CN114673939A - Detection and positioning method for trace leakage of natural gas - Google Patents
Detection and positioning method for trace leakage of natural gas Download PDFInfo
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- CN114673939A CN114673939A CN202210252834.6A CN202210252834A CN114673939A CN 114673939 A CN114673939 A CN 114673939A CN 202210252834 A CN202210252834 A CN 202210252834A CN 114673939 A CN114673939 A CN 114673939A
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- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 title claims abstract description 178
- 238000001514 detection method Methods 0.000 title claims abstract description 89
- 238000000034 method Methods 0.000 title claims abstract description 52
- 239000003345 natural gas Substances 0.000 title claims abstract description 45
- 239000007789 gas Substances 0.000 claims abstract description 116
- 238000004458 analytical method Methods 0.000 claims abstract description 14
- 229910000831 Steel Inorganic materials 0.000 claims abstract description 6
- 239000010959 steel Substances 0.000 claims abstract description 6
- 238000005070 sampling Methods 0.000 claims description 12
- 238000002347 injection Methods 0.000 claims description 10
- 239000007924 injection Substances 0.000 claims description 10
- 230000010354 integration Effects 0.000 claims description 9
- OTMSDBZUPAUEDD-UHFFFAOYSA-N Ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 claims description 3
- 238000009825 accumulation Methods 0.000 claims description 2
- 238000004364 calculation method Methods 0.000 description 6
- 239000012466 permeate Substances 0.000 description 6
- 239000000243 solution Substances 0.000 description 5
- 238000005259 measurement Methods 0.000 description 3
- 230000008569 process Effects 0.000 description 3
- 230000005540 biological transmission Effects 0.000 description 2
- 239000013307 optical fiber Substances 0.000 description 2
- 238000012360 testing method Methods 0.000 description 2
- 238000001069 Raman spectroscopy Methods 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000004868 gas analysis Methods 0.000 description 1
- 230000008595 infiltration Effects 0.000 description 1
- 238000001764 infiltration Methods 0.000 description 1
- 230000003993 interaction Effects 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012544 monitoring process Methods 0.000 description 1
- 230000035515 penetration Effects 0.000 description 1
- 239000000047 product Substances 0.000 description 1
- 230000003068 static effect Effects 0.000 description 1
- 238000006467 substitution reaction Methods 0.000 description 1
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
- F17D—PIPE-LINE SYSTEMS; PIPE-LINES
- F17D5/00—Protection or supervision of installations
- F17D5/02—Preventing, monitoring, or locating loss
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
- F17D—PIPE-LINE SYSTEMS; PIPE-LINES
- F17D1/00—Pipe-line systems
- F17D1/02—Pipe-line systems for gases or vapours
- F17D1/065—Arrangements for producing propulsion of gases or vapours
- F17D1/07—Arrangements for producing propulsion of gases or vapours by compression
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
- F17D—PIPE-LINE SYSTEMS; PIPE-LINES
- F17D3/00—Arrangements for supervising or controlling working operations
- F17D3/01—Arrangements for supervising or controlling working operations for controlling, signalling, or supervising the conveyance of a product
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01M—TESTING STATIC OR DYNAMIC BALANCE OF MACHINES OR STRUCTURES; TESTING OF STRUCTURES OR APPARATUS, NOT OTHERWISE PROVIDED FOR
- G01M3/00—Investigating fluid-tightness of structures
- G01M3/02—Investigating fluid-tightness of structures by using fluid or vacuum
- G01M3/04—Investigating fluid-tightness of structures by using fluid or vacuum by detecting the presence of fluid at the leakage point
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- General Engineering & Computer Science (AREA)
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- General Physics & Mathematics (AREA)
- Examining Or Testing Airtightness (AREA)
Abstract
The invention relates to a detection and positioning method for trace leakage of natural gas, which comprises the following steps: arranging a detection positioning system near the long natural gas pipeline, opening a standard gas steel cylinder in the detection positioning system, and injecting characteristic gas C3 into one end of a leakage detection permeation tube; opening an air compressor, providing a positive pressure power source, pushing air in the leakage detection permeation tube to flow, enabling the air to flow together with the injected characteristic gas C3 and the natural gas trapped in the leakage detection permeation tube to flow out of the other end of the leakage detection permeation tube, and enabling the air to sequentially enter a mass flow controller and an online gas analyzer for analysis; when the online gas analyzer detects the concentration value of the characteristic gas C3, all gases in the leakage detection permeation tube are extracted for analysis; traversing and analyzing the detection data, identifying a methane concentration peak and a characteristic gas C3 concentration peak, and judging whether leakage occurs or not; if there is a leak, the location of the methane leak is calculated. The invention can improve the positioning precision of the trace leakage detection of the natural gas pipeline.
