GB2517411A - Monitoring pipelines - Google Patents
Monitoring pipelines Download PDFInfo
- Publication number
- GB2517411A GB2517411A GB1312752.7A GB201312752A GB2517411A GB 2517411 A GB2517411 A GB 2517411A GB 201312752 A GB201312752 A GB 201312752A GB 2517411 A GB2517411 A GB 2517411A
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- GB
- United Kingdom
- Prior art keywords
- fluid
- pipeline
- volume
- detecting
- pressure
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
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Classifications
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01S—RADIO DIRECTION-FINDING; RADIO NAVIGATION; DETERMINING DISTANCE OR VELOCITY BY USE OF RADIO WAVES; LOCATING OR PRESENCE-DETECTING BY USE OF THE REFLECTION OR RERADIATION OF RADIO WAVES; ANALOGOUS ARRANGEMENTS USING OTHER WAVES
- G01S15/00—Systems using the reflection or reradiation of acoustic waves, e.g. sonar systems
- G01S15/88—Sonar systems specially adapted for specific applications
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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
- F17D5/06—Preventing, monitoring, or locating loss using electric or acoustic means
-
- 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
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N29/00—Investigating or analysing materials by the use of ultrasonic, sonic or infrasonic waves; Visualisation of the interior of objects by transmitting ultrasonic or sonic waves through the object
- G01N29/02—Analysing fluids
- G01N29/024—Analysing fluids by measuring propagation velocity or propagation time of acoustic waves
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N29/00—Investigating or analysing materials by the use of ultrasonic, sonic or infrasonic waves; Visualisation of the interior of objects by transmitting ultrasonic or sonic waves through the object
- G01N29/14—Investigating or analysing materials by the use of ultrasonic, sonic or infrasonic waves; Visualisation of the interior of objects by transmitting ultrasonic or sonic waves through the object using acoustic emission techniques
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01S—RADIO DIRECTION-FINDING; RADIO NAVIGATION; DETERMINING DISTANCE OR VELOCITY BY USE OF RADIO WAVES; LOCATING OR PRESENCE-DETECTING BY USE OF THE REFLECTION OR RERADIATION OF RADIO WAVES; ANALOGOUS ARRANGEMENTS USING OTHER WAVES
- G01S15/00—Systems using the reflection or reradiation of acoustic waves, e.g. sonar systems
- G01S15/02—Systems using the reflection or reradiation of acoustic waves, e.g. sonar systems using reflection of acoustic waves
- G01S15/04—Systems determining presence of a target
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01S—RADIO DIRECTION-FINDING; RADIO NAVIGATION; DETERMINING DISTANCE OR VELOCITY BY USE OF RADIO WAVES; LOCATING OR PRESENCE-DETECTING BY USE OF THE REFLECTION OR RERADIATION OF RADIO WAVES; ANALOGOUS ARRANGEMENTS USING OTHER WAVES
- G01S15/00—Systems using the reflection or reradiation of acoustic waves, e.g. sonar systems
- G01S15/02—Systems using the reflection or reradiation of acoustic waves, e.g. sonar systems using reflection of acoustic waves
- G01S15/06—Systems determining the position data of a target
- G01S15/08—Systems for measuring distance only
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01S—RADIO DIRECTION-FINDING; RADIO NAVIGATION; DETERMINING DISTANCE OR VELOCITY BY USE OF RADIO WAVES; LOCATING OR PRESENCE-DETECTING BY USE OF THE REFLECTION OR RERADIATION OF RADIO WAVES; ANALOGOUS ARRANGEMENTS USING OTHER WAVES
- G01S15/00—Systems using the reflection or reradiation of acoustic waves, e.g. sonar systems
- G01S15/02—Systems using the reflection or reradiation of acoustic waves, e.g. sonar systems using reflection of acoustic waves
- G01S15/06—Systems determining the position data of a target
- G01S15/08—Systems for measuring distance only
- G01S15/10—Systems for measuring distance only using transmission of interrupted, pulse-modulated waves
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01S—RADIO DIRECTION-FINDING; RADIO NAVIGATION; DETERMINING DISTANCE OR VELOCITY BY USE OF RADIO WAVES; LOCATING OR PRESENCE-DETECTING BY USE OF THE REFLECTION OR RERADIATION OF RADIO WAVES; ANALOGOUS ARRANGEMENTS USING OTHER WAVES
- G01S7/00—Details of systems according to groups G01S13/00, G01S15/00, G01S17/00
- G01S7/52—Details of systems according to groups G01S13/00, G01S15/00, G01S17/00 of systems according to group G01S15/00
- G01S7/52004—Means for monitoring or calibrating
Landscapes
- Engineering & Computer Science (AREA)
- Physics & Mathematics (AREA)
