WO2015110791A1 - Système de surveillance - Google Patents

Système de surveillance Download PDF

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Publication number
WO2015110791A1
WO2015110791A1 PCT/GB2015/050046 GB2015050046W WO2015110791A1 WO 2015110791 A1 WO2015110791 A1 WO 2015110791A1 GB 2015050046 W GB2015050046 W GB 2015050046W WO 2015110791 A1 WO2015110791 A1 WO 2015110791A1
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WO
WIPO (PCT)
Prior art keywords
bearing element
measurement
load
monitoring system
data collection
Prior art date
Application number
PCT/GB2015/050046
Other languages
English (en)
Inventor
Andrew Lawson
Philip Bull
Original Assignee
Parkburn Precision Handling Systems Limited
Priority date (The priority date 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 date listed.)
Filing date
Publication date
Application filed by Parkburn Precision Handling Systems Limited filed Critical Parkburn Precision Handling Systems Limited
Priority to GB1612845.6A priority Critical patent/GB2536597B/en
Publication of WO2015110791A1 publication Critical patent/WO2015110791A1/fr

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Classifications

    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B66—HOISTING; LIFTING; HAULING
    • B66D—CAPSTANS; WINCHES; TACKLES, e.g. PULLEY BLOCKS; HOISTS
    • B66D1/00—Rope, cable, or chain winding mechanisms; Capstans
    • B66D1/54—Safety gear
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B66—HOISTING; LIFTING; HAULING
    • B66B—ELEVATORS; ESCALATORS OR MOVING WALKWAYS
    • B66B7/00—Other common features of elevators
    • B66B7/12—Checking, lubricating, or cleaning means for ropes, cables or guides
    • B66B7/1207—Checking means
    • B66B7/1215—Checking means specially adapted for ropes or cables
    • B66B7/1238—Checking means specially adapted for ropes or cables by optical techniques

Definitions

  • the present invention relates to a monitoring system and corresponding method, particularly for monitoring load bearing elements, including spoolable load bearing elements such as ropes, cables and other lines.
  • Spoolable load bearing elements or media such as ropes, cables and other lines are used for a variety of purposes in a wide range of industries.
  • ropes and some cables comprise linear lines formed by a plurality of strands, such as yarns, fibres, wires, plies or the like.
  • the strands are generally braided, woven or otherwise intermeshed together in order to form a strong but flexible load bearing line.
  • the strands can have a range of thicknesses and other properties and be formed from a variety of materials, which are generally selected according to the intended purpose.
  • Common materials used for this purpose include synthetic or polymeric materials, natural materials and metallic materials, although other materials would be apparent to a skilled person.
  • suitable synthetic or polymeric materials include polypropylene, nylon, polyesters, polyethylene, aramid fibres, acrylics, halogenated polymers such as PTFE and cellulosic fibres such as rayon, tencel, and lyocell, and the like, along with various derivatives and copolymers thereof.
  • Ultra High Molecular Weight Polyethylene (UHMWPE) fibre rope has proven especially successful due to its high strength to weight ratio and low elongation under loads.
  • Suitable metallic materials include various grades of steel but it will be appreciated that other metallic fibres or cords could be used.
  • Commonly used natural materials include cotton, sisal, hemp, coir and the like.
  • Exemplary uses for such load bearing elements include lifting and handling, restraining, pulling, moving, supporting and dragging a range of objects and structures.
  • Some examples of the numerous industries where such load bearing elements are used include the nautical and oil and gas industries, mining, construction, transport, support in architectural structures such as buildings and bridges, and so on.
  • sub-sea hardware in very deep water, e.g. at depths of 1000m and greater.
  • Deep water deployment of sub-sea hardware is particularly associated with the oil and gas industry.
  • Examples of such sub-sea hardware include manifolds, templates, processing systems and wellhead systems. Assemblies of this type can weigh hundreds of tonnes. Similarly, extreme loads may be encountered when lifting or lowering a pipeline or section of pipeline to or from the seabed during installation and/or maintenance.
  • Deep water deployment systems including cranes employ a variety of mechanisms and typically include traction systems to move payloads via load- bearing spoolable elements or media.
  • Traction systems include a drum winch around which a spoolable medium is wound, wherein rotation of the drum permits spooling of the medium.
  • the drum acts to store the spoolable medium, with the medium arranged in single or multiple wraps and layers between end flanges of the drum.
  • the spoolable medium may be subject to significant radial crushing forces, particularly in circumstances where large payloads are involved and thus significant tensions are applied to the spoolable medium.