Description
Technical Field
The invention relates to the technical field of natural gas leakage detection in pipe transmission, in particular to a detection and positioning method for trace leakage of natural gas.
Background
The natural gas long-distance pipeline leakage accident has serious consequences and a large influence range, and is the key point of safety production attention. Because the natural gas pipeline is usually buried underground and laid, the space span is large, how to timely and effectively discover natural gas leakage and accurately position a leakage point is achieved, and the method has important significance for timely disposing and preventing potential accidents.
The current natural gas pipeline leakage detection technology mainly comprises optical fiber leakage detection and ultrasonic leakage detection. The optical fiber leakage detection is to detect the temperature change caused by the natural gas pipeline leakage through the Raman scattering effect and to inversely calculate the position of a leakage point through the light wave transmission distance; the ultrasonic leakage detection is to detect high-frequency sound waves generated at a crevasse when the natural gas pipeline leaks and to inversely calculate the position of a leakage point by detecting the time difference of the sound waves transmitted to two ends of the pipeline. The above-described technique usually reveals a leak when a leak is detected, and has no detection capability for a minute leak generated by a minute crack or the like, and a gas leak cannot be detected at an extremely early stage. In the existing literature, natural gas in the environment is collected through a penetration pipe which is laid in the same ditch as a natural gas pipeline and is made of special materials, and the natural gas is conveyed to a gas detector for analysis in a positive pressure or negative pressure driving mode, so that trace leaked natural gas can be detected. The detection technique, however, back calculates the location of the leak by measuring the time at which the leaking gas is detected, as well as the gas flow rate. Because the sampling pump can form certain differential pressure in the test tube in the sampling process, and the pressure, the velocity of flow etc. of gas are all unstable, fluctuate at any time, cause very big influence to the positioning calculation. Since the length of the detector tube can reach 30 kilometers at most, even a small error can cause a deviation of several hundreds of kilometers in positioning result.
Disclosure of Invention
In view of the above problems, an object of the present invention is to provide a method for detecting and positioning trace leakage of natural gas, which eliminates the influence of factors such as gas density, pipeline cross-sectional area, and pressure fluctuation on the calculation result, and effectively improves the accuracy of detecting and positioning trace leakage of natural gas pipeline.
In order to realize the purpose, the invention adopts the following technical scheme: a detection and positioning method for trace leakage of natural gas comprises the following steps: arranging a detection positioning system near a natural gas long-distance pipeline, wherein the detection positioning system comprises an air compressor, a mass flow controller, an online gas analyzer, a leakage detection permeation tube and a standard gas steel cylinder; opening the standard gas cylinder and injecting characteristic gas C3 into one end of the leakage detection permeation tube; turning on the air compressor, providing a positive pressure power source, pushing air in the leakage detection permeation tube to flow, enabling the air to flow together with the injected characteristic gas C3 and the natural gas trapped in the leakage detection permeation tube to flow out of the other end of the leakage detection permeation tube, and enabling the air to sequentially enter the mass flow controller and the online gas analyzer for analysis; when the online gas analyzer detects the concentration value of the characteristic gas C3, the online gas analyzer indicates that all gases in the leakage detection permeation tube are extracted for analysis, and a detection period is finished; traversing and analyzing the detection data, identifying a methane concentration peak and a characteristic gas C3 concentration peak, and judging whether leakage occurs or not; if there is a leak, the location of the methane leak is calculated.