- Radar, Positioning & Navigation (AREA)
- Remote Sensing (AREA)
- General Physics & Mathematics (AREA)
- Acoustics & Sound (AREA)
- Computer Networks & Wireless Communication (AREA)
- Life Sciences & Earth Sciences (AREA)
- Health & Medical Sciences (AREA)
- Chemical & Material Sciences (AREA)
- Analytical Chemistry (AREA)
- Biochemistry (AREA)
- General Health & Medical Sciences (AREA)
- Immunology (AREA)
- Pathology (AREA)
- Mechanical Engineering (AREA)
- General Engineering & Computer Science (AREA)
- Pipeline Systems (AREA)
- Examining Or Testing Airtightness (AREA)
Abstract
An apparatus and method that provide for an accurate and reliable way of remotely determining the presence and/or location of slacks and/or slugs within fluid transporting pipelines is disclosed. A method and apparatus for detecting a volume of a second fluid contained within a first fluid (a slack or slug) in a pipeline is disclosed. The apparatus is associated with a pipeline and has pressure changing means to apply a pressure change signal to the first fluid; pressure sensing means for monitoring the pressure within the first fluid; and a processing means for identifying the reflections of the pressure change signal from an interface between the volume and first fluid and determining the location of an interface between the volume and first fluid. The pressure change signal may be generated by opening or closing a valve, a signal generator, an oscillator or a loudspeaker. The pressure sensing means may be located at the same point in the pipeline as where the pressure change signal is applied, or the pressure sensing means may be located at a different point in the pipeline. The pressure sensing means may be a microphone or a strain gauge. Reflections from discontinuities in the pipeline may also be detected. The time difference between the applied pressure change signal and the identified reflection from the interface may be detected and the location of the interface calculated using the propagation speed of the pressure signal. The propagation speed may be determined by measuring reflections from known discontinuities (e.g. 107) in the pipeline. The temperature, density may be measured of the first fluid.
Description
Monitoriirn pipelines
Technical Field of the Invention
The present invention relates to monitoring pipelines and in particular to a method of determining the presence and location of a slack and/or slug within a pipeline for transporting fluids. Slacks and slugs refer to volumes of different density fluids accumulating within the bulk fluid transported by the pipeline; slacks consist of the vapour phase of the fluid, whereas slugs consist of a non-mixing fluid, often a gas or a different liquid such as oil and water.
Background to the Invention
It is often necessary to convey fluids such as oil and gas over large distance. One method of doing this involves pumping the fluid through a dedicated pipeline system.
Often the fluid is not pure, for example oil may contain dissolved gases, and gas may be contaminated with oil, water and/or sand. In some instances, the pipelines need to deviate vertically, for example over mountain ranges. In such instances negative pressures can occur, and in the case ofoil pipelines, this can cause any dissolved gases to evaporate. On vaporisation, a volume of gas forms within the fluid in the pipeline causing the fluid to separate into the gas phase. This is what is referred to as a slack in an oil pipeline.
The opposite situation can occur in undersea gas pipelines. The oil, water and/or sand can accumulate in the lower-lying parts of the pipeline under gravity. Over time, these can build up to cause blockages. Gases can then build up upstream causing an increase in pressure. When the pressure gets too great, the oil, water and/or sand concentration, or the slug, is forced towards the outlet of the pipeline.
Both slacks and slugs are undesirable since they can cause clogging of pipelines and/or pumps and therefore, unstable and/or reduced flow.
One method of determining the presence of a slack or slug is to measure the flow at two separate points in, or at ends of, the pipeline over a set period of time. Within certain elTor limits, it would be expected that measured flow past each point would be equal. This indicates a regular flow and, therefore, no problems. If the measured flows do not balance this indicates a reduced flow rate and, therefore, a problem. However, it is difficult to confirm what the cause ofthis imbalance is; for instance a reduced flow rate alone can indicate that a leak has occurred or that there is a slack/slug present. As such, false alarms are common.
