• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
  • 法律状态
  • 优先权
    • 专利摘要:
    system and method for monitoring an underwater structure. it is a system for monitoring an underwater structure. The system includes a sensor arranged in or on one or more tubular components of the underwater structure, where the one or more tubular components of the underwater structure include a riser, a flow line and a submarine umbilical. In addition, the system includes a controller operatively coupled to one or more tubular components of the subsea structure and configured to detect an anomaly in one or more tubular components of the subsea structure. A method for monitoring the subsea structure is also introduced.
    公开号:BR102013031656B1
    申请号:R102013031656-3
    申请日:2013-12-09
    公开日:2020-10-06
    发明作者:Pekka Tapani Sipilä；Marko Klaus Baller；Nicholas Josep Ellson；Parag Vyas
    申请人:General Electric Company；
    IPC主号:
    专利说明:

    FIELD OF THE INVENTION
    [001] The achievements of the present invention refer in general to the monitoring of subsea structures and, more specifically, to the monitoring of pressure and / or stress in risers, tubes and flow lines of the subsea infrastructure. BACKGROUND OF THE INVENTION
    [002] In submarine hydrocarbon production, risers are used to deliver the fluid from the subsea well to a collection facility, such as a production vessel or an injection fluid to the subsea well from the production vessel. Also, during underwater drilling, a riser is used to drill the tube and provide a return path for the drilling fluid. Typically, risers extend from the seabed to the surface and are subjected to bending, torsion and tension forces due to currents and movements of the production vessel. Depending on flow parameters such as flow rate, temperature and consistency, risers may experience an accumulation of stress due to the pressure difference between the environment and a flow channel. In order to ensure the effective operation of the risers, it is beneficial to continuously monitor the stress experienced by the risers. Also, identifying pressure and / or stress variations helps an operator to ensure an efficient transfer of oil from the subsea well to the collection facility .
    [003] Occasionally, voltage sensors such as electrical extensometers and fiber Bragg sensors are employed to perceive the mechanical stress in the risers. In addition, pressure sensors can be used to measure pressure in flow lines and risers. The use of voltage sensors and / or pressure sensors generally provides mechanical coupling with flow lines and risers. The extended use of these sensors results in the loss of resistance of the mechanical adhesion of the sensors. Also, sensors can be subjected to hostile environments for extended periods of time. Additionally, repairing or replacing the sensors can be a challenging task.
    [004] In addition, the riser and / or the flow line are generally designed and employed with a fixed number of sensors arranged in certain locations. However, it may be desirable to either increase the number of sensors in the riser and / or flow line or vary the locations of the sensors during the life of the riser and / or flow line. However, varying the number and / or location of the sensor is a costly and laborious task. DESCRIPTION OF THE INVENTION
    [005] In accordance with aspects of the present invention, a system for monitoring an underwater structure is presented. The system includes a sensor arranged in or on one or more tubular components of the subsea structure, wherein the one or more tubular components of the subsea structure includes a riser, a flow line and a subsea umbilical. In addition, the system includes a controller operatively coupled to one or more tubular components of the subsea structure and configured to detect an anomaly in one or more tubular components of the subsea structure.
    [006] In accordance with another aspect of the present invention, a method for monitoring an underwater structure is presented. The method includes arranging a sensor on or over one or more tubular components of the subsea structure, where the one or more tubular components of the subsea structure include a riser, a flow line and a subsea umbilical and where the sensor is configured to measure a parameter. Also, the method includes analyzing the measured parameter using a controller. Additionally, the method includes identifying an anomaly in one or more of the riser, the flow line and the submarine umbilical based on the analysis of the measured parameter.