  • it may be necessary to store the medium in a high tension state which may reduce the life span of the medium through fatigue, excessive strains, hysteresis and the like.
  • storage of the spoolable medium on a drum typically requires the use of complex fleeting arrangements to ensure that the medium is arranged in suitable wraps and layers.
  • the drum is used only to apply a force to a spoolable medium, with the spoolable medium being stored separately, for example in a basket, on a separate spool or the like.
  • the force applied by the drum is typically either a pulling force to pay in a spoolable medium, or a controlled releasing force to permit controlled paying out of a spoolable medium while under load, for example while connected to a payload.
  • winch species which may include capstans or windlasses
  • an intermediate portion of a spoolable medium is wrapped around the drum a number of times such that an outboard side of the spoolable medium extends from the drum to engage a payload, and an inboard side of the spoolable medium extends to storage.
  • the drum functions to reduce the tension in the spoolable medium from a high tension condition in the outboard side, to a lower tension condition in the inboard side of the spoolable medium, thus permitting the spoolable medium to be stored in a favourable low tension state.
  • winch species are often called detensioning units.
  • the drum establishes a tension gradient in the spoolable medium.
  • Synthetic fibre ropes In order to reduce the weight of the spoolable media used in very deep water applications, synthetic fibre ropes have been adopted. Synthetic fibre ropes typically exhibit near neutral buoyancy and therefore minimal added weight, even when working at great depths.
  • the load bearing member or medium may be subject to degradation, for example due to exposure to radiation such as sunlight, chemical processes such as rusting, and/or thermal processes such as friction heating, proximity to hot components and the like.
  • wear and/or degradation may arise due to abrasion, e.g. from handling equipment such as winches, drums, pulleys and the like, and/or from tensioning, relaxing, other applied forces, strains and other operational conditions.
  • a monitoring system for monitoring at least one load bearing element.
  • the monitoring system may comprise a plurality of measurement or data collection devices for collecting data indicative of one or more parameters or properties of at least one section or portion of the at least one load bearing element.
  • the monitoring system may comprise at least two different types of the measurement or data collection device.
  • the monitoring system may comprise a processing system configured to communicate with, and/or receive output and/or data from, the measurement or data collection devices.
  • the processing system may be configured to determine a condition of the at least one section or portion of the at least one load bearing element from the data measured or collected by the measurement or data collection devices.
  • the processing system may be configured to determine the properties or parameters of the at least one section or portion of the at least one load bearing element and/or changes or variations therein, and may thereby determine the condition of the at least one section or portion of the at least one load bearing element.
  • At least one measurement or data collection devices may be configured to measure or collect data indicative of a different parameter or property of the load bearing element to that measured or collected by at least one other of the measurement or data collection devices.
  • at least one of the measurement or data collection devices may use a different measurement or data collection technology to at least one other measurement or data collection device.
  • the processing system may be configured to determine a condition of the at least one load bearing element from the output from the plurality of measurement or data collection devices.
  • One or more or each of the load-bearing elements may comprise an elongate element, such as a line, e.g. rope, cable, wire, or the like.
  • One or more or each of the load-bearing elements or lines may comprise a multicomponent element, such as a rope, cable, wire, or the like.
  • One or more load-bearing elements or lines may comprise a synthetic fibre rope, a metal rope such as a steel rope, or the like.
  • the cross-section of one or more load-bearing elements may be substantially circular, oval, rectangular (e.g. a so-called "flat rope), or may have any other suitable profile.
  • One or more load-bearing elements may be made from a polymeric material, for example UHMWPE; a liquid crystal polyester (LCP); an aramid, or blends thereof.
  • a polymeric material for example UHMWPE; a liquid crystal polyester (LCP); an aramid, or blends thereof.
  • the properties or parameters of the load bearing element may comprise at least one of, and optionally at least two of:
  • the measurement or data collection technologies may comprise one or more optical or visual, thermal, and/or mechanical measurement technologies or methods.
  • the measurement technologies or methods may comprise technologies or methods to determine at least one and preferably two or more of: physical or geometric properties such as one or more dimensions or volume, thermal properties and/or velocity, distance and/or location of one or more or each section or portion of the at least one load bearing element.
  • the processing system may be configured to determine a location or position of wear or damage to the load bearing element using the determined velocity, distance and/or location of the at least one portion or section of the load bearing element
  • At least one of the measurement or data collection devices may comprise a thermal imaging device, such as an infra-red or thermographic camera.
  • At least one of the measurement or data collection devices may be configured to monitor or collect data indicative of a physical characteristic of one or more or each section or portion of the load-bearing element, such as geometry and/or at least one dimension and/or volume of one or more or each section or portion of the load- bearing element.