Further, the identifying of the methane concentration peak and the characteristic gas C3 concentration peak by adopting a peak identification method comprises the following steps:
arranging all the methane concentration data detected by the online gas analyzer according to a time sequence;
setting a methane concentration reference value CbaseBelow the reference methane concentration value CbaseData skipping of (3);
for the concentration of methane greater than the reference value CbaseData C ofnThe data CnComparing with m data before and m data after it, if CnIf the value is the maximum value, the n is considered as a methane concentration peak value;
several methane concentration peaks are identified, i.e. several leaks are present.
Further, the method for calculating the position of the methane leakage point adopts an equal mass method or a flow rate integration method.
Further, the equal quality method comprises the following steps: and calculating the position of the leakage point by accumulating the ratio of the flow values by using the distance of the characteristic gas injection point as a known value under the condition that the gas density in the detection pipe is the same.
Further, the flow rate integration method includes: converting the measured mass flow or volume flow into a flow velocity value, and calculating the position of a leakage point through the accumulation of the flow velocity; and correcting the leakage point positioning value by using the distance of the characteristic gas injection point as a known value.
Further, the mass flow controller controls the flow rate of the gas so that the gas enters the online gas analyzer according to a constant mass flow.
Further, the online gas analyzer performs real-time online sampling analysis on gas components in the air, and the sampling frequency is 1 time per second.
Furthermore, the online gas analyzer adopts the combination of various types of analyzers to realize ppm level concentration detection of various components of methane, ethane and C3 gas.
Due to the adoption of the technical scheme, the invention has the following advantages:
1. the invention adopts an equal mass positioning method, utilizes the known condition of the distance from the characteristic gas injection point to the outlet of the detection tube, can approximate the reasonable assumption that the density is uniform based on the gas in the whole process of the detection tube, and simplifies the calculation to obtain the position of the leakage peak by accumulating the proportion of flow values. Compared with a flow velocity integral algorithm, the method saves a flow velocity conversion process, eliminates the influence of factors such as gas density, pipeline sectional area and pressure fluctuation on a calculation result, and has high positioning precision.
2. The invention adopts a flow velocity integration method, and corrects the positioning result by using the distance from the characteristic gas injection point to the outlet of the detection tube as a known condition on the basis of conventional flow velocity integration, thereby improving the positioning accuracy.
Drawings
FIG. 1 is a schematic diagram of a detection and positioning system for natural gas micro-leakage in an embodiment of the invention.
Detailed Description
In order to make the objects, technical solutions and advantages of the embodiments of the present invention clearer, the technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the drawings of the embodiments of the present invention. It should be apparent that the described embodiments are only some of the embodiments of the present invention, and not all of them. All other embodiments, which can be derived by a person skilled in the art from the description of the embodiments of the invention given above, are within the scope of protection of the invention.
It is noted that the terminology used herein is for the purpose of describing particular embodiments only and is not intended to be limiting of exemplary embodiments according to the present application. As used herein, the singular forms "a", "an" and "the" are intended to include the plural forms as well, and it should be understood that when the terms "comprises" and/or "comprising" are used in this specification, they specify the presence of stated features, steps, operations, devices, components, and/or combinations thereof, unless the context clearly indicates otherwise.
The invention provides a detection and positioning method for trace leakage of natural gas, which is suitable for online monitoring of trace leakage of a long-distance natural gas pipeline. The invention comprises the following steps: arranging a detection positioning system near the natural gas long-distance pipeline, opening a standard gas steel cylinder in the detection positioning system, and injecting characteristic gas C3 into one end of the leakage detection permeation tube; opening an air compressor, providing a positive pressure power source, pushing air in the leakage detection permeation tube to flow, enabling the air to flow together with the injected characteristic gas C3 and natural gas trapped in the leakage detection permeation tube to flow out of the other end of the leakage detection permeation tube, and enabling the air to enter a mass flow controller and an online gas analyzer in sequence for analysis; when the online gas analyzer detects the concentration value of the characteristic gas C3, all gases in the leakage detection permeation tube are extracted for analysis; traversing and analyzing the detection data, identifying a methane concentration peak and a characteristic gas C3 concentration peak, and judging whether leakage occurs; if there is a leak, the location of the methane leak is calculated. The invention can improve the positioning precision of the trace leakage detection of the natural gas pipeline.
