in the embodiments are only used for clearly illustrating the verification process of the invention and are not used for limiting the patent protection scope of the present application, which is subject to the claims, and all the equivalent structural changes made by using the contents of the specification and the drawings of the present application should be included in the protection scope of the present application.
Claims (10)
1. The corrosion position determination method based on the flow field analysis in the total station is characterized by comprising the following steps of:
establishing a geometric model of the pipeline;
introducing the pipeline geometric model into a fluid dynamics calculation model to solve and obtain pipeline liquid phase distribution data;
and obtaining the corroded pipe section based on the pipeline liquid phase distribution data.
2. The method for determining corrosion position based on flow field analysis in a total station field according to claim 1, wherein the method for establishing a geometric model of a pipe comprises:
collecting pipeline basic data, wherein the pipeline basic data comprises a pipeline segmentation single line diagram and pipeline specification data;
and establishing a pipeline three-dimensional model based on the pipeline basic data.
3. The corrosion position determination method based on the total-station intrafield flow field analysis according to claim 1, wherein the computational fluid dynamics model includes a multiphase flow model and a turbulence model, and the solving method of the computational fluid dynamics model includes:
collecting pipeline operation condition data;
setting physical properties of a fluid material and boundary conditions and solving modes for solving the multiphase flow model and the turbulence model based on the pipeline operation condition data;
carrying out mesh division on the geometric model of the pipeline, and leading the meshes into the multiphase flow model and the turbulence model;
initializing a flow field and iteratively solving the multiphase flow model and the turbulence model to obtain the pipeline liquid phase distribution data.
4. The corrosion position determination method based on flow field analysis in a total station field according to claim 3, characterized in that:
the pipeline operation condition data comprises the pressure, the temperature, the flow, the water yield and the sand yield of the pipeline operation;
the main phase of the fluid material is methane, and the secondary phase is water;
the multi-phase flow model is a VOF multi-phase flow model;
the turbulence model is a standard k-epsilon model;
the solving mode adopts coupling solving.
5. The method for determining the corrosion position based on the flow field analysis in the total station field according to claim 1, wherein the obtaining of the corroded pipe section based on the pipe liquid phase distribution data comprises:
dividing the pipeline into a plurality of equidistant pipe sections based on a preset length;
acquiring the maximum liquid phase volume fraction in the equidistant pipe section and the liquid phase volume fraction at the inlet of the equidistant pipe section based on the pipeline liquid phase distribution data;
judging whether the ratio of the maximum liquid phase volume fraction to the inlet liquid phase volume fraction is greater than a preset threshold value or not;
and if the ratio is larger than a preset threshold value, judging that the equidistant pipe section is a corroded pipe section.
6. The method for determining the corrosion position based on the analysis of the flow field in the total station according to claim 1, further comprising:
acquiring the maximum liquid phase volume fraction in the corrosion pipe section and the liquid phase volume fraction at the inlet of the corrosion pipe section based on the pipeline liquid phase distribution data;
determining a corrosion risk level based on a ratio of the maximum liquid phase volume fraction to the inlet liquid phase volume fraction, the corrosion risk level comprising a low corrosion risk, a medium corrosion risk, and a high corrosion risk;
determining the position of a detection point of the corrosion pipe section based on the corrosion risk level of the corrosion pipe section and the wall surface liquid phase distribution rule;
and arranging detection equipment to detect and verify the corroded pipe section based on the position of the detection point.
7. The corrosion position determination method based on flow field analysis in a total station field according to claim 6, characterized in that:
the detection equipment is an ultrasonic thickness gauge, and the ultrasonic side thickness gauge detects the corrosion state of the pipe section by measuring the wall thickness of the pipe section.
8. Corrosion position decision maker based on flow field analysis in total powerstation, its characterized in that includes:
a model generation module for establishing a pipeline geometric model;
the liquid phase distribution acquisition module is used for guiding the pipeline geometric model into a fluid dynamics calculation model to be solved to obtain pipeline liquid phase distribution data;
and the corrosion position determination module is used for obtaining a corrosion pipe section based on the pipeline liquid phase distribution data.
9. A computer arrangement, characterized by comprising a memory in which a computer program is stored and a processor which, when executing said computer program, carries out the steps of the method for determining a position of corrosion based on an analysis of a flow field within a total station field according to any one of claims 1 to 7.
10. A computer-readable storage medium, having stored thereon a computer program which, when being executed by a processor, carries out the steps of the method for determining a corrosion position based on flow field analysis within a total station field of any one of claims 1 to 7.
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