  • the at least one measurement or data collection device may comprise a laser profiler, a microwave or other radiation profiler, an ultrasonic profiler and/or the like.
  • At least one of the measurement or data collection devices may be configured to determine and/or log and/or collect data indicative of a speed or velocity of the load-bearing element and/or a distance that the one or more sections or portions of the load-bearing element, e.g. over time.
  • the at least one of the measurement or data collection devices may comprise a Doppler shift measurement or data collection device such as a laser Doppler measurement or data collection device and/or an ultrasonic or sonic Doppler measurement or data collection device.
  • At least one of the measurement or data collection devices may comprise a rotational monitor for monitoring the speed of rotation of a sheave or wheel over or through which the load-bearing element passes.
  • At least one of the measurement or data collection devices may comprise a camera or other visual imaging device, such as a digital imaging device, which may comprise, for example, one or more CCD sensor, CMOS sensor, photodiode array, or the like.
  • a camera or other visual imaging device such as a digital imaging device, which may comprise, for example, one or more CCD sensor, CMOS sensor, photodiode array, or the like.
  • At least one of the measurement or data collection devices may be configured to measure or determine a work input into the load-bearing element.
  • the measurement or data collection devices may comprise one or more electrical measurement or data collection devices, such as conductivity, impedance or ac-impedance spectroscopy measurement or data collection devices.
  • the measurement or data collection devices may comprise a radiation absorption or reflection based measurement or data collection device, such as an x- ray or microwave absorption measurement or data collection device.
  • a plurality of the measurement or data collection devices may be configured to perform measurements on the same imaging or analysis area or volume and/or on the same section of the at least one load bearing element.
  • the measurement or data collection devices may be configured to perform measurements on the same imaging area or volume and/or on the same section or portion of the at least one load bearing element from two or more directions, such as two or more directions selected from above or in plan view, below, one or more sides or in an elevation view of, or perpendicularly to and/or obliquely to the at least one load bearing element.
  • the one or more properties or parameters determined by the processing system may comprise one or more profiles, volumes and/or dimensions, e.g. in one, two or three dimensions, of one or more sections or portions or all of the load bearing element(s).
  • the one or more profiles, volumes and/or dimensions may be determined by the processing system, e.g. from the measurements performed by at least one and optionally a plurality of the measurement or data collection devices.
  • the one or more profiles may comprise dimensional profiles, such as thickness or width profiles, and/or thermal profiles, and/or absorption or reflection profiles.
  • the one or more properties or parameters determined by the processing system may comprise a maximum, average and/or localised cross sectional dimension, such as thickness, height, diameter, or the like, of the at least one load bearing element, e.g. in one or more cross sectional direction.
  • the output of one or more of the measurement or data collection devices may comprise an image, such as a visual image, a thermal or infra-red image, and/or data relating to one or more of the properties or parameters of the load-bearing element, such as absorption of radiation or sound, one or more dimensions, temperature, position, sound and/or the like.
  • the processing system may be configured to determine a proportion or number of one or more parts of the load-bearing element(s) or one or more views or images of the one or more portions of the load-bearing element(s) having values of one or more of the parameters or properties within one or more ranges, regions, bands, or thresholds.
  • the one or more ranges, regions, bands or thresholds may be pre-set or predetermined and/or based on calibration data, e.g. based on the corresponding parameters or properties of the load-bearing element when new or in an initial or other comparative state.
  • the monitoring system may be configured to receive, determine or collect initial, new or calibration data, which may comprise or be derived from data indicative of the one or more parameters or properties of at least one section or portion or all of the at least one load bearing element when the load bearing member is in a new or initial state.
  • the monitoring system may be configured to receive, determine or collect the initial, new or calibration data along the entire length of the load bearing element.
  • the processing system may be configured to at least partially determine the condition of the at least one section or portion of the at least one load bearing element from variations between the data measured or collected by the measurement or data collection devices and the initial, new or calibration data and/or previously determined parameters or properties of the at least one section or portion of the at least one load bearing element.
  • the processing system may be configured to determine anomalies and/or modifications to the load bearing element (e.g. intended modifications, such as those made by a user).
  • the modifications may comprise splices, joins and/or the like.
  • the processing system may be configured to identify step-wise or discrete changes in the parameters or properties of at least one section or portion of the at least one load bearing element and may be configured to correlate the step-wise or discrete changes with anomalies and/or modifications.
  • the processing system may be configured to update the collect initial, new or calibration data when it identifies the anomalies and/or modifications.