In an embodiment of the present invention, as shown in fig. 1, a method for detecting and locating a trace leakage of natural gas is provided, and this embodiment is illustrated by applying the method to a terminal, it is to be understood that the method may also be applied to a server, and may also be applied to a system including a terminal and a server, and is implemented by interaction between the terminal and the server.
In this embodiment, the method includes the steps of:
1) arranging a detection positioning system near a natural gas long-distance pipeline 1, wherein the detection positioning system comprises a standard gas steel cylinder 2, a leakage detection permeation tube 3, an air compressor 4, a mass flow controller 5 and an online gas analyzer 6;
2) opening the standard gas cylinder 2 and injecting characteristic gas C3 into one end of the leakage detection permeation tube 3;
3) turning on the air compressor 4, providing a positive pressure power source, pushing the air in the leakage detection permeation tube 3 to flow, flowing out from the other end of the leakage detection permeation tube 3 together with the injected characteristic gas C3 and the natural gas trapped in the leakage detection permeation tube 3, and sequentially entering the mass flow controller 5 and the online gas analyzer 6 for analysis;
the mass flow controller 5 controls the flow rate of the gas to enable the gas to enter the online gas analyzer 6 according to constant mass flow; the mass flow controller 5 comprises a mass flow meter, a control chip and a control valve, can realize mass flow measurement, and automatically control the opening of the valve according to the set flow value so as to control the flow rate of the gas; the system records the flow value measured by the mass flow controller 5 according to the sampling interval in 1 second;
The online gas analyzer 6 is used for carrying out real-time online sampling analysis on gas components in the air; the sampling frequency is 1 time per second;
the on-line gas analyzer 6 can adopt a combination of various types of analyzers, and can realize ppm level concentration detection on various components such as methane, ethane, C3 gas and the like;
4) when the online gas analyzer 6 detects the concentration value of the characteristic gas C3, the online gas analyzer indicates that all the gases in the leakage detection permeation tube 3 are pumped out for analysis, and a detection period is finished;
the system is used for sampling and analyzing the extracted gas in real time. The on-line gas analyzer 6 is located at one end of the leak detection permeate tube 3, and the characteristic gas is injected from the other end of the leak detection permeate tube 3, so that when the characteristic gas is detected, it indicates that a detection cycle is finished;
5) traversing and analyzing the detection data, identifying a methane concentration peak and a characteristic gas C3 concentration peak, and judging whether leakage occurs; if there is a leak, the location of the methane leak is calculated.
In the step 5), a peak value identification method is adopted to identify a methane concentration peak and a characteristic gas C3 concentration peak and judge whether leakage occurs, and the method comprises the following steps:
5.1) arranging all the methane concentration data detected by the online gas analyzer 6 according to a time sequence;
5.2) setting a reference value C of methane concentrationbaseBelow the reference value C for methane concentrationbaseData skipping of (3);
5.3) for values greater than the reference value C for methane concentrationbaseData C ofnThe data CnM data C ahead of itn-m，Cn-m+1,···Cn-1And m data Cn+1，···，Cn+mMaking a comparison if CnIf the value is the maximum value, the n is considered as a methane concentration peak value; the value of m can be adjusted according to the measurement data, for example, m is 3.
5.4) several methane concentration peaks are identified, i.e. several leaks are present.
In the step 6), the method for calculating the position of the methane leakage point may adopt an equal mass method or a flow rate integration method.