    [007] In accordance with another aspect of the present invention, a system is presented. The system includes a monitoring subsystem configured to monitor one or more tubular components of an underwater structure, where the one or more tubular components of the underwater structure includes a riser, a flow line and an underwater umbilical. The monitoring subsystem includes a sensor arranged on or on one or more tubular components of the subsea structure and configured to measure a parameter associated with one or more tubular components of the subsea structure and a controller operatively coupled to one or more tubular components of the subsea structure. subsea structure and configured to detect an anomaly in one or more tubular components of the subsea structure. Furthermore, the system includes an energy capture unit operatively coupled to the monitoring subsystem and configured to energize the sensor and a coupled communication unit of operating mode to the monitoring subsystem and configured to transmit or receive the parameter measured by the sensor. BRIEF DESCRIPTION OF THE DRAWINGS
    [008] These and other features, aspects and advantages of the present invention will be better understood when the following detailed description is read with reference to the attached drawings in which equal characters represent equal parts throughout the drawings, in which: Figure 1 is a diagrammatic representation of a system for monitoring the tubular components of an underwater structure, in accordance with aspects of the present invention; Figures 2 to 4 are diagrammatic representations of the realizations of a portion of the system of Figure 1, according to the aspects of the present invention; Figure 5 is a diagrammatic representation of another embodiment of a portion of the system of Figure 1, in accordance with aspects of the present invention; Figure 6 is a diagrammatic representation of a magnetization of the tubular components of the underwater structure for use in the system of Figure 1, according to the aspects of the present invention; Figure 7 is a diagrammatic representation of an optical fiber based on the sensing of the tubular components of the underwater structure for use in the system of Figure 1, according to the aspects of the present invention; Figure 8 is a diagrammatic representation of another embodiment of a portion of the system of Figure 1, in accordance with aspects of the present invention; Figures 9 and 10 are diagrammatic representations of the realizations of a locking mechanism for coupling a sensor to the tubular components of the subsea structure, according to the aspects of the present invention; and Figure 11 is a flow chart representing a method for monitoring the tubular components of the underwater structure, according to the aspects of the present invention. DESCRIPTION OF ACCOMPLISHMENTS OF THE INVENTION
    [009] Unless otherwise defined, all technical and scientific terms used in this document have the same meaning as commonly understood by a technician in the subject to which this invention belongs. The terms "first", "second" and similar as used in this document do not denote any order, quantity or importance, but are instead used to distinguish one element from the other. Also, the terms "one" and "one" do not denote a limitation of quantity, but instead denote the presence of at least one of the referenced items. The term "or" is intended to be inclusive and mean one, some or all of the items listed. The use of "include", "understand" or "have" and variations of same in this document is intended to cover the items listed later and their equivalents as well as additional items. The terms "connected" and "coupled" are not restricted to physical or mechanical connections or couplings and may include electrical or direct or indirect connections or couplings. Furthermore, the terms "circuit" and "circuit set" and "controller" may include either a single component or a plurality of components, which are either active and / or passive and are connected or otherwise coupled together to provide the described function.
    [010] As will be described in detail hereinafter, several achievements of a system and method for monitoring a tubular component of an underwater structure such as, but not limited to risers, flow lines, subsea umbilicals and tubes are presented. since the system and method use a magnetostrictive technique, the sensing is robust against aging, dirt, moisture, changes in the composition of the ambient fluid and the like.
    [011] Turning now to the drawings, using the example in Figure 1, an embodiment of a system 100 for monitoring one or more tubular components of an underwater structure, according to the aspects of the present invention is depicted. In this embodiment, the system 100 for monitoring the tubular components of the subsea structure 102 may include a power capture unit 104 and a sensor 106.0 System 100 may also include a communication unit 108 and a controller 110. The sensor 106 that is coupled to the structure submarine 102 and controller 110 can generally be referred to as a monitoring subsystem. The monitoring subsystem can be configured to monitor one or more tubular components of subsea structure 102. In one embodiment, the power for communication unit 108 can be supplied using the power capture unit 104. The tubular components of the subsea structure 102 may include a riser 114, a flow line 116 , a submarine umbilical 118 and the like.In one example, the submarine umbilical may include a plurality of tubes. Flow lines 116 are typically undersea pipelines configured to load oil and gas products from an underwater wellhead to a riser foot. 114. Also, flow lines 116 may include connecting tubes and other subsea tubes. In addition, riser 114 is typically connected to a production and / or drilling facility above the seawater surface and is configured to transfer fluids. Fluids can include oil, hydrocarbons and the like in, in one example. Also, the riser114 can be rigid or flexible. In addition, the riser is primarily used for vertical transport. Furthermore, submarine umbilical 118 is positioned between a production and / or drilling and an underwater installation to supply the necessary controls and chemicals to the subsea wells.