  • the processing system may determine a variation over time in the one or more parameter or property or in the proportion or number of the one or more portions of the load-bearing element(s) having values of one or more of the parameters or properties within one or more ranges, regions, bands, or thresholds.
  • the processing system may be configured to determine the condition of the one or more portions of the load-bearing element from or using the one or more parameters or properties and/or the proportion or number of portions of the load- bearing element having one or more of the properties and/or parameters within the one or more ranges, bands or thresholds and/or the variation therein over time.
  • the processing system may be configured to determine the variation in the number or proportion of regions of one or more portions of the load- bearing element are within one or more thickness and/or temperature ranges over time.
  • the processing unit may be configured to determine a smoothness, uniformity and/or straightness of an edge or surface of one or more portions of the load-bearing element, e.g. from visual images, and at least partially determine a condition of the load-bearing element accordingly.
  • the processing system may be configured to display and/or represent the condition of the one or more portions of the load-bearing element using an indicative value, colour, symbol or other indicia, e.g. a traffic light green-amber-red colour to show acceptable, possible concerns or advisories and unacceptable conditions respectively.
  • an indicative value, colour, symbol or other indicia e.g. a traffic light green-amber-red colour to show acceptable, possible concerns or advisories and unacceptable conditions respectively.
  • the monitoring system may comprise communications apparatus, such as wired or wireless communications apparatus.
  • the communications apparatus may be configured to receive and/or provide data to a removable storage medium, such as a memory card or stick or disc or other storage device.
  • the communications apparatus may be configured to communicate over the internet.
  • the processing system may be configured to transmit the condition and/or the determined properties and/or parameters of one or more of the portions of the load-bearing element(s) to a remote device or system, such as a server or other suitable computing, storage and/or display device, via the communications apparatus.
  • One or more and optionally each of the measurement or data collection devices that are configured to monitor or measure at least one dimension or other geometrical property of the load-bearing element may be positioned or positionable such that the measurement or data collection device(s) measure or monitor the load bearing element at a portion that is de-stressed or de-tensioned, e.g. between handling devices such as pulleys, sheaves, winches windlasses, capstans, drums and the like and/or inboard, downstream or on the de-tensioned side of a de- tensioning element such as a winch, windlass or capstan or the like.
  • One or more and optionally each of the measurement or data collection devices that are configured to monitor or measure temperature, infra-red or other thermal properties of the load-bearing element or absorption or reflection of sound waves, light or radiation by the load bearing element may be positioned or positionable such that the measurement or data collection device(s) measure or monitor the load bearing element at a portion that is stressed or tensioned, e.g. at or on handling devices such as pulleys, sheaves (e.g. a boarding sheave), winches, windlasses, capstans, drums, a first point of contact with a vessel, and the like and/or upstream or on the tensioned side of a de-tensioning element such as a winch, windlass, capstan or the like.
  • handling devices such as pulleys, sheaves (e.g. a boarding sheave), winches, windlasses, capstans, drums, a first point of contact with a vessel, and the like and/or upstream or on
  • the processing unit may be configured to account for weave compensation in the load-bearing element.
  • the processing unit may be provided with a compensation factor associated with a given load-bearing element or weave, e.g. at a given tension or velocity.
  • the processing unit may be configured to apply the weave compensation in determining the one of more properties or parameters and/or the condition of the load-bearing element.
  • the processing unit may be configured to identify surface damage to the load-bearing element, e.g. cuts and/or the like.
  • the surface damage may be identified from visual images, e.g. by comparing visual images over time or by determining indicative patterns in the visual image or via image recognition, such as using learning or trained algorithms such as genetic algorithms, fuzzy logic, and the like, which may be trained using reference or calibration images or samples.
  • a second aspect of the present invention is a method for monitoring at least one load bearing element, the method comprising:
  • the measuring or monitoring the at least one load bearing element using at least two different measuring technologies, wherein at least one of the measuring technologies is different to at least one other of the measurement technologies; and determining a condition of the at least one load bearing element from or using the measurements obtained using at least two different measuring technologies.
  • the method may comprise using the monitoring system described in relation to the first embodiment or performing an action using, associated with or equivalent to a feature described in relation to the first aspect.
  • a handling apparatus for handling a load-bearing element the handling apparatus may comprise at least one monitoring device according to the first aspect for monitoring a condition of the load-bearing element.
  • the handling apparatus may comprise at least one pulley, sheave, winch windlass, capstan, drum, other tensioning or de-tensioning devices and/or drive devices for propelling, driving or moving the load-bearing element and/or the like.