The principle of the equal-quality method is as follows: in the static state, the gas density in the leak detection permeate tube 3 is approximately uniformly distributed:
where m is the mass of the gas in the leak-detection permeate tube 3, L is the gas length, a is the cross-sectional area of the leak-detection permeate tube 3, and ρ is the density of the gas in the leak-detection permeate tube 3.
The length L of gas flowing through the permeation tube 3 is measured for leakage at time ttComprises the following steps:
wherein q istMass flow at time t, mtThe mass of gas in the permeation tube 3 was checked for leaks at time t.
In actual detection, the system samples each second to obtain a discrete value of the flow rate, and the above integral value can be approximated as an accumulated value from 0 to t:
Wherein q isiAnd the measured value of the mass flow value of the ith second is, and delta t is a sampling time interval.
Assuming a peak methane concentration is detected at time m, the leak point is spaced from the flow controller by a distance LmComprises the following steps:
assuming that a characteristic gas concentration peak is detected at time n, the distance from the characteristic gas injection point to the mass flow meter is:
l in the above formula0Can be obtained by measurement and is a known value. Combining the above two equations, one can obtain:
q for certain mass flow controller outputsiIs a converted standard condition volume flow value, and the method is still applicable because the density is assumed to be uniform in the method.
In this example, the position of the methane leak was calculated using an equal mass method: the gas density in the detection pipe is assumed to be the same, the distance of the characteristic gas injection point is used as a known value, the position of the leakage point is calculated by accumulating the ratio of the flow values, the calculation method is simplified, and the positioning precision is high. Specifically, the method for calculating the position of the methane leakage point by adopting an equal mass method comprises the following steps:
(1) arranging the mass flow values, the methane concentration values and the C3 gas concentration values measured at all the moments in time according to a time sequence;
(2) assuming that the peak of methane concentration occurs at time m and the peak of C3 gas concentration occurs at time n, the sum of the mass flows from time 0 to time m is calculated 
(3) Calculating the sum of the mass flows from time 0 to time n
(4) Based on the sum of the mass flow rates from time 0 to time m and the mass from time 0 to time nAnd (3) calculating the distance from the leakage point to the mass flowmeter according to the sum of the flow rates:
in this example, the position of the methane leak was calculated using a flow rate integration method: and converting the measured mass flow or volume flow into a flow velocity value, and calculating the position of the leakage point by accumulating the flow velocity. Similarly, the leak location value may be corrected using the known distance from the characteristic gas injection point.
Specifically, the method for calculating the position of the methane leakage point by adopting a flow rate integration method comprises the following steps:
(1) determining the distance L over which the gas flowst：
The above-described integrated value may be approximated as an accumulated value from 0 to time t.
(2) Calculating the distance L from the leakage point to the mass flowmeterm：
In the formula, d is the pipe diameter of the detection pipe, rho is the air density in the current state, and the air density rho in the standard condition can be measured according to the measured temperature and pressure values according to an ideal state equation0And (5) correcting to obtain the product.
If the flowmeter gives a volume flow value, the above equation can be simplified as:
in the formula, qv iAnd the temperature and the pressure are corrected according to an ideal state equation for the standard condition volume flow value at the moment i.
In order to eliminate the influence of factors such as density, pipe diameter and the like, the positioning result is corrected by utilizing the known condition of the distance between the characteristic gas injection points, and the following results are obtained:
in the step 1), a leakage detection permeation tube 3 in the detection positioning system is laid in parallel with the natural gas long-distance pipeline 1 and is used for capturing trace natural gas leaked from the natural gas long-distance pipeline 1; one end of the permeation tube 3 for leak detection is provided with an air compressor 4 for providing power source, and a standard gas steel cylinder 2 is arranged between the air compressor 4 and the permeation tube 3 for leak detection. The other end of the leakage detection permeation tube 3 is connected with a mass flow controller 5 and an online gas analyzer 6 in sequence. A pressure gauge PT and a temperature gauge TT are arranged between the other end of the leakage detection permeation tube 3 and the mass flow controller 5.
