GB2475225A - A method for monitoring and/or maintaining the condition of a structure such as a pipeline - Google Patents

A method for monitoring and/or maintaining the condition of a structure such as a pipeline Download PDF

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Publication number
GB2475225A
GB2475225A GB0919035A GB0919035A GB2475225A GB 2475225 A GB2475225 A GB 2475225A GB 0919035 A GB0919035 A GB 0919035A GB 0919035 A GB0919035 A GB 0919035A GB 2475225 A GB2475225 A GB 2475225A
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Prior art keywords
signal
location
condition
received
pipeline
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GB0919035A
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GB0919035D0 (en
Inventor
Wayne Rudd
Laurie Linnett
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Individual
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Individual
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Priority to GB0919035A priority Critical patent/GB2475225A/en
Publication of GB0919035D0 publication Critical patent/GB0919035D0/en
Publication of GB2475225A publication Critical patent/GB2475225A/en
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    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01B—MEASURING LENGTH, THICKNESS OR SIMILAR LINEAR DIMENSIONS; MEASURING ANGLES; MEASURING AREAS; MEASURING IRREGULARITIES OF SURFACES OR CONTOURS
    • G01B17/00—Measuring arrangements characterised by the use of infrasonic, sonic or ultrasonic vibrations
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01B—MEASURING LENGTH, THICKNESS OR SIMILAR LINEAR DIMENSIONS; MEASURING ANGLES; MEASURING AREAS; MEASURING IRREGULARITIES OF SURFACES OR CONTOURS
    • G01B17/00—Measuring arrangements characterised by the use of infrasonic, sonic or ultrasonic vibrations
    • G01B17/04—Measuring arrangements characterised by the use of infrasonic, sonic or ultrasonic vibrations for measuring the deformation in a solid, e.g. by vibrating string
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01M—TESTING STATIC OR DYNAMIC BALANCE OF MACHINES OR STRUCTURES; TESTING OF STRUCTURES OR APPARATUS, NOT OTHERWISE PROVIDED FOR
    • G01M5/00—Investigating the elasticity of structures, e.g. deflection of bridges or air-craft wings
    • G01M5/0025—Investigating the elasticity of structures, e.g. deflection of bridges or air-craft wings of elongated objects, e.g. pipes, masts, towers or railways
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01M—TESTING STATIC OR DYNAMIC BALANCE OF MACHINES OR STRUCTURES; TESTING OF STRUCTURES OR APPARATUS, NOT OTHERWISE PROVIDED FOR
    • G01M5/00—Investigating the elasticity of structures, e.g. deflection of bridges or air-craft wings
    • G01M5/0033—Investigating the elasticity of structures, e.g. deflection of bridges or air-craft wings by determining damage, crack or wear
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01M—TESTING STATIC OR DYNAMIC BALANCE OF MACHINES OR STRUCTURES; TESTING OF STRUCTURES OR APPARATUS, NOT OTHERWISE PROVIDED FOR
    • G01M5/00—Investigating the elasticity of structures, e.g. deflection of bridges or air-craft wings
    • G01M5/0041—Investigating the elasticity of structures, e.g. deflection of bridges or air-craft wings by determining deflection or stress
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01M—TESTING STATIC OR DYNAMIC BALANCE OF MACHINES OR STRUCTURES; TESTING OF STRUCTURES OR APPARATUS, NOT OTHERWISE PROVIDED FOR
    • G01M5/00—Investigating the elasticity of structures, e.g. deflection of bridges or air-craft wings
    • G01M5/0066—Investigating the elasticity of structures, e.g. deflection of bridges or air-craft wings by exciting or detecting vibration or acceleration
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01M—TESTING STATIC OR DYNAMIC BALANCE OF MACHINES OR STRUCTURES; TESTING OF STRUCTURES OR APPARATUS, NOT OTHERWISE PROVIDED FOR
    • G01M99/00—Subject matter not provided for in other groups of this subclass
    • 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
    • G01N29/04—Analysing solids
    • 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
    • G01N29/04—Analysing solids
    • G01N29/11—Analysing solids by measuring attenuation 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
    • G01N29/36—Detecting the response signal, e.g. electronic circuits specially adapted therefor
    • 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
    • G01N29/44—Processing the detected response signal, e.g. electronic circuits specially adapted therefor
    • G01N29/46—Processing the detected response signal, e.g. electronic circuits specially adapted therefor by spectral analysis, e.g. Fourier analysis or wavelet analysis
    • 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
    • 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
    • G01S15/32—Systems for measuring distance only using transmission of continuous waves, whether amplitude-, frequency-, or phase-modulated, or unmodulated
    • G01S15/36—Systems for measuring distance only using transmission of continuous waves, whether amplitude-, frequency-, or phase-modulated, or unmodulated with phase comparison between the received signal and the contemporaneously transmitted signal
    • 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
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N2291/00—Indexing codes associated with group G01N29/00
    • G01N2291/04—Wave modes and trajectories
    • G01N2291/048—Transmission, i.e. analysed material between transmitter and receiver
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N2291/00—Indexing codes associated with group G01N29/00
    • G01N2291/26—Scanned objects
    • G01N2291/263—Surfaces
    • G01N2291/2634—Surfaces cylindrical from outside

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  • Physics & Mathematics (AREA)
  • General Physics & Mathematics (AREA)
  • Engineering & Computer Science (AREA)
  • Radar, Positioning & Navigation (AREA)
  • Remote Sensing (AREA)
  • Analytical Chemistry (AREA)
  • Pathology (AREA)
  • Health & Medical Sciences (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Chemical & Material Sciences (AREA)
  • Acoustics & Sound (AREA)
  • Biochemistry (AREA)
  • General Health & Medical Sciences (AREA)
  • Immunology (AREA)
  • Computer Networks & Wireless Communication (AREA)
  • Aviation & Aerospace Engineering (AREA)
  • Signal Processing (AREA)
  • Mathematical Physics (AREA)
  • Spectroscopy & Molecular Physics (AREA)
  • Testing Resistance To Weather, Investigating Materials By Mechanical Methods (AREA)
  • Pipeline Systems (AREA)
  • Investigating Or Analyzing Materials By The Use Of Ultrasonic Waves (AREA)

Abstract

The method of monitoring comprises transmitting an acoustic signal 320 in a wall of a pipeline 110 so as to provide a signal front occurring at a location in the pipeline. A received signal 340 associated with the transmitted signal is received and from it one or more signal characteristics of the received signal are used to determine a change in condition of the structure at the location of the signal front (350, fig 3c). The condition of the pipeline can be maintained by transmitting a maintenance signal in a structure. Again, the maintenance signal comprises a locatable signal front, whereby the signal front occurs at a location in the structure to be maintained. The signal front can be configured to reduce or remove the chance of a change in condition of the structure at that location in the pipeline, such as a build up, corrosion, or other change, such as stress or deformation.