    [012] The energy capture unit 104 can be configured to generate electricity by using vibrations from one or more tubular components of subsea structure 102 and / or temperature variations of one or more tubular components from subsea structure 102. The temperature variations of the one or more tubular components of the subsea structure 102 may include a difference in temperature along the one or more tubular components of the subsea structure 102, a difference in temperature between the one or more tubular components of the subsea structure 102 and the water In another example, the energy capture unit 104 can be configured to generate electricity using light, seawater movement, microbiological technologies and the like. In one example, light used to generate electricity may include solar radiation. In addition, in a non-limiting example, the energy capture unit 104 may include a battery, a the direct current source, an alternating current source and the like. Ademias, the energy capture unit 104 can be operatively coupled to sensor 106 and can be configured to energize sensor 106.
    [013] In addition, in one embodiment, sensor 106 can be arranged on or on riser 114, flow line 116, submarine umbilical 118 and / or other tubular components of subsea structures. Particularly, sensor 106 can be arranged on the external periphery of riser 114, flow line 116, submarine umbilical 118 and the other tubular components of subsea structure 102.0 sensor 106 can be configured to measure / perceive a parameter. The term parameter, as used herein, can include a pressure, a load, compression stress, residual stress, longitudinal stress, tension stress, curvature stress, torque-induced stress, a flow property of a production fluid or combinations thereof.
    [014] In addition, communication unit 108 can be operatively coupled to sensor 106. Communication unit 108 can be configured to transmit and / or receive a parameter measured / determined by sensor 106. In addition, in an example limiting device, communication unit 108 can be arranged in a remote location. In another example, communication unit 108 can be placed on or on riser 114, flow line 116, submarine umbilical 118 and other tubular components of structures Also, communication unit 108 may include an electronic circuitry such as a transmitter, receiver and the like. Furthermore, in a non-limiting example, the transmitter of communication unit 108 may be arranged on or on the riser 114 , the flow line 116, the submarine umbilical 118 and the other tubular components of the subsea structures, while the receiver of the communication unit 108 can be arranged in a remote location. In addition, the energy capture unit 104 and the communication unit 108 can be operatively coupled to sensor 106 using a wired connection, a wireless connection and the like.
    [015] Additionally, controller 110 may be a subsea control module (SCM). Although Figure 1 depicts communication unit 108 and controller 110 as separate units, in certain embodiments, controller 110 may include the unit communication device 108. Furthermore, controller 110 can be operatively coupled to communication unit 108. The parameter measured by sensor 106 can be communicated by communication unit 108 to controller 110.
    [016] In one embodiment, controller 110 may include processing unit 112. Processing unit 112 can be configured to analyze the parameter measured by sensor 106. Furthermore, processing unit 112 can be configured to identify an anomaly in one or more tubular components of subsea structures 102 based on an analysis of the parameter. Also, the anomaly in one or more tubular components of subsea structures 102 may include an anomaly in one or more of the riser 114, flow lines 116, submarine umbilical 118 and the like. Additionally, based on the identification of the anomaly, controller 110 can be configured to regulate pressure, stress, flow property and the like, on riser 114, on flow line 116, on submarine umbilical 118 and in other tubular components of the underwater structure 102.0 term anomaly, as used in this document, may include a condition that could lead to a failure in an o u more among riser 114, flow line 116 and other tubular components of the subsea structure.Additionally, controller 110 can also be configured to control the operation of sensor 106 which measures pressure, flow and stress in one or more tubular components of underwater structures 102.