During the use, air compressor machine 4 provides the power supply, carries the gas in the leak testing infiltration pipe 3 through air compressor machine 4 and carries out ppm level's concentration detection in online gas analysis appearance 6 to it takes place the tiny leakage to discern the pipeline. The gas flow rate is controlled by a mass flow controller 5, sampling is performed at a constant flow rate, and a real-time flow value is recorded as a basis for back calculation of the leak location.
Finally, it should be noted that: the above examples are only intended to illustrate the technical solution of the present invention, and not to limit it; although the present invention has been described in detail with reference to the foregoing embodiments, it should be understood by those of ordinary skill in the art that: the technical solutions described in the foregoing embodiments may still be modified, or some technical features may be equivalently replaced; and such modifications or substitutions do not depart from the spirit and scope of the corresponding technical solutions of the embodiments of the present invention.
Claims (8)
1. A detection and positioning method for trace leakage of natural gas is characterized by comprising the following steps:
arranging a detection positioning system near a natural gas long-distance pipeline, wherein the detection positioning system comprises an air compressor, a mass flow controller, an online gas analyzer, a leakage detection permeation tube and a standard gas steel cylinder;
opening the standard gas cylinder and injecting characteristic gas C3 into one end of the leakage detection permeation tube;
turning on the air compressor, providing a positive pressure power source, pushing the air in the leakage detection permeation tube to flow, enabling the air to flow together with the injected characteristic gas C3 and the natural gas trapped in the leakage detection permeation tube to flow out of the other end of the leakage detection permeation tube, and sequentially entering the mass flow controller and the online gas analyzer for analysis;
When the online gas analyzer detects the concentration value of the characteristic gas C3, the online gas analyzer indicates that all gases in the leakage detection permeation tube are extracted for analysis, and a detection period is finished;
traversing and analyzing the detection data, identifying a methane concentration peak and a characteristic gas C3 concentration peak, and judging whether leakage occurs; if there is a leak, the location of the methane leak is calculated.
2. The method for detecting and locating natural gas micro-leakage according to claim 1, wherein the identifying the methane concentration peak and the characteristic gas C3 concentration peak by a peak value identification method comprises:
arranging all the methane concentration data detected by the online gas analyzer according to a time sequence;
setting a methane concentration reference value CbaseBelow the reference value C for methane concentrationbaseData skipping of (1);
for a value greater than the reference value C for methane concentrationbaseData C ofnThe data CnComparing with m data before and m data after the data, if CnIf the value is the maximum value, the n is considered as a methane concentration peak value;
several methane concentration peaks are identified, i.e. several leaks are present.
3. The method for detecting and locating the trace leakage of natural gas as claimed in claim 1, wherein the position of the methane leakage point is calculated by an equal mass method or a flow rate integration method.
4. The method for detecting and locating the trace leakage of the natural gas as claimed in claim 3, wherein the equal quality method comprises the following steps: and calculating the position of the leakage point by accumulating the ratio of the flow values by using the distance of the characteristic gas injection point as a known value under the condition that the gas density in the detection pipe is the same.
5. The method for detecting and locating the trace leakage of natural gas as claimed in claim 3, wherein the flow rate integration method comprises: converting the measured mass flow or volume flow into a flow velocity value, and calculating the position of a leakage point through the accumulation of the flow velocity; and correcting the leakage point positioning value by using the distance of the characteristic gas injection point as a known value.
6. The method for detecting and locating the trace leakage of natural gas as claimed in claim 1, wherein the mass flow controller controls the flow rate of the gas so that the gas enters the on-line gas analyzer according to a constant mass flow.
7. The method for detecting and positioning trace leakage of natural gas as claimed in claim 1, wherein the online gas analyzer performs real-time online sampling analysis on gas components in the air, and the sampling frequency is 1 time per second.
8. The method for detecting and positioning the trace leakage of the natural gas as claimed in claim 1 or 7, wherein the online gas analyzer adopts a combination of multiple types of analyzers to realize ppm level concentration detection of multiple components of methane, ethane and C3 gas.
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