In some jurisdictions, regulations require that, when a possible leak in a pipeline is detected, the pipeline be shut down for investigation, since a leak can be hazardous to the environment. This shutdown is time consuming and expensive, both in terms of delivery delays and the direct cost of investigation. Additionally, since slacks/slugs also tend to occur in hard to access parts ofthe pipelines, such as high up in mountain ranges where negative pressures can occur, or under the sea, this makes investigation particularly difficult.
It is, therefore, an object of the present invention to provide a method of determining the presence and location of slacks and slugs in pipelines, which at least partially overcomes or alleviates the above problems.
Summary of the Invention
According to a first aspect ofthe present invention there is provided a method of detecting a volume of a second fluid contained within a first fluid in a pipeline, the method comprising the steps of: applying a pressure change signal to the first fluid; monitoring the pressure within the first fluid; identifying reflections of the pressure change signal from an interface between the volume and first fluid; and thereby determining the location of the interface.
The volume of Ihe second fluid may equate to a slack (a fluid of lesser density within a more dense transported fluid) or a slug (a fluid of greater density within a less dense transported fluid). The second fluid may be comprised substantially of a single component or may comprise a mixture ofdifferent components. In pipelines, a slack may comprise a plurality of different soluble gases and a slug may comprise a mixture of liquids and/or a mixture of liquids and solids.
As such, the method according to the present invention provides for an accurate and reliable way of remotely determining the presence andlor location of slacks and/or slugs within fluid transporting pipelines. It may, therefore, be implemented as a stand-alone method or it may be used to compliment prior art methods of measuring flow volumes within pipelines to detect a problem. Using the present method can result in a reduction of the number of false leak alarms when compared with these prior art methods.
The pressure change signal may be applied to the first fluid at a known point along the pipeline. The pressure change signal may be generated by any suitable means including, but not limited to: the opening or closing of a valve; or the operating of a signal generator, an oscillator or a loudspeaker. The pressure change signal may be in the form of a pressure wave.
The pressure within the first fluid is monitored by a pressure sensing means. The pressure may be monitored continuously or intermittently. The pressure sensing means may be located at the same point in the pipeline as where the pressure change signal is applied, or it may be monitored at a different, monitoring point. The pressure sensing means can be any form of pressure sensor including, but not limited to, a microphone or strain gauge.
Additional features may be identified in the monitored pressure signal. Such additional features may include one or more of: the applied pressure change signal; and for a pipeline with discontinuities, reflections of the pressure change signal off the disconthiuities.
The method may include the steps ofdetermining the time difference between the applied pressure change signal and the identified reflection fromthe interface. Where the propagation speed of the pressure signal is known, this method may include the further step of calculating the location of the interface.
The method may also include the steps of determining the time difference for all ofthe identified reflections for a particular signal. These time differences may be used to determine the relative locations ofthe interface and identified discontinuities. Where the location ofthe one or more discontinuities is known, the method may include the further steps of determining the propagation speed of the signal to the known discontinuities.
The method may then involve the steps ofdetermining the location ofthe interface using the determined propagation speed. Alternatively, the location of the interface may be calculated directly from the determined relative location of the interface to a known discontinuity.
Additionally or alternatively, the propagation speed may be directly calculated from the properties of the fluid. Accordingly, in such cases, the method may include the steps of measuring the temperature and/or density of the first fluid.
According to a second aspect of the present invention, there is provided an apparatus associated with a pipeline for detecting a volume of a second fluid contained within a first fluid in a pipeline, the apparatus comprising: pressure changing means to apply a pressure change signal to the fir st fluid; pressure sensing means for monitoring the pressure within the first fluid; and a processing means for identifying the reflections of the pressure change signal from an interface between the volume and first fluid and thereby determining the location of an interface between the volume and first fluid.
The apparatus according to the second aspect of the present invention may comprise any or all of the features of the method according to the first aspect of the present invention, as desired or required.
The apparatus may further comprise a monitoring means. The monitoring means may be used to monitor the times at which the pressure signal is applied to the first fluid and the times at which reflections of the pressure change signal are identified, and, therefore, the time periods.
The processing means may be in communication with the pressure changing means, The processing means may also be in communication with the pressure sensing means and/or the monitoring means. The processing means may be, but is not limited to, a control unit. The control unit may be operable to control the emission ofthe pressure change signal. The control unit may be provided with local or remote user interface means. The control unit may additionally be provided with communication means. The communication means may be operable to communicate information relating to the monitored reflections to a master control system for the pipeline. The communication means may also be operable to enable instructions from the master control system to be transmitted to the control unit. The communication means may comprise any suitable wires or wireless linics.