  • the handling apparatus may comprise or be comprised a winch, crane or other lifting device, which may comprise a spoolable load bearing element.
  • the load bearing element may comprise a rope, cable, wire or other line.
  • a fourth aspect of the present invention is a vessel, vehicle or structure comprising the handling apparatus of the third aspect.
  • a fifth aspect of the present invention is a computer program product configured to implement or program the monitoring device of the first aspect, the processing device described in relation to the first aspect or the method of the second aspect.
  • the computer program product may comprise a series of commands or control codes for operating and/or controlling the monitoring device or processing device.
  • a sixth aspect of the present invention is a processing device when suitably programmed with the computer program product of the fifth aspect of configured to implement the method of the second aspect and/or configured to be operable in or with the monitoring device of the first aspect.
  • the processing device may comprise at least one feature described in relation to, or equivalent to, the first aspect.
  • the processing device may comprise a processor, a memory and/or data store, communications apparatus, and one or more input devices and/or one or more output devices.
  • a seventh aspect is a carrier or storage medium loaded with or comprising the computer program product of the fifth aspect.
  • Figure 1 is a diagrammatic representation of a vessel having a rope based handling system
  • FIG 2 is a detail view of the handling system shown in Figure 1 , having a condition monitoring system for monitoring the condition of the rope;
  • Figure 3 is a schematic of a condition monitoring system shown in Figure 2;
  • Figure 4(a) is a thickness profile image of a portion of a new rope collected using the monitoring system of Figure 3;
  • Figure 4(b) is a thickness profile image of a portion of a slightly used rope collected using the monitoring system of Figure 3;
  • Figure 4(c) is a thickness profile image of a portion of a well-used rope collected using the monitoring system of Figure 3;
  • Figure 4(d) is a thickness profile image of a portion of an old, worn rope collected using the monitoring system of Figure 3;
  • Figure 5(a) is a processed monochromatic image derived from the image of Figure 4(a);
  • Figure 5(b) is a processed monochromatic image derived from the image of Figure 4(b);
  • Figure 5(c) is a processed monochromatic image derived from the image of
  • Figure 4(c); Figure 5(d) is a processed monochromatic image derived from the image of Figure 4(d);
  • Figure 6(a) is a contrast enhanced image derived from the image of Figure
  • Figure 6(b) is a contrast enhanced image derived from the image of Figure
  • Figure 6(c) is a contrast enhanced image derived from the image of Figure
  • Figure 6(d) is a contrast enhanced image derived from the image of Figure
  • Figure 7(a) is a processed image derived from the image of Figure 6(a), showing the results of a grouping operation
  • Figure 7(b) is a processed image derived from the image of Figure 6(d), showing the results of a grouping operation
  • Figure 8 is a three dimensional image of a rope derived from images collected using the monitoring system of Figure 3;
  • Figure 9 is a three dimensional image of a new rope derived from images collected using the monitoring system of Figure 3.
  • Figure 10 is a three dimensional image of an old, worn rope derived from images collected using the monitoring system of Figure 3.
  • Figure 1 shows a vessel 5 upon which a handling system 10 is mounted.
  • the vessel 5 shown is a ship or boat, it will be appreciated that the handling system 10 could equally be mounted on a rig or other structure. Indeed, it will be appreciated that the handling system 10 is not limited to nautical or oil and gas based applications but is generally applicable to other suitable systems that use ropes, cables, wires and other lines.
  • the handling system 10 is shown in more detail in Figure 2 and in this example is used to raise and lower loads 15 over the side of the vessel 5.
  • the handling system 10 comprises a rope 20 that is payable out from, and retractable into, a storage winch 25 under low tension. From the storage winch 25, the rope 20 extends in a few loops around a drum of a drive or traction winch 30.
  • the drive or traction winch 30 is provided with a motor 35 or other suitable drive means to rotate the drive or traction winch 30 in forward and reverse directions.
  • the drive or traction winch 30 acts to both tension the rope on a load side of the drive or traction winch 30 and also to drive or control the rope 20 in order to raise or lower the load 15.
  • From the drive or traction winch 30, the rope 20 extends under tension to an overboard sheave 40 located at an edge of the vessel 5. The rope 20 runs over the overboard sheave 40 then downwardly to the load 15.
  • the drive or traction winch 30 is operable to drive the rope 20 in forward or reverse directions in order to respectively lower or raise the load 15.
  • the rope 20 is payed out from the storage winch 25 and the rope 20 is received back into the storage winch 25 as the drive or traction winch 30 rotates in the reverse direction in order to raise the load 15.