Description

Method for monitoring and/or maintenance and associated apparatus
Technical Field
The invention relates to methods for monitoring and/or maintenance and associated apparatus. In particular, but not exclusively, the invention relates to methods for monitoring and/or maintenance of a structure, for example a pipeline, such as an oil and gas exploration, production or transportation pipeline.
Background
In the field of oil and gas exploration, transportation and/or production it can be useful to monitor and/or maintain structures, such as pipelines. The condition of such structures can change during use, which may have an adverse affect on their performance. For example, corrosion may occur which may result in damage or loss of material being communicated through a pipeline. Similarly, deposition within a pipeline may occur, which may result in a region of restriction. In addition or alternatively, some mechanical change may occur due to some form of stress in a structure, which may result in deformation.
In each case, it can be useful to identify the onset of such problems at an early stage so that preventative measures can take place before needing to repair or replace a structure. Irrespective of whether or not problems are identified, it can be useful to try to maintain the condition of a structure. This can extend the lifetime of a structure (e.g. a pipeline).
Summary
According to a first aspect of the invention there is provided a method for monitoring the condition of a structure, the method comprising: transmitting a signal in a structure, the signal providing a signal front occurring at a location in the structure; receiving a received signal, the received signal associated with the transmitted signal; determining one or more signal characteristics of the received signal to determine a change in condition of the structure at the location of the signal front.
The signal characteristic may comprise a difference between the received signal and an expected received signal. Such an expected received signal may be associated with a particular condition of a structure at a location of a signal front.
The signal characteristic may comprise a difference between the received signal and one or more further received signals (e.g. a plurality of further received signals). The further received signals may be associated with different locations of signal front in a structure. The method may comprise transmitting a plurality of signals to provide the received signal and the one or more further received signals. The method may comprise transmitting a plurality of signals in a structure so as to provide a plurality of signal fronts occurring at locations in the structure, which may be different locations.
The transmitting of the signal may provide a movable signal front occurring at a location in the structure. The movable signal front may be movable long the length of the structure. The movable signal front may be movable around a portion of the structure, such as around a perimeter portion or circumferential portion of a pipeline, or the like.
The signal front may provide a region of changing pressure, such as oscillating pressure, in the structure. The signal front may provide a region of maximum changing pressure in the structure.
The signal may comprise two or more frequency components. The signal front may be provided by a complex anti-node of the two of more frequency components. The signal may be configured to provide a standing wave. The signal front may be considered to be a movable signal front of a standing wave.
The signal front may be movable by changing one or more of the frequency components of the signal. The signal front may be movable by using dispersive effects of one or more of the frequency components.
The determined difference between the received signal and the expected received signal may be a determined difference in decay, or rate of decay.
The method may comprise moving the signal front along some or all of the structure.
This may permit the condition of the structure at various locations or intervals to be determined. The method may comprise moving the location of the signal front at regular or irregular intervals along and/or around the structure (e.g. along the length, or around a perimeter/circumference).
The method may comprise associating a change in condition of the structure at a particular interval with a determined difference at that interval. The method may comprise associating a change in condition of the structure at a particular interval with a largest determined difference at that interval, compared to other intervals.
The method may comprise moving the signal front when little or no difference (e.g. no difference beyond a particular threshold) is observed between the received signal and the expected received signal for a particular interval.
The method may comprise associating the change in the structure with a region of deposition, such as wax, asphaltenes, hydrates, or the like. The method may comprise associating the change in the structure with a region of corrosion. The method may comprise associating the change in the structure with a region of stress or deformation.
The expected received signal may be a derived from the results of a transmitted signal in the structure at a particular time, such as when the structure is new, or newly installed, at sometime earlier in the life of the structure, or the like. The expected received signal may be a derived from a simulated expected signal (e.g. based on the material properties of the structure).
The method may comprise transmitting the signal in the structure, and providing two or more signal fronts occurring at two or more locations in the structure. The two or more signals fronts may occur simultaneously.
The structure may be a conduit, such as a pipeline, or container, support structure (e.g. a rolled steel joist (RSJ)), etc. The structure may be a framework, such as a building or construction framework.
The transmitted signal may be considered to be a local monitoring signal. Similarly, the received signal may be considered to be a received local monitoring signal. The expected received signal may be considered to be an expected received local monitoring signal.
The method may comprise monitoring the condition of the structure by transmitting a global monitoring signal in the structure. The global monitoring signal may comprise one or more frequency components. The method may comprise receiving the global monitoring signal and determining a difference between the received global monitoring signal and an expected received global monitoring signal. The determined difference may be associated with a change in condition of the structure, such as a global change in the condition of the structure.