    [017] Also, sensor 106 may include a magnetic field sensor, a magnetostrictive sensor, a Villari effect sensor, an inductive coil, an acoustic transducer, an optical fiber, a magnetic sensor or combinations thereof. In one embodiment, sensor 106 may also include a temperature sensor, a humidity sensor, a chemical sensor and the like. The term operatively coupled as used herein includes wire coupling, wireless coupling, electrical coupling , magnetic coupling, capacitive coupling, optical coupling, radio communication, communication based on software or combinations thereof.
    [018] Referring now to Figures 2 to 4, diagrammatic representations 200, 206, 212 of carrying out a portion of a system for monitoring the tubular components of an underwater structure, such as the system 100 in Figure 1 are depicted. , Figures 2 to 4 are diagrammatic representations of a portion of the tubular components of the underwater structure, such as the tubular components of the underwater structure 102 of Figure 1.
    [019] Figure 2 is a diagrammatic representation 200 of a riser 202, such as riser 114 of Figure 1. As shown in Figure 2, a sensor 204 such as sensor 106 in Figure 1 can be arranged on an external periphery of the riser 202.
    [020] Furthermore, Figure 3 is a diagrammatic representation 206 of a portion of a flow line 208, such as flow line 116 of Figure 1. Reference numeral 210 is representative of a sensor disposed on the outer periphery of the line flow rate 208.
    [021] Turning now to Figure 4, a diagrammatic representation 212 of a portion of a submarine umbilical 214, such as submarine umbilical 118 is depicted. Also, a sensor 216 is disposed on an outer periphery of submarine umbilical 214.It can it should be noted that although the embodiments of Figures 2 to 4 depict sensors 204, 210, 216 as being arranged on the outer periphery of riser 202, on flow line 208 and on submarine umbilical 214, respectively, the sensors can also be arranged in close proximity riser 202, flow line 208 and submarine umbilical 214.
    [022] It can be noted that the stress experienced by the tubular components of the underwater structure is a linear function of a difference in pressure between the inside of a tubular component and the pressure outside the tubular component of the underwater structure. In one example, stress can include circumferential stress. Consequently, any variation in pressure in flow line 208, riser 202 and the tubes within submarine umbilical 214 may result in variation in stress in flow line 208, riser 202 and / or in tubes within the submarine umbilical 214.This stress can be captured by sensors 204, 210, 216 arranged in flow line 208, riser 202 and / or submarine umbilical 214. Also, the stress experienced by flow line 208, riser 202 and / or by submarine umbilical 214 can be a combination of residual stress, applied stress, curvature stress and stress due to stretching and compression.Additionally, for the riser 202 other parameters s, such as, but not limited to, wall thickness of riser 202, internal diameter of riser 202, Young's modulus and Poisson's ratio of riser202 material can also be used in the stress calculation. Similarly, stress can be calculated for flow line 208 and submarine umbilical 214.
    [023] Turning now to Figure 6, a diagrammatic representation 300 of another embodiment of a portion of a system 100 of Figure 1, according to the aspects of the present invention, is presented. Particularly, Figure 5 depicts the use of a sensor, such as an inductive coil in or over a tubular component of the subsea structure, such as, but not limited to, a flow line, riser and subsea umbilical. System 300 may include a tubular component of the subsea structure such as a riser 302.In the present example, riser 302 may include a coating 304 disposed on the outer periphery of riser 302. Furthermore, system 300 may include a sensor such as inductive coil 306 disposed on the outer periphery of riser 302. Additionally, the sensor 302 can also be arranged on the outer periphery of coating 304. In one example, coating 304 may include a polymer coating such as a polyurethane coating. However, a cement coating can also be employed. In addition, the inductive coil 306 can be energized using an alternating current and this in turn can induce a magnetic field in the riser 302. In the example of Figure 5, the inductive coils 306 can be magnetically coupled to the riser 302.