  • This handling system 10 is analogous to a commonly used arrangement. However, it will be appreciated that other handling systems 10 known in the art may be used instead.
  • the handling system 10 is provided with a monitoring system 50, shown in Figures 2 and 3 for monitoring the condition of the rope 20.
  • the monitoring system 50 comprises a processing unit 55 that is in communication with a plurality of measurement devices 60a-60f that are arranged to monitor or measure properties or parameters of the rope 20.
  • the measurement devices 60a-60f can be connected to the processing unit 55 via a wired or wireless connection 65a, 65b such as wi-fi, Bluetooth, Zigbee, cellular or other suitable communications system.
  • first, second and third measurement devices 60a-60c are connected wirelessly to the processing unit 55 whilst fourth, fifth and sixth measurement devices 60d-60f are connected via wired connections.
  • the measurement devices 60a-60f could be connected to the processing unit 55 in any manner that is convenient for the application for which it is to be used. Particularly, certain measurement devices 60a-60f can be beneficially located at different locations on the handling system 10 that are remote from the processing unit 55. As such, the above arrangement provides a useful method for distributing the measurement devices 60a-60f.
  • the monitoring system 10 comprises a variety of measurement devices 60a-60f that use different measurement technologies, techniques or methodologies to monitor different properties or parameters of the rope 20.
  • each of the first to third and fifth measurement devices 60a-60c, 60f use different measurement technologies, whilst the fourth and fifth measurement devices 60d, 60e use the same measurement technology.
  • the first measurement device 60a is a low energy x-ray inspection system comprising a radiation source and detected by a suitable x-ray detector array. In this way, some of the x-rays emitted from the x-ray source are absorbed by the rope 20 and the remainder detected by the detector array.
  • properties or parameters of the rope 20 such as one or more dimensions and/or the density of the rope 20 can then be determined from the absorption of x-rays by the rope, which can be determined from the output of the receiver array.
  • the second measurement device 60b is a three dimensional laser profiler.
  • the laser profile comprises three profiling modules 70a-70c, each profiling module 70a-70c comprising a scanning or multiplexed laser light source and a suitable detector array for detecting reflections of the incident laser light, i.e. from the rope 20.
  • the profiling modules 70a-70c are each arranged to image the same imaging volume from different viewpoints, such as from above or in a plan view, from the side or in an elevation view and obliquely. In this way, the profile images from the three profiling modules 70a-70c can be combined in order to form a three dimensional image of the section or portion of the rope 20 within the imaging volume.
  • the third measurement device 60c is a rope velocity determination device.
  • the third measurement device 60c comprises a laser Doppler device for determining a rope velocity, i.e. speed and direction.
  • a rope velocity i.e. speed and direction.
  • the rope velocity, distance and/or position is/are determined using a Doppler laser device, it will be appreciated that other suitable measurement techniques could be used.
  • the rope velocity, distance and/or position may be determined by detecting periodic markings on the rope 20 or by measuring rotation of one of the components of the handling system such as the storage winch 25, drive or traction winch 30 and/or overboard sheave 40, or a device provided specifically for that purpose.
  • the fourth and fifth measurement devices 60d, 60e use the same measurement technology, in this case thermal imaging.
  • the third and fourth measurement devices 60d, 60e comprise an infra-red or thermographic camera.
  • the thermal imaging technology is operable to provide temperature maps or profiles of portions of the rope 20 as they pass the thermal imaging devices 60d, 60e.
  • the sixth measurement device 60f comprises an ultrasonic measurement device, for measuring reflectance and/or absorption of ultrasonic radiation by the rope 20.
  • the accuracy of the condition determination may be improved.
  • providing measurement devices 60b-60e for measuring rope speed, position and/or distance, thermal properties (e.g. temperature distribution) and one or more physical properties (e.g. one or more dimensions or other geometrical properties) advantageously provides accurate condition monitoring and can also determine a location of any degradation.
  • measurement devices 60a-60f dependent on the type of measurement device. For example, it has been found to be beneficial to position measurement devices 60a-60f, such as the first and second imaging devices 60a, 60b, that measure geometrical properties or dimensions of the rope 20 in locations where the rope 20 is under low tension, such as downstream or on a low tension side of the drive or traction winch 30 or other tensioning means.
  • measurement devices such as the fourth fifth and sixth measurement devices 60d-60f, that measure physical properties of the rope 20 (such as thermal properties, heat, temperature, or absorption of radiation) at locations where the rope 20 is under high stress, for example, at components of the handling system such as at the drive or traction winch 30 or other tensioning means or at any pulleys, sheaves or guides, e.g. at the overboard sheave 40.