The expected received global monitoring signal may be associated with a particular condition of the structure. The expected received global monitoring signal may be derived from the results of a transmitted global monitoring signal in the structure at a particular time, such as when the structure is new, or newly installed, etc. The expected received global monitoring signal may be derived from a simulated expected global monitoring signal (e.g. based on the material properties of the structure).
The determined difference between the received global monitoring signal and the expected received global monitoring signal may be a determined difference in decay, or rate of decay.
The method may comprise monitoring the condition of the structure from time to time, such as minutely, hourly, daily, weekly, monthly, or the like.
The method may comprise monitoring the condition of the structure from time to time using the global monitoring signal, and upon observing a change in condition of the structure, using the local monitoring signal to determine the location of the change in condition.
The method may comprise communicating a maintenance signal in the structure. The maintenance signal may provide a signal front, such as a locatable or movable signal front. The signal front may be provided at a location in the structure to be maintained.
For example, the method may comprise communicating a maintenance signal in the structure in response to a determined change in condition, or a determined change in condition at one or more locations or intervals.
The maintenance signal may be configured to reduce or remove the chance of deposit or corrosion at that location in the structure.
The method may comprise agitating the structure. The method may comprise agitating the structure or material in the structure at, or around, the location of a determined change in condition. The agitating may be provided by moving the location of the signal front, such as moving the location about an interval at which a determined change in condition has occurred.
The method may comprise heating the structure at a particular location or interval.
The signal front may provide the heating of the structure. The maintenance signal may comprise an electromagnetic signal.
The method may comprise heating and agitating.
The length of the structure may be greater than 100 meters, or greater than 500 meters. The length may be greater than 1,000 meters. The structure may be up to 6,000 meters (i.e. 6 km).
According to a second aspect of the invention the is provided apparatus for monitoring the condition of a structure, the apparatus comprising a transmitter configured to transmit a signal in a structure, such a signal configured to provide a signal front at a location in a structure; a receiver configured to receive a received signal, such a received signal being associated with the transmitted signal; wherein the apparatus is configured to determine one or more signal characteristics of a received signal to determine a change in condition of a structure at the location of the signal front.
The signal characteristic may comprise a difference between a received signal and an expected received signal. Such an expected received signal may be associated with a particular condition of a structure at a location of a signal front.
The characteristic may comprise the difference between a received signal and one or more further received signals. The further received signals may be associated with different locations of signal front in the structure.
A transmitted signal may provide a movable signal front occurring at a location in a structure. A movable signal front may be movable long a length of a structure. The movable signal front may be movable around a portion of the structure, such as around a perimeter portion or circumferential portion of a pipeline, or the like. A signal front may provide a region of changing pressure, such as oscillating pressure, in a structure. The signal front may provide a region of maximum changing pressure in the structure.
The apparatus may be configured to transmit a signal comprising two or more frequency components. A signal front may be provided by a complex anti-node of two of more frequency components. A signal front may be provided by a complex node of two of more frequency components. The apparatus may be configured to provide a signal as a standing wave. The apparatus may be configured to provide movable signal front of a standing wave.
The apparatus may be configured to change one or more of the frequency components of a signal in order to move the location of a signal front. The apparatus may be configured to use dispersive effects of one or more of the frequency components.
The apparatus may be configured to move a signal front along some or all of a structure. This may determine the condition of the structure at various locations. The apparatus may be configured to move a location of a signal front at regular intervals of a structure.
The apparatus may be configured to associate a change in condition of a structure at a particular interval with a determined difference at that interval. The apparatus may be configured to associate a change in condition of a structure at a particular interval with a largest determined difference at that interval, compared to other intervals.
A change in a structure may be associated with a region of deposition, such as wax, asphaltenes, hydrates, or the like. A change in the structure may be associated with a region of corrosion. A change may be associated with a region or stress or deformation.
An expected received signal may be derived from results of a transmitted signal in a structure at a particular time, such as when the structure is new, newly installed, etc. The apparatus may be configured to store expected received signals (e.g. store for subsequent comparison).
An expected received signal may be derived from a simulated expected signal (e.g. based on the material properties of the structure).
The structure may be a conduit, such as a pipeline, or container, support structure (e.g. a rolled steel joist (IRSJ)), etc. The structure may be a framework, such as a building or construction framework.
The transmitted signal may be considered to be a local monitoring signal. Similarly, the received signal may be considered to be a received local monitoring signal. The expected received signal may be considered to be an expected received local monitoring signal.
The apparatus may be configured to monitor the condition of a structure by transmitting a global monitoring signal in a structure. Such a global monitoring signal may comprise one or more frequency components. The apparatus may be configured to receive a global monitoring signal and determine a difference between a received global monitoring signal and an expected received global monitoring signal. A determined difference may be associated with a change in condition of a structure.
An expected received global monitoring signal may be a derived from the results of a transmitted a global monitoring signal in the structure at a particular time, such as when the structure is new, newly installed, etc. An expected received global monitoring signal may be a derived from a simulated expected global monitoring signal (e.g. based on the material properties of the structure).
The apparatus may be configured to monitor the condition of the structure from time to time, such as minutely, hourly, daily, weekly, monthly, or the like.
The apparatus may be configured to monitor the condition of a structure from time to time using a global monitoring signal, and upon observing a change in condition of a structure the apparatus may be configured to use a local monitoring signal to determine a location of a change in condition.
The apparatus may be configured to agitating a structure or material in a structure at, or around, a location of an observed change in condition. The agitating may be provided by moving the location of the signal front, such as moving the location about an interval at which an observed change in condition has occurred.