According to a third aspect of the present invention, there is provided a pipeline fitted with at least one apparatus according to the second aspect of the present invenlion.
The pipeline according to the third aspect ofthe present invention may comprise any or all ofthe features ofthe method and/or apparatus according to the first and second aspects of the present invention respectively, as desired or required.
Detailed Descriøtion of the Invention The method according to the present invention relates to monitoring pipelines and more specifically to determining the presence and location ofa slack and/or slug within a pipeline for transporting fluids.
In order that the invention may be more clearly understood embodiments thereof will now be described, by way of example only, with reference to the accompanying drawings, of which: Fig. 1 is a schematic representation of an oil carrying pipeline which is suitable for implementing a method of detennining the presence and location of a slack within the pipeline according to the present invention; Fig. 2 shows the temporal measurement of the pressure in the oil as would be measured by the pressure sensing means ofthe apparatus shown in Fig. 1; Fig. 3 is a schematic representation of a gas carrying pipeline which is suitable for implementing a method of determining the presence and location of a slug within the pipeline according tO the present invention; Fig. 4 shows the temporal measurement of the pressure in the gas as would be measured by the pressure sensing means ofthe apparatus shown in Fig.3; and Fig. 5 is a schematic representation of an apparatus according to the present invention.
Referring to Fig. 1, there is an oil carrying pipeline 100 extending over a mountain top 110. The pipeline 100 comprises the oil 101 to be transported and a slack 102, where dissolved gases have vaporised out ofthe oil 101 at negative pressure. The vapour tends to gather at the high point of the pipeline since it is lower in density than the oil 101. At each side ofthe slack 102 is a slack interface 103, 130. Apressure changing means 104 is associated with the pipeline 100 and is operable to apply a pressure change signal to the oil at a first point. The pressure change signal can have any suitable form and can be applied by any suitable means including, but not limited to, the opening or closing of a valve, or the operation of a signal generator, oscillator or loudspeaker. A pressure sensor 105 is operable to monitor the pressure within the oil 101 over time, at a second point.
The method according to the present invention involves determining the location ofthe slack interface 103 to thereby determine the location of the slack 102. The first step in the method involves applying a pressure change signal to the oil 101 at a first time, ti.
The pressure change signal propagates through the oil 101 at a speed which is characteristic of the properties of the oil 101. Subsequent to the application of the pressure change signal the method involves monitoring the pressure within the oil 101 using the pressure sensor 105.
Referring to Fig. 2, the temporal measurements ofthe pressure within the oil 101, as measured by the pressure sensor 105, is shown. A first pressure change 201 is detected by the pressure sensor 105 at a second time, t2, attributable to the applied pressure change signal first passing the pressure sensor 105. Once the pressure change signal reaches the interface 103, it is reflected off the interface 103, and travels back in the direction of the pressure sensor 105. As such, at a further time, t3, the pressure sensor detects a second pressure change 202, attributable to the reflection of the pressure change signal off the interface 103.
From the output of the pressure sensor 105, the time difference tdjff between the time at which the pressure change signal was first detected, t2, and the time at which the reflection of the pressure change signal off the interface was detected, t3, can be determined. If the speed of propagation of the pressure change signal is known, tdf if can be used to calculate the location of the interface 103 and hence the location of the slack 102.
The speed ofpropagation can be calculated using known properties of the oil 101, such as temperature, density and/or bulk modulus, and/or from modelling the flow of fluid through pipelines. In such implementations, the method can comprise the step of measuring the necessary properties ofthe oil 101 via suitable means 106 associated with the pipeline. The measured properties can then be used to calculate the speed of 20. propagation of a pressure change signal through the oil 101.
Alternatively, or additionally, the method may involve using known discontinuities in the pipeline 100 to determine the speed ofpropagation. Referring back to Fig. 1, the pipeline 100 has a known discontinuity 107. The method again comprises the step of applying a pressure change signal to the oil 101 at a first time, ti, and monitoring the pressure within the oil using the pressure sensor 105. Referring again to Fig. 2, in addition to the first pressure change signal 201 and the second pressure change 202, as the discontinuity 107 causes a partial reflection of the fressure change signal 201, the pressure sensor 105 will additionally detect a third pressure change 203 attributable to the partial reflection of the pressure change signal 201 off the discontinuity 107. The third pressure change 203 is detected by the pressure sensor 105 at a subsequent time, t4.