  • a load monitor 72 such as a force meter or the like can be provided on a component of the handling system 10, such as the overboard sheave 40.
  • the load monitor 72 is configured to monitor the load applied to the component of the handling system 10 (in this case the overboard sheave 40), which can be used to give an indication of the tension in the rope 20. In this way, one or more parameters or properties of the rope 20, such as tension, can be indirectly determined
  • the output from each of the measurement devices 60a-60f is provided to the processing unit 55.
  • the processing unit 55 comprises a processor 75, a data store or memory 80 and a communications system 85.
  • the communications system 85 comprises wired and/or wireless connectors, as appropriate, such that the processing unit 55 can receive data and other measurement from the measurement devices 60a-60f and output condition data to remote devices (not shown), such as servers or monitoring systems or displays, e.g. online.
  • the processing unit 55 is configured to determine and display or transmit a condition indicator to the determined condition of each portion of the rope 20.
  • the condition indicator can advantageously comprise a green, amber red traffic light style indicator in order to allow operators to quickly recognise good condition, worn but non critical or advisory condition and unacceptable conditions respectively.
  • the condition indicator can be assigned according to predetermined criteria or values or changes therein.
  • the processor 75 is configured to determine the condition of the rope 20 based on variations in parameters such as rope thickness or width in one or more cross sectional directions, a thickness or width profile, a degree of absorption of radiation, a degree of smoothness of a surface and/or edge of the rope 20, temperature profile and/or the like, which can be determined using the plurality of measurement devices 60a-60f.
  • Figure 4 shows images of a rope 20 in various conditions collected using the laser profiler 60b.
  • Figure 4(a) is a laser profile image of the rope 20 in a new condition
  • Figure 4(b) is a laser profile image of the rope 20 in a slightly used condition
  • Figure 4(c) is a laser profile image of the rope 20 in a more used condition
  • Figure 4(d) is a laser profile image of the rope 20 in an old, worn condition.
  • the colours in the image are representative of a distance from the laser profiler, i.e. of rope 20 height or thickness, and each rope 20 condition produces different effect in the profile images.
  • the profile images are synthetic two dimensional images that contain height information represented by colour for each coordinate of the image of the rope 20.
  • the new, unused rope 20 in Figure 4(a) has a higher height than the used ropes 20 shown in Figures 4(b) to 4(d) and that the height of the rope 20 generally decreases with use. Furthermore, surfaces 90 of the newer rope 20 have more texture to them that the surface of the older, more worn ropes 20 but with smoother, more sharply defined edges 95. All of the braids of the new rope 20 can be seen to be in good condition and all of the picks of the new rope 20 can be clearly distinguished. Variation in these properties can be associated with wear in the rope 20.
  • a particularly useful tool is a height or thickness calculation tool for determining an average or maximum height or thickness of the rope from the image.
  • the profile images output from three laser profilers of the second imaging devices can be combined in order to produce to build a three dimensional model of the rope 20 and determine volume or sections or portions of the rope 20, wherein variations in volume for any given section or portion of rope 20 can be indicative of wear.
  • the images from the laser profiles can optionally be converted into grey scale images, such as those shown in Figures 5(a) to 5(d), which are derived from images 4(a) to 4(d) respectively.
  • grey scale images such as those shown in Figures 5(a) to 5(d)
  • the edges 95 can be clearly seen to fray with use and the bulk of the rope 20 appears more homogenous and has less distinct features in the images of the older ropes 20.
  • Suitable image analysis calliper tools are available for determining the dimensions of the rope 20.
  • contrast enhancement can be used to more clearly isolate regions of the image where the rope thickness is above a certain threshold thickness, as indicated by bright patches 105 in the contrast enhanced images shown in Figure 6(a) to Figure 6(b), which correspond to images 4(a) to 4(d) respectively.
  • regions meeting the thickness threshold condition can be readily identified using edge detection, blob tools or other techniques known in the art, as shown in Figures 7(a) and 7(b), which correspond to images 6(a) and 6(d) respectively. Absence of regions meeting the thickness threshold or a reduction in number or proportion of these regions can be indicative of wear 120, as shown in Figure 7(b).
  • three dimensional images can be created from multiple images of the same portion or region of rope 20 taken from multiple imaging directions.
  • the more sharply defined surface and edges 105 of the new rope can be readily seen in Figure 9, whilst the old, worn rope 20 shown in Figure 10 has less distinct features in the body of the rope and rougher edges 105.