The apparatus may be configured to heat the structure at a particular interval or location.
The apparatus may comprise a user interface configured to provide a visual output.
The user interface may be provided by a liquid crystal display, light emitting diode, or the like.
The apparatus may further comprise a structure.
The apparatus may be configured to be one or more of: mountable, demountable, attachable, detachable, fixably attachable, retrofit with a structure.
The structure may be an oil and gas transportation pipeline. The structure may be an oil and gas exploration pipeline. The structure may be an oil and gas production pipeline.
The apparatus may be configured to transmit and/or receive acoustic signals. The apparatus may be configured to create a pressure signal in a conduit. The apparatus may be configured to transmit and/or receive electromagnetic signals.
According to a third aspect of the invention there is provided a method for monitoring the condition of a structure, the method comprising transmitting a local monitoring signal in a structure, the local monitoring signal comprising a moveable signal front, the signal front occurring at a location in the structure; receiving the local monitoring signal and observing a difference between the received local monitoring signal and an expected received local monitoring signal, and associating that difference with a change in condition of the structure at the location of the signal front.
According to a fourth aspect of the invention the is provided apparatus for monitoring the condition of a structure, the apparatus comprising a transmitter configured to transmit a local monitoring signal in a structure, such a local monitoring signal comprising a moveable signal front, such a signal front configured to occur at a location in the structure; a receiver configured to receive a local monitoring signal and observe a difference between the received local monitoring signal and an expected received local monitoring signal; the apparatus configured to associate an observed difference with a change in condition of a structure at a location of a signal front.
According to a fifth aspect of the invention there is provided a method for maintaining a structure, the method comprising: transmitting a maintenance signal in a structure, the maintenance signal comprising a locatable signal front, the signal front occurring at a location in the structure to be maintained; the signal front configured to reduce or remove the chance of a change in condition of the structure at that location in the structure.
The change in condition may be deposition, corrosion, stress, deformation, etc. The maintenance signal may comprise more than may comprise two or more frequency components. The signal front may be provided by a complex anti-node of the two of more frequency components. The signal front may be provided by a complex node of the two of more frequency components. The maintenance signal may be configured to provide a standing wave. The signal front may be considered to be a locatable or movable signal front of a standing wave.
The signal front may be movable or locatable by changing one or more of the frequency components of the local monitoring signal. The signal front may be movable by using dispersive effects of one or more of the frequency components.
The method may comprise maintaining the structure at regions of deposition or potential deposition, such as wax, asphaltenes, hydrates, or the like. The method may comprise maintaining the structure at regions of corrosion, or potential corrosion, such as ablation, oxidation, etc. The method may comprise heating the structure at a location using the maintenance signal.
The method may comprise communicating a maintaining signal for the structure from time to time, such as minutely, hourly, daily, weekly, monthly, or the like.
According to a sixth aspect of the invention the is provided apparatus for maintaining a structure, the apparatus comprising: a transmitter configured to transmit a maintenance signal in a structure, such a maintenance signal comprising a locatable signal front, such a signal front configured to occur at a location in a structure; the apparatus configured to provide a signal front configured to reduce or remove the chance of change in condition of a structure at a location in a structure.
The apparatus may further comprise a structure.
The apparatus may be configured to be one or more of: mountable, demountable, attachable, detachable, fixably attachable, retrofit with a structure.
The structure may be an oil and gas transportation structure. The structure may be an oil and gas exploration pipeline. The structure may be an oil and gas production pipeline.
According to an seventh aspect of the invention the is provided apparatus for monitoring the condition of a structure, the apparatus comprising a transmitter configured to transmit a local monitoring signal in a structure, such a local monitoring signal configured to provide a signal front at a location in a structure; a receiver configured to receive a received local monitoring signal, such a received local monitoring signal being associated with the local monitoring signal; wherein the apparatus is configured to determine a difference between a received local monitoring signal and an expected received local monitoring signal, such an expected received local monitoring signal being associated with a particular condition of a structure; and the apparatus further configured to associate a difference between a received local monitoring signal and an expected received local monitoring signal with a change in condition of a structure at a location of a signal front.
According to a eighth aspect of the invention the is provided a method for monitoring the condition of a structure, the method comprising transmitting a local monitoring signal in a structure, the local monitoring signal configured to provide a signal front at a location in a structure; receiving a received local monitoring signal, the received local monitoring signal being associated with the local monitoring signal; wherein determining a difference between a received local monitoring signal and an expected received local monitoring signal, the expected received local monitoring signal being associated with a particular condition of a structure; and associating a determined difference with a change in condition of a structure at the location of a signal front.
According to a ninth aspect of the invention the is provided a method for monitoring the condition of a structure, the method comprising transmitting a local monitoring signal in a structure, the local monitoring signal configured to provide a signal front at a location in a structure; receiving a received local monitoring signal, the received local monitoring signal being associated with the local monitoring signal; wherein determining a difference between a received local monitoring signal and a further received local monitoring signal, the further received local monitoring signal being associated with a particular local monitoring signal providing a signal front at a different location in the structure; and associating a determined difference with a change in condition of a structure at the location of a signal front.
According to tenth aspect of the invention there is a structure comprising any of the features of the second, fourth, sixth, or seventh aspects.
According to a eleventh aspect there is a conditioning monitoring device comprising any of the features of the second, fourth, sixth or seventh aspects.
According to a twelfth aspect there is a maintenance device comprising any of the features of the second, fourth, sixth or seventh aspects.
According to a thirteenth aspect of the invention there is provided a computer program product, provided on a computer readable medium, the computer program product configured to provide the method according any of the features of the first, third, fifth, eighth or ninth aspects.