The time difference tdlm between times t4 and t2 can then be used to calculate an average speed of propagation of the pressure change signal from the known location of the discontinuity 107. This determined average speed can then be used to determine the absolute location the interface 103 from the time difference tdjff. Alternatively, or additionally, the ratio of tdlfO:tdlff can be used to determine a relative distance of the interface 103 from the discontinuity 107.
Fig. 3 and 4 show the equivalent situation for a gas carrying pipeline 300, where a slug 302 has formed in the gas 301 intended to be transported. The location of a slug interface 303 can be determined in the same way as for the slack interface 103. Fig. 4 again identifies the pressure change signal 201, at a second time, t2, attributable to the applied pressure change signal initially passing the pressure sensor. Reflection402 ofthe pressure change signal off the interface 303 is detected at a time t3. A partial reflection 203 of the pressure change signal off a discontinuity 107 is identified at a time t4. As before, the time difference tdjff between times t3 and t2 can be used to calculate the location ofthe interface 303, if the speed is known. Similarly, the ratio oftd:tdlg can be used to calculate an average speed of propagation and either an absolute or relative location of the interface 303.
This method of determining the location of a slack or slug within a fluid carrying pipeline is advantageous since it is easy to implement, accurate and reliable. Since it can be accurately used to identif5, the presence of a slack or slug, it can considerably reduce the number of false alarms and subsequent shutdowns ofpipelines, which are a result of suspected leaks, saving time, money and resources.
Referring to figure 5, according to another aspect ofthe present invention, there is provided an apparatus associated with a fluid carrying pipeline for detecting the presence and location of a slack or slug within the pipeline. The apparatus comprises a pressure changing means 501. The apparatus further comprises a pressure sensor 502 that is operable to monitor the pressure within the fluid, The pressure changing means 501 might be, but is not limited to, a valve, signal generator, oscillator or loudspeaker. The pressure sensor 502 might be, but is not limited to, a microphone or strain gauge.
A processing means 503 connects to the signal generator 501 and pressure sensor 502, and is operable to identifS' the reflections of the pressure change signal off a slack/slug interface and/or discontinuities in the pipeline. The processing means 503 can thereby implement the above method of determining the location of a slack/slug interface within a pipeline.
The processing means 503 is connected to a control unit 505 which is operable to control the emission of a pressure change signal. A user interface 504, which may be local or remote, is connected to the control unit 505 to control the timing of such emissions and subsequently output information relating to the pressure monitoring and/or the location of any slacks/slugs. A communication means 506, which may be wired or wireless, is associated with the control unit 505, which links the system 500 to a master control system 507. Ultimately, all of the information relating to the monitored reflections can be sent to the master control system 507. Similarly, the master control system 507 may control operation of the system 500. This facilitates monitoring of a large pipeline network or sub network from a single master control system 507.
The above embodiments are described by way ofexample only. Many variations are possible without departing from the scope ofthe invention as defined in the appended claims.
Claims (9)
- Claims I. A method of detecting a volume of a second fluid contained within a first fluid in a pipeline, the method comprising the steps of: applying a pressure change signal to the first fluid: monitoring the pressure within the first fluid; identifying reflections of the pressure change signal from an interface between the volume and first fluid; and thereby determining the location of the interface.
- 2. A method of detecting a volume of a second fluid contained within a first fluid in a pipeline according to claim 1. wherein the pressure change signal is applied to the first fluid at a known point along the pipeline.
- 3. A method of detecting a volume of a second fluid contained within a first fluid inI0 a pipeline according to claim 1 or 2, wherein the pressure change signal is (0 generated by any of: the opening or closing oN vah'e; or the operating oft signal r generator, an oscillator or a loudspeaker.
- 4. A method of detecting a volume of a second fluid contained within a first fluid in a pipeline according to any preceding claim, wherein the pressure change signal is in the form of a pressure wave.
- 5. A method of detecting a volume of a second fluid contained within a first fluid in a pipeline according to any preceding claim, wherein the pressure within the first fluid is monitored by a pressure sensing means.
- 6. A method of detecting a volume of a second fluid contained within a first fluid in a pipeline according to claim 5, wherein the pressure is monitored continuously or intermittently.