    [024] It can be noted that any anomaly in one or more tubular components of an underwater structure such as riser 302 can result in a substantial variation in pressure in riser 302. In one example, excessive movement on an underwater surface can result in high tension loads and / or stress causing the riser material to sag and burst. This burst of riser 302 can lead to a drop in pressure on riser 302.In an alternative example, a leak can be caused in riser 302 due to erosion . This leak can, in turn, cause a pressure drop in the riser 302, thereby resulting in a decrease in pressure in the riser 302.These variations in pressure in the riser 302 can be manifested in the form of stress in the riser 302.0 stress experienced by the riser 302 can result in changes in the magnetostrictive property of the riser 302, thereby causing a variation in the magnetic field induced in the riser 302. This variation in the induced magnetic field and consequently the stress experienced by the riser 302 can be detected by the inductive coils 306. In one example , the stress detected by inductive coil 306 can also be referred to as a parameter.
    [025] In addition, inductive coils 306 can be operatively coupled to a communication unit, such as communication unit 108 in Figure 1. Any measurements can be communicated from inductive coils 306 to the communication unit. the communication unit can be coupled to a controller, such as controller 110 in Figure 1.0 controller can be configured to analyze the parameter. Based on the analysis of the parameter, the type of fault in the riser 302 can be determined and / or an action corrective action can be taken to prevent any failure in the riser 302. Furthermore, in another example, parameter analysis can assist in calculating the remaining life of the riser 302. In addition, the system 300 in Figure 5 may include a field sensor. reference 308 configured to eliminate or minimize any error due to a background magnetic field. The reference field sensor 308 can be positioned on the 304 coating, in one example. and the background magnetic field can include natural magnetic fields, fields due to permanent magnetization of components, fields due to moving magnets, fields due to ferromagnetic objects, fields induced by electric currents or combinations thereof. In one embodiment, the 300 system it can also include an auxiliary temperature sensor.
    [026] Referring to Figure 6, a diagrammatic representation 400 of yet another embodiment of a portion of the system 100 to monitor the one or more tubular components of the subsea structure, according to the aspects of the present invention, is depicted. of Figure 6 can include a riser 402 which has a coating 404 on the outer periphery of riser 402. As noted earlier, the coating 404 can be a cement coating or a polymer coating. According to aspects of the present invention, the riser 402 can include one or more segments capable of sensing. In one example, the segments capable of sensing can include one or more magnetically encoded regions. In the example in Figure 6, the riser 402 can include one or more magnetically encoded regions. The magnetically encoded regions can include a magnetized line that has a first polarity 406 and a magnetized line that has a second polarity 408.These magnetized lines that have the first and second polarities 406, 408 can be formed using a determined value of electric current, a determined value of magnetic field or both. In one embodiment, the magnetized lines 406, 408 can be created in riser 402 before installation and commissioning of the tubular components of the underwater structure However, in another example, to magnetize the 402 riser after installation, the 404 coating can be removed and the 402 can be magnetized.
    [027] Also, in a non-limiting example, the riser 402 can be configured to behave as a sensor by applying acoustic signals, ultrasound signals and similar to the riser 402. Furthermore, if the riser 402 is subjected to stress due to any anomalies in it, the riser 402 may experience a variation in pressure. Also, the stress caused on the riser 402 may cause the magnetostrictive property of the riser 402 to change. This change in the magnetostrictive property of the riser 402 can, in turn, result in changes in the magnetic field associated with the magnetized lines 406, 408 of the riser 402.The change in the magnetic field can be measured with the use of a 410 magnetic field sensor. In addition, magnetic field sensor 410 can be placed on riser 402. In an alternative example, magnetic field sensor 410 can be placed on coating 404. It can be noted that riser 402 with magnetized lines 406, 408 can also be configured for use as a sensor, in one example.