The invention includes one or more corresponding aspects, embodiments or features in isolation or in various combinations whether or not specifically stated (including claimed) in that combination or in isolation. For example, it will readily be appreciated that features of the first aspect may be used with features of the second, third, fourth, fifth, sixth aspects, etc. and vice versa, without the need to recite again every possible permutation here.
Corresponding means for performing one or more of the discussed functions are also within the present disclosure. It will be appreciated that one or more embodiments/aspects may be useful in monitoring the condition of a pipeline.
The above summary is intended to be merely exemplary and non-limiting.
Brief description of the figures
These and other aspects will now be described, by way of example only, with reference to the accompanying drawings, in which: Figure 1 shows an example of a pipeline, and plots of a global monitoring signal and a received global monitoring signal; Figure 2 shows an example of a pipeline comprising a deposit, and plots of an expected received global monitoring signal and a received global monitoring signal; Figure 3 shows an example of a pipeline comprising a deposit, a plot of a local monitoring signal providing a signal front, and an associated pressure in a pipeline; Figure 4 shows an exemplary local monitoring signal in a pipeline and simplified representations of associated received local monitoring signals; Figure 5 shows an example of a maintenance signal; Figure 6 shows an example of a pipeline comprising corrosion; Figure 7 shows a further embodiment, in which a localised signal front is provided; and Figure 8 shows an example of apparatus for use in monitoring/maintaining the condition of a pipeline.
Detailed description of the figures
Figure la shows an example of a structure, which in this example is a pipeline 100, such an oil and gas transportation pipeline. However, the structure 100 need not be limited to use with a pipeline, and in fact can be used with any structure, such as a conduit, container, support structure (e.g. a rolled steel joist (RSJ)), framework, such as a building or construction framework, as will be understood when considering the following embodiments.
Figure 1 a shows also a global monitoring signal 120 being communicating into a wall of the pipeline 100. In this example, the global monitoring signal 120 comprises a plurality of frequency components 120a-120h. The global monitoring signal 120 is an acoustic signal. Figure lb shows a plot of the various frequency components 120a- 120h, and their respective amplitude. Here, all of the frequency components 120a- 120h have the same, or at least a similar, amplitude, but of course, this is exemplary only, as is the number of frequency components used. In some instances, only a single frequency component may be used.
When using multiple frequency components 120a-120h, the global monitoring signal can be considered to be a complex signal. That is to say that all the frequency components are communicated cumulatively, or at, or around, the same time.
While shown here that the global monitoring signal 120 is communicated into the wall of the pipeline 100, in other examples the global monitoring signal 120 may be communicated into a medium (e.g. fluid) in the pipeline 100.
To establish a baseline for the condition of the pipeline 100, the global monitoring signal 120 is communicated into the pipeline 100. Generally, this communication occurs over a particular period of time. For example, the global monitoring signal 120 may be communicated over a few seconds, (e.g. pinged) into the pipeline. Some time after the global monitoring signal 120 has been communicated, the remnants of the signal remain in the pipeline 100. This is received as an expected received global monitoring signal 125.
Although, in Figure la, the expected received global monitoring signal 125 is shown to be received at a region of the pipeline 110 different from the region in which the global monitoring signal 120 had been injected, this is exemplary only. In some examples, the global monitoring signal 120 and the expected received global monitoring signal 125 are transmitted and received at the same or similar region of the pipeline 100.
Figure ic shows an exemplary received global monitoring signal 125. As can be seen, the expected received global monitoring signal 125 also contains a plurality of frequency components 125a-125h, which are associated with the frequency components of the global monitoring signal 120. However, some of the frequency components 125a-125h have been attenuated. This is due, at least in part, to the mechanical nature of the pipeline 100.
The expected received global monitoring signal 125 provided in Figure ic can therefore be considered as the baseline for that pipeline 100. That is to say that the response is indicative of the condition of the pipeline 1 00 at that particular time. This may be when the pipeline 100 is new, or newly installed, or at a further predetermined time in the life of the pipeline 100. It will be appreciated that the expected received global monitoring signal 125 may have been obtained when the pipeline 100 contains material (e.g. partially or fully contains one or more of: oil, gas, and/or water).
Should the conditions of the pipeline remain the same, then the same expected received global monitoring signal 125 should be received.
Of course, it will be appreciated that in some examples, the expected received global monitoring signal 125 may be provided by simulation. This may be achieved by using the material or mechanical properties (e.g. mass, length, etc.) of the pipeline 100.
Figure 2a shows the pipeline 100 of Figure la after a period of time in use. The pipeline 100 has been used to transport oil and/or gas.
As is shown in Figure 2a, a deposit 150 has built up at a particular location 155 on an inner surface of the wall 110 of the pipeline 100. Examples of such deposits 150 may be waxes, asphaltenes, hydrates, or the like. The deposit 150 may be accumulated based on the conditions of the pipeline at that location 155, such as temperature, and/or based on the conditions of the flow of material at that location 155, such as eddy currents, or the like.
Of course, it will be appreciated that this build-up may not be identified during use of the pipeline 100. The first that an operator may know of the deposit 150, is when the flow through the pipeline 100 is substantially reduced.
To determine the condition of the pipeline 100, a global monitoring signal 220 is communicated into the pipeline 100. However, in this example because the condition of the pipeline has changed (e.g. the mechanical properties of the pipeline have changed), a received global monitoring signal 240 will have changed from the baseline.
Figure 2b shows the expected received global monitoring signal 125, and the actual received global monitoring signal 240. As can be seen, some of the frequency components of the received global monitoring signal 240 have attenuated more than expected. Of course, this is exemplary only. In further examples, some of the frequency components may have attenuated to a lesser extend due to the existence deposit 150.