  • the three dimensional images can also be used to derive coordinates of points on the surface of the rope 20 and thicknesses, heights and/or volumes of portions or sections of the rope 20. Again, it will be appreciated that variations of such properties or parameters of the rope 20 over time can be determined in order to determine deteriorations in condition of the rope 20.
  • thermal profile images taken using the thermal imaging cameras 60d, 60e where temperature is used as the monitored parameter in place of thickness or width can also be applied to thermal profile images taken using the thermal imaging cameras 60d, 60e where temperature is used as the monitored parameter in place of thickness or width. For example, variation in a number or proportion of parts of the rope 20 having temperatures below a threshold can be determined in order to determine wear.
  • the portion or section of the rope being analysed by any of the measurement devices can be determined using the rope velocity, position and/or distance measurement device, such as the third measurement device. This allows the variations in the properties or parameters of any given potion or section of the rope over time to be determined and any problem sections or portions identified.
  • monitoring device for example, although the application of the monitoring device to monitoring rope 20 is described, it will be appreciated the monitoring system could also be used to monitor the condition of cables, wires and/or other lines.

Abstract

L'invention concerne un système de surveillance et un procédé associé pour la surveillance d'au moins un élément porteur (20), le système de surveillance comprenant au moins deux types différents de dispositifs de mesure ou de collecte de données (60a-60f) permettant de collecter des données indiquant un ou plusieurs paramètres ou une ou plusieurs propriétés d'au moins une section ou partie de l'/des élément(s) porteur(s); et le système de surveillance comprenant en outre un système de traitement (55) conçu pour communiquer avec les dispositifs de mesure ou de collecte de données et pour déterminer un état de la/des section(s) ou partie(s) de l'/des élément(s) porteur(s) à partir des données mesurées ou collectées par les dispositifs de mesure ou de collecte de données.
PCT/GB2015/050046 2014-01-21 2015-01-12 Système de surveillance WO2015110791A1 (fr)

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KR101799378B1 (ko) * 2017-04-19 2017-12-20 대광기업 주식회사 와이어 로프 스풀링 통합관리 장치
EP3309105A1 (fr) * 2016-10-14 2018-04-18 Inventio AG Procédé et système de dispositif de commande de surveillance du moyen de traction suspendu d'un ascenseur et système d'ascenseur comprenant un ascenseur et un système de dispositif de commande
EP3357858A1 (fr) * 2017-02-03 2018-08-08 PRINOTH S.p.A. Câble pour un ensemble, ensemble de treuil et véhicule à chenilles, en particulier une dameuse, comportant un tel câble
EP3715815A1 (fr) 2019-04-08 2020-09-30 Airbus Defence And Space, S.A.U. Système et procédé de surveillance de l'état de dégradation du ravitaillement de tuyaux
US10994968B2 (en) 2018-08-29 2021-05-04 Otis Elevator Company Elevator rope elongation measuring device
WO2023018336A1 (fr) * 2021-08-11 2023-02-16 Watbots As Procédé de détection de l'usure d'un filet

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Publication number Priority date Publication date Assignee Title
EP3309105A1 (fr) * 2016-10-14 2018-04-18 Inventio AG Procédé et système de dispositif de commande de surveillance du moyen de traction suspendu d'un ascenseur et système d'ascenseur comprenant un ascenseur et un système de dispositif de commande
EP3357858A1 (fr) * 2017-02-03 2018-08-08 PRINOTH S.p.A. Câble pour un ensemble, ensemble de treuil et véhicule à chenilles, en particulier une dameuse, comportant un tel câble
KR101799378B1 (ko) * 2017-04-19 2017-12-20 대광기업 주식회사 와이어 로프 스풀링 통합관리 장치
US10994968B2 (en) 2018-08-29 2021-05-04 Otis Elevator Company Elevator rope elongation measuring device
EP3715815A1 (fr) 2019-04-08 2020-09-30 Airbus Defence And Space, S.A.U. Système et procédé de surveillance de l'état de dégradation du ravitaillement de tuyaux
EP3715815B1 (fr) * 2019-04-08 2023-03-29 Airbus Defence and Space, S.A.U. Système et procédé de surveillance de l'état de dégradation du ravitaillement de tuyaux
WO2023018336A1 (fr) * 2021-08-11 2023-02-16 Watbots As Procédé de détection de l'usure d'un filet
GB2624333A (en) * 2021-08-11 2024-05-15 Watbots As Method for detecting wear of a net

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GB201612845D0 (en) 2016-09-07
GB2536597A (en) 2016-09-21
GB201400967D0 (en) 2014-03-05

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