- 7. A method of detecting a volume of a second fluid contained within a first fluid in a pipeline according to claim 5 or 6, wherein the pressure sensing means is located at the same point in the pipeline as where the pressure change signal is applied.
- 8. A method of detecting a volume of a second fluid contained within a first fluid in a pipehne according to claim 5 or 6. wherein the pressure sensing means is located at a different point in the pipeline to where the pressure change signal is applied, at a monitoring point.
- 9. A method of detecting a volume of a second fluid contained within a first fluid in a pipeline according to any of claims 5 to 8, wherein the pressure sensing means is a microphone or a strain gauge.I10. A method oldetecting a volume of a second fluid contained within a first fluid inCDr a pipeline according to any of claims S to 9, wherein additional features are identified in the monitored pressure signal.11. A method of detecting a volume of a second fluid contained within a first fluid in a pipeline according to claim 10, wherein the additional features include one or more of: the applied pressure change signal; and for a pipeline with discontinuities, reflections of the pressure change signal off the discontinuities.12. A method of detecting a volume of a second fluid contained within a first fluid in a pipeline according to any preceding claim, further comprising the steps of determining the time difference between the applied pressure change signal and the identified reflection from the interface.13. A method of detecting a volume of a second fluid contained within a first fluid in a pipeline according to claim 12, further comprising the step of calculating the location of the interface if the propagation speed of the pressure signal is known.14. A method of detecting a volume of a second fluid contained within a first fluid in a pipeline according to 12 or 13. further comprising the steps of detemilning the time difference for all of the identified reflections br a particular signal.15. A method of detecting a volume of a second fluid contained within a first fluid in a pipehnc according to claim 14, wherein the time differences arc used to deteimine the relative locations of the interface and identified discontinuities.16. A method oldetecting a volumeofa second fluid contained within a first fluid in a pipeline according to claim 15, further comprising the steps of determining the propagation speed of the signal to the known discontinuities. (0r 17. A method of detecting a volume of a second fluid contained within a first fluid in a pipeline according to claim 16, further comprising the steps of determining the location of the intcrfacc using the dctcrmincd propagation speed.18. A nicthod of dctecting a volume of a second fluid contained within a first fluid in a pipeline according to claim 17, further comprising calculating the location of the interface directly from the determined relative location of the interface to a known discontinuity.19. A method of detecting a volume of a second fluid contained within a first fluid in a pipeline according to claim any preceding claim, wherein the propagation speed is directly calculated from the properties of the fluid.20. A method of detecting a volume of a second fluid contained within a first fluid in a pipeline according to claim any preceding claim, further comprising the steps of measuring the temperature and/or density of the first fluid.21. An apparatus associated with a pipeline for detecting a volume of a second fluid contained within a first fluid in a pipeline, the apparatus comprising: pressure changing means to apply a pressure change signal to the first fluid; pressure sensing means for monitoring the pressure within the first fluid; and a processing means for identifying the reflections of the pressure change signal from an interface between the volume and first fluid and thereby determining the location of an interface between the volume and first fluid.22. An apparatus associated with a pipeline for detecting a volume of a second fluid 0 contained within a first fluid in a pipeline according to claim 21, further (0 comprising a monitoring means. r23. An apparatus associated with a pipeline for detecting a volume of a second fluid contained within a first fluid in a pipeline according to claim 22, wherein the monitoring means is used to monitor the times at which the pressure signal is applied to the first fluid and the times at which rcflections of the pressure change signal are identified. and. therefore. the time periods.24. An apparatus associated with a pipeline for detecting a volume of a second fluid contained within a first fluid in a pipeline according to any of claims 21 to 23, wherein the processing means is in communication with the pressure changing means.25. An apparatus associated with a pipeline for detecting a volume of a second fluid contained within a first fluid in a pipeline according to claim 24, wherein the processing means is also in communication with the pressure sensing means and/or the monitoring means.26. An apparatus associated with a pipeline for detecting a volume of a second fluid contained within a first fluid in a pipeline according to any of claims 21 to 25, wherein the processing means is a control unit.27. An apparatus associated with a pipeline for detecting a volume of a second fluid contained within a first fluid in a pipeline according to claim 26, wherein the control unit is operable to control the emission of the pressure change signal.i'-.. 