Nonetheless, there is a difference between the expected received global monitoring signal 125 and the received global monitoring signal 240. Using this difference it is possible to determine that the condition of the pipeline 100 has changed.
However, from the above analysis the location 155 of the deposit 150 may not be apparent. Therefore, cleaning, or pigging of the entire pipeline would be required.
The longer the pipeline is out of use, the greater the lost of revenue may be to the operator.
Consider now the communication of a signal 320 into the pipeline 100 comprising the deposit 150, as shown in Figure 3a. For convenience, consider this signal to be a local monitoring signal 320.
Here, the local monitoring signal 320 is an acoustic signal. The local monitoring signal 300 can be considered to be a complex signal comprising a plurality of frequency components 320a-320h. Figure 3b shows an exemplary local monitoring signal 320, in a similar manner to that presented in Figure lb. Although, in this instance, each of the frequency components have a different amplitude, this is again exemplary only, as is the number of frequency components 320a-320h used.
The frequency and the phase angle at which each of the frequency components 320a-320h are communicated into the pipeline 100 is selected such that a standing wave is creating within the pipeline 100. It will be appreciated that the formation of a standing wave may be dependent upon the length of the pipeline 100. In this example, the dispersive effects of some or all of the frequency components 320a- 320h (e.g. of the higher frequency components) are also taken into consideration to allow for the standing wave to be formed.
Figure 3c shows a pressure representation of the standing wave created by the cumulative frequency components 320a-320h of the local monitoring signal 320 in the pipeline 100. As can be seen, the local monitoring signal 320 provides a signal front 350. This signal front 350 manifests as a local region of comparatively high changing pressure. This is caused by the selected cumulative effect of the in phase amplitudes of the frequency components 320a-320h of the local monitoring signal 320 at, or around, that location.
It will be appreciated that the pressure at the signal front 350 is oscillatory in nature.
That is to say, that while in Figure 3c the pressure is shows as a maximum at the signal front 350, this is in fact an oscillatory maximum pressure (i.e. swings between a positive pressure maximum and a negative pressure maximum). This may be considered to be an anti-node of the standing wave created.
As can be seen from Figure 3c, the remainder of the pipeline 100 exhibits a comparatively low pressure, or changing pressure.
Although the signal front 350 is provided at the wall 110 of the pipeline 100, it will be apparent that the signal front may additionally, or alternatively be provided in material within the pipeline 100. For example, the local monitoring signal 320 may be communicated through material flowing in the pipeline 100.
This signal front 350 of the local monitoring signal 320 can be presented diagrammatically in the wall 100 of the pipeline 100, as is shown in Figure 3d.
Because the frequency components can be varied and/or the phase angle at which they enter the pipeline 100 can be varied, the signal front 350 can be movable along the length of the pipeline 100. This movement may be gradual, or at intervals, which can be regular or irregular.
Figure 3d shows such intervals 400a-400g along the pipeline 100 for which the signal front 350, in this example, can be positioned. For each interval 400a-400g, a local monitoring signal providing a signal front 350 at that interval or location can be communicated into the pipeline 100.
In a similar manner to that described above in relation to the global monitoring signal and expected received global monitoring signal 125, an expected received signal can be determined for that interval or location to provide a baseline. For convenience, consider this to be an expected received global monitoring signal.
That is to say that a local monitoring signal 320 is communicated (e.g. pinged) into the pipeline 100 having a signal front 350 at a particular interval 400a-400g, and an expected received local monitoring signal 340 is received for that particular location.
Should the conditions of the pipeline remain the same, then the same received local monitoring signal should be received for each interval.
An expected received local monitoring signal can be determined for each of the intervals 400a-400g. This may be determined when the pipeline 100 is new, or newly installed, or at sometime in the pipeline's 100 lifetime.
Figure 4a shows an example of the pipeline 100 comprising the deposit 150. Here, the deposit 150 is located at a sixth interval 400f along the pipeline 100.
A global monitoring signal 120 may have been used to identify that a change in the pipeline 100 has occurred, but this may not provide the location 155 of that deposit 150. Therefore, in a local monitoring signal 320 is communicated into the pipeline having a movable signal front 350.
For each interval 400a-400g a received local monitoring signal is compared with the expected received local monitoring signal. Of course, because the condition of the pipeline 100 has changed, each of the received local monitoring signals may have changed from the expected received local monitoring signal for each interval (e.g. attenuated slightly). However, the received local monitoring signal and the expected received local monitoring signal for the interval 400f at the location or interval at the deposit 150 would have changed to a greater extent. This is exemplified in Figure 4b, which by way of a simplification for the purposes of clarity, shows the cumulative amplitude of the expected received local monitoring signal 700a-700g for each interval 400a-400g, and the cumulative amplitude of the actual received local monitoring signals 750a-750g.
As can be seen, the cumulative amplitude of the actual received local monitoring signal 750f at the sixth interval 400f is less than the cumulative amplitude of the actual received local monitoring signal at every other interval 750a-750e, 750g.
This cumulative amplitude is exemplary only. Nonetheless, the received local monitoring signal 750f at the interval 400f at the deposit 150 will be apparently different from the received local monitoring signals 750a-750e, 750g at the other intervals 400a-400e, 400g.
This method allows for identification of the location 155 of the deposit 150. As such, remedial work can be conducted at that location, without the need to pass solvents, a pig, or the like, through the entire length of the pipeline 100.
Of course, because the local monitoring signal 320 can provide a signal front 350 at a particular location, it is also possible to agitate the pipeline 100 at, or around, the location of the deposit 150. This can be used to break-up the deposit 150. Similarly, the local monitoring signal 320 can be used to ameliorate the possibility of further build-up at that location. In each case this may be considered as a maintenance signal.
Consider the example of a maintenance signal 500 shown in Figure 5. The maintenance signal 500 is similar to the local monitoring signal 320 shown in Figure 3c in that it provides a signal front 550. However, in this example, the amplitude of the maintenance signal 500 at the signal front 550 is less than that of the local monitoring signal 320.
In use, such a maintenance signal 500 is communicated into the pipeline 100 from time to time, or continuously, in order to prevent or reduce the chance of a deposit being built up at that location 155.
In some examples, the maintenance signal 500 may be used as a preventative measure, without knowledge of the possibility of a deposit 150. For example, some pipelines 100 may have a critical portion, or portion that is difficult to access. These may include pipe flanges, or structural connection regions, or the like. In those situations, the maintenance signal 500 may be used to prevent deposit, corrosion, unwanted stress, etc., at those locations.
Although described above in relation to a deposit 150, it will readily be appreciate that the same apparatus and methodology may be used for corrosive or mechanical (e.g. stress) effects. Figure 6 shows an example of corrosion 650 at a location in the pipeline 100. It will be appreciated that the properties of the pipeline 100 will change due to the corrosion. Corrosion may be considered to be any form of deterioration of the pipeline, or removal of material (e.g. ablation, oxidation, etc.).
Similarly, although described with only a single signal front 350, 550 (local monitoring signal and/or maintenance signal) it will be appreciated that in some instances, more than one signal front 350, 550 may be provided. For example, a maintenance signal 500 having more that one signal front may be used to prevent or remove deposit, corrosion, etc. at two or more locations.
Similarly, although the above examples have been described in relation to acoustic signals, it will be appreciated that the same methodology can be applied for electromagnetic signals.
Consider, for example, communicating an electromagnetic maintenance signal into the pipeline 100 (e.g. extra low frequency). Again, such a signal comprising a plurality of frequency components can provide a standing wave having one or more signal fronts 550. However, such a maintenance signal 500 would not necessarily provide a change in pressure, but rather, the signal 500 would provide heating of the pipeline (e.g. localised heating) at the location of the signal front 550. Such a maintenance signal 500 can be used to remove, or reduce wax deposits, or the like.
While in the above examples the location of a deposit (corrosion, etc.) along a length of a pipeline has been described, it will readily be appreciated that the same methodology may be applied in order to provide a signal front at a localised region of the structure. Consider the embodiment of the pipeline 1 00 shown in Figure 7, in which a plurality of signals 800 (e.g. local monitoring/maintenance signals) are communicated into the pipeline at different regions. In this example, the signals are communicated into different circumferential locations. In a similar manner to that described above, the signals 800 can be used to provide a signal front 850 at a particular location of the pipeline, which in this example, can be considered localised.
Although in the above examples, the signal front has been described as an anti-node, a node of a standing wave may also be used to determine the location of deposit, corrosion, stress, etc. Figure 8 shows an example of apparatus 900 for determining a change in condition of a pipeline. The apparatus 900 comprises a signal generator 910 and a transmitter 920 for communicating a local monitoring signal and a global monitoring signal into the pipeline 100.
The apparatus further comprises a receiver 930 for receiving a received global and local monitoring signal. In this example, the apparatus 900 further comprises a user interface 940, such as a liquid crystal display, or the like. The user interface 940 is configured to provide a visual representation of the pipeline 100. Of course, in some examples the user interface 940 may be configured as a user input interface also.
It will be appreciated that in some examples, the apparatus 900 may be configured such that the receiver 930 is provided by the transmitter 920 (e.g. using a transceiver) It will also be appreciated that that apparatus 900 can be used to provide a maintenance signal. However, in such instances, there may be no need to receive the signals in the pipeline 100. The apparatus may be for use with acoustic and/or electromagnetic signals.
It will be appreciated that any of the aforementioned apparatus or method may have other functions or steps in addition to the described functions/steps, and that these functions/steps may be performed by the same apparatus.
Similarly, although this has been exemplified with respect to a pipeline, the invention need not be so limited and may be used with any form of structure, such as These structures may include structure may be a conduit, such as a pipeline, or containers, support structures (e.g. a rolled steel joist (RSJ)), etc. The structures may be a frameworks, such as a building or construction frameworks, or the like. A skilled reader will readily be able to implement the invention accordingly.
The applicant discloses in isolation each individual feature described herein and any combination of two or more such features, to the extent that such features or combinations are capable of being carried out based on the specification as a whole in the light of the common general knowledge of a person skilled in the art, irrespective of whether such features or combinations of features solve any problems disclosed herein, and without limitation to the scope of the claims. The applicant indicates that aspects of the invention may consist of any such individual feature or combination of features.
In view of the foregoing description it will be evident to a person skilled in the art that various modifications may be made within the scope of the invention.

Claims (37)

  1. Claims 1. A method for monitoring the condition of a structure, the method comprising: transmitting a signal in a structure, the signal providing a signal front occurring at a location in the structure; receiving a received signal, the received signal associated with the transmitted signal; determining one or more signal characteristics of the received signal to determine a change in condition of the structure at the location of the signal front.
  2. 2. The method according to claim 1, wherein the signal characteristic comprises a difference between the received signal and an expected received signal, such an expected received signal being associated with a particular condition of the structure at the location of the signal front.
  3. 3. The method according to claim 2, wherein the expected received signal is derived from the results of a transmitted signal in the structure at a particular time, such as when the structure is new, or newly installed.
  4. 4. The method according to any preceding claim, wherein the signal characteristic comprises a difference between the received signal and one or more further received signals, the further received signals being associated with different locations of signal fronts in the structure.
  5. 5. The method according to claim 4 comprising associating a change in condition of the structure at a particular location with a largest determined difference at that location, compared to other locations.