28. An apparatus associated with a pipeline for detecting a volume of a second fluid contained within a first fluid in a pipeline according to claim 26 or 27, wherein (0 r the control unit is provided with local or remote user interface means.29. An apparatus associated with a pipeline for detecting a volume of a second fluid contained within a first fluid in a pipeline according to any of claims 26 to 28, wherein the control unit is additionally provided with communication means.30. An apparatus associated with a pipeline for detecting a volume of a second fluid contained within a first fluid in a pipeline according to claim 29, wherein the communication means is operable to communicate infoirnation relating to the monitored reflections to a master control system for the pipeline.31. An apparatus associated with a pipeline for detecting a volume of a second fluid contained within a first fluid in a pipeline according to claim 29 or 30. wherein the communication means is operable to enable instructions from the master control system to be transmitted to the control unit.32. An apparatus associated with a pipeline for detecting a volume of a second fluid contained within a first fluid in a pipeline according to ally of claims 29 to 31, wherein the communication means comprises any suitable wired or wireless links.33. A pipeline fitted with at least one apparatus according to any one of claims 21 to 32. (0 r
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| GB1312752.7A GB2517411A (en) | 2013-07-17 | 2013-07-17 | Monitoring pipelines |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| GB1312752.7A GB2517411A (en) | 2013-07-17 | 2013-07-17 | Monitoring pipelines |
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| Publication Number | Publication Date |
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| GB201312752D0 GB201312752D0 (en) | 2013-08-28 |
| GB2517411A true GB2517411A (en) | 2015-02-25 |
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| GB1312752.7A Withdrawn GB2517411A (en) | 2013-07-17 | 2013-07-17 | Monitoring pipelines |
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| GB (1) | GB2517411A (en) |
Cited By (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2019096854A1 (en) | 2017-11-15 | 2019-05-23 | Eni S.P.A. | System and method of remote monitoring of the integrity of pressurised pipes by means of vibroacoustic sources |
| WO2020134702A1 (en) * | 2018-12-28 | 2020-07-02 | 大连理工大学 | Method for pressure pipe blocking status detection using pulse pressure wave |
| US11953161B1 (en) | 2023-04-18 | 2024-04-09 | Intelcon System C.A. | Monitoring and detecting pipeline leaks and spills |
Families Citing this family (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN117628417B (en) * | 2024-01-25 | 2024-03-26 | 深圳市晶湖科技有限公司 | Intelligent safety control system for gas field |
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2013
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| US4935884A (en) * | 1988-04-28 | 1990-06-19 | Champlin Electronics, Inc. | Sonic pipe length detector |
| JPH03282290A (en) * | 1990-03-29 | 1991-12-12 | Osaka Gas Co Ltd | Method for detecting joint part of underground pipe |
| EP0465032A1 (en) * | 1990-06-27 | 1992-01-08 | The British Petroleum Company P.L.C. | Method for monitoring acoustic emissions |
| US5295120A (en) * | 1990-12-26 | 1994-03-15 | Westinghouse Electric Corp. | Hermetically sealed ultrasonic transducer system |
| EP0610073A1 (en) * | 1993-02-03 | 1994-08-10 | Tokyo Gas Co., Ltd. | System for acoustically measuring the length of a pipe |
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| JPH10132542A (en) * | 1996-10-30 | 1998-05-22 | Tokyo Gas Co Ltd | Reflection Signal Judgment Method in Ultrasonic Pipeline Inspection System |
| JP2002196074A (en) * | 2000-12-25 | 2002-07-10 | Koden Electronics Co Ltd | Device for inspecting inside of conduit line |
| JP2003207329A (en) * | 2002-01-11 | 2003-07-25 | Osaka Gas Co Ltd | Joint detection method for piping |
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Cited By (3)
| Publication number | Priority date | Publication date | Assignee | Title |
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| WO2019096854A1 (en) | 2017-11-15 | 2019-05-23 | Eni S.P.A. | System and method of remote monitoring of the integrity of pressurised pipes by means of vibroacoustic sources |
| WO2020134702A1 (en) * | 2018-12-28 | 2020-07-02 | 大连理工大学 | Method for pressure pipe blocking status detection using pulse pressure wave |
| US11953161B1 (en) | 2023-04-18 | 2024-04-09 | Intelcon System C.A. | Monitoring and detecting pipeline leaks and spills |
Also Published As
| Publication number | Publication date |
|---|---|
| GB201312752D0 (en) | 2013-08-28 |
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