  6. 6. The method according to any preceding claim comprising transmitting a plurality of signals in the structure so as to provide a plurality of signal fronts occurring at different locations in the structure.
  7. 7. The method according to any preceding claim comprising transmitting the signal to provide a movable signal front occurring at a location in the structure, the movable signal front being movable along the length of the structure.
  8. 8. The method according to any preceding claim, in which the signal front provides a region of oscillating pressure change in the structure.
  9. 9. The method according to any preceding claim, in which the signal comprises two or more frequency components.
  10. 10. The method according to claim 9, wherein the signal front is provided by a complex anti-node of a standing wave.
  11. 11. The method according to claim 9 or 10, in which the signal front is movable by changing one or more of the frequency components of the signal.
  12. 12. The method according to claim 11 comprising moving the location of the signal front at regular or irregular intervals along the structure.
  13. 13. The method according to any preceding claim comprising associating a change in the structure at a particular location with a region of one or more: deposition, corrosion, stress, deformation, at that location.
  14. 14. The method according to any preceding claim, in which the structure comprises one or more of: a conduit, such as a pipeline; container; support structure, such as a rolled steel joist; framework, such as a building or construction framework.
  15. 15. The method according to any preceding claim comprising: transmitting a global monitoring signal in the structure; receiving the global monitoring signal and determining a difference between the received global monitoring signal and an expected received global monitoring signal, such an expected received global monitoring signal being derived from the results of a transmitted global monitoring signal in the structure at a particular earlier time; and associating the determined difference with a global change in condition of the structure.
  16. 16. The method according to claim 15 in which the determined difference between the received global monitoring signal and the expected received global monitoring signal is a determined difference in decay, or rate of decay.
  17. 17. The method according to claim 15 or 16, comprising monitoring the condition of the structure using the global monitoring signal from time to time.
  18. 18. The method according to claim 17 in which the transmitted signal is considered to be a local monitoring signal, the received signal is considered to be a received local monitoring signal, and the expected received signal is considered to be an expected received local monitoring signal, the method further comprising monitoring the condition of the structure from time to time using the global monitoring signal, and upon determining a global change in condition of the structure, using the local monitoring signal to determine the location of the change in condition.
  19. 19. The method according to any preceding claim comprise communicating a maintenance signal in the structure, the maintenance signal providing a locatable signal front at a location in the structure to be maintained, the maintenance signal configured to reduce or remove the chance of a change in condition of the structure at that location in the structure
  20. 20. The method according to claim 19, wherein the maintenance signal is configured to reduce or remove the chance of deposit or corrosion at that location in the structure.
  21. 21. The method according to claim 19 or 20 comprising communicating the maintenance signal in the structure in response to a determined change in condition of the structure.
  22. 22. The method according to claim 19, 20 or 21 comprising heating and/or agitating the structure at a particular location or interval.
  23. 23. The method according to any preceding claim, wherein the length of the structure is greater than 1 00 meters.
  24. 24. Apparatus for monitoring the condition of a structure, the apparatus comprising: a transmitter configured to transmit a signal in a structure, such a signal configured to provide a signal front at a location in a structure; a receiver configured to receive a received signal, such a received signal being associated with a transmitted signal; wherein the apparatus is configured to determine one or more signal characteristics of a received signal to determine a change in condition of a structure at the location of the signal front.
  25. 25. Apparatus according to claim 24, in which the apparatus is configured to be one or more of: mountable, demountable, attachable, detachable, fixably attachable, retrofit with a structure.
  26. 26. The method according to any of the claims 1 to 23, or the apparatus according to any of the claims 24 to 25, in which the structure is one or more of: an oil and gas transportation pipeline; an oil and gas exploration pipeline; an oil and gas production pipeline.
  27. 27. A method for maintaining a structure, the method comprising: transmitting a maintenance signal in a structure, the maintenance signal comprising a locatable signal front, the signal front occurring at a location in the structure to be maintained; the signal front configured to reduce or remove the chance of a change in condition of the structure at that location in the structure.
  28. 28. The method according to claim 27, in which the change in condition is one or more of: deposition, corrosion, stress, deformation.
  29. 29. The method according to claim 27 or 28, in which the maintenance signal comprises two or more frequency components.
  30. 30. The method according to claim 29, in which the signal front is locatable by changing the two or more frequency components.
  31. 31. The method according to any of the claims 27 to 30, wherein the signal front is provided by a complex anti-node of a standing wave.
  32. 32. The method according to any of the claims 27 to 31 comprising heating and/or agitating the structure at a location using the maintenance signal.
  33. 33. Apparatus for maintaining a structure, the apparatus comprising: a transmitter configured to transmit a maintenance signal in a structure, such a maintenance signal comprising a locatable signal front, such a signal front configured to occur at a location in a structure; the apparatus configured to provide a signal front configured to reduce or remove the chance of change in condition of a structure at a location in a structure.32. Apparatus according to claim 31, wherein the apparatus is configured to be one or more of: mountable, demountable, attachable, detachable, fixably attachable, retrofit with a structure.33. Apparatus according to claim 31 or 32 in which the structure is one or more of an oil and gas transportation structure; an oil and gas exploration pipeline; an oil and gas production pipeline.
  34. 34. A device comprising apparatus according to any of the claims 22, 23, 31, 32 or 33.
  35. 35. A computer program product, provided on a computer readable medium, the computer program product configured to provide the method according any of the claims 1 to 23, or 27 to 32.
  36. 36. Apparatus/device substantially as described herein, with reference to the figures.
  37. 37. Methods substantially as described herein, with reference to the figures.
GB0919035A 2009-10-30 2009-10-30 A method for monitoring and/or maintaining the condition of a structure such as a pipeline Withdrawn GB2475225A (en)

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