    [028] Also, in one embodiment, the 410 magnetic field sensor can be coupled to the 402 riser. In one example, the 402 riser can be made of a high-strength metal alloy. Furthermore, the 410 magnetic field sensor can coupled to the metal surface of the riser 402. In another example, the magnetic field sensor 410 can be arranged in close proximity to the metal surface of the riser 402.0 magnetic field sensor 410 can be configured to measure a parameter and communicate the measured parameter In addition, the parameter can be transmitted from the communication unit to a controller, such as controller 110 in Figure 1, for processing. In particular, the controller can be configured to analyze the parameter to detect the presence any anomalies in the riser 402. In a non-limiting example, parameter analysis can facilitate the identification of a condition that can lead to a failure. Failures in the riser 402 can include an error riser, a leak in the riser, a rupture in the riser, an increase in the load on the riser, and the like. However, in certain embodiments, the parameter measured by the magnetic field sensor 410 can be transmitted wirelessly to the controller via an inductive sensor, a radio frequency link and the like. In addition, the 400 system can also include a power capture unit and a communication unit. Also, the power for the magnetic field sensor 410 can be communicated / received without wire from the energy capture unit. In the example in Figure 6, the reference numeral 412 is representative of a wireless power and communication link for the magnetic field sensor 410. In addition, the use of the magnetic field sensor 410 assists in the identification of any anomaly in one or more tubular components of the underwater structure.
    [029] In addition, the magnetized lines 406, 408 can run along an entire length of the riser 402. In one example, the magnetized lines 406, 408 can be formed along different longitudinal segments of the riser 402. In one example , the magnetized lines 406, 408 along the length of the riser 402 can be discontinuous.In an alternative embodiment, the magnetized line 406, 408 can be in a spiral configuration along the riser 402. Although the magnetization in the longitudinal and spiral configurations revealed in the present document, the magnetization of the riser 402 in other orientations is also contemplated. Also, the magnetization of the other tubular components of the underwater structure is also contemplated.
    [030] Additionally, the magnetized line of the first polarity 406 can include magnetization domains 414 that have an upward orientation. Also, the magnetized line of the second polarity 408 can include magnetization domains 416 that have a different orientation. In one example, the magnetization domains 416 may have a downward orientation.Depending on the magnetoresistance of the metal of the riser 402 and the stress experienced by the metal of the riser 402, the orientation of the magnetization domains 414, 416 can be changed.Additionally to the change in the orientation of the domains of magnetization 414, 416, the magnetic susceptibility of material can also be altered. The change in magnetic susceptibility of material can be perceived with the use of magnetic field sensors 410, in one embodiment. Furthermore, the sensing of the change in the magnetic susceptibility of material can assist in the identification of an anomaly, such as fatigue in the riser 402. In a similar way, a the anomaly in other components, such as flow lines and submarine umbilicals can also be identified.
    [031] Turning now to Figure 7, a diagrammatic representation 500 of the sensing based on optical fiber exemplifying a tubular component of the underwater structure, such as, however, without limitation, a riser, according to the aspects of the present invention , is presented. The system 500 in Figure 7 can include a riser 502 that has a coating 504 on the outer periphery of the riser 502. Furthermore, the riser 502 can include the magnetized lines in the spiral configuration. The magnetized lines in the spiral configuration can include a magnetized line from the first polarity 506 and a magnetized line of the second polarity 508.
    [032] Additionally, an optical fiber 510 can be wound in a spiral configuration between the magnetized line of the first polarity 506 and the magnetized line of the second polarity 508. Also, the optical fiber 510 can be operatively coupled to a detector and optical source 512.The detector and optical source unit 512 can be configured to guide light through the optical fiber 510. Additionally, the detector and optical source unit 512 can be configured to detect the light emitted by the optical fiber 510.
    [033] Optical fiber 510 can be based on a magneto-optical effect. Consequently, optical fiber 510 can be sensitive to changes in a magnetic field. Furthermore, the sensitivity of optical fiber 510 can be increased when optical fiber 510 is coiled between the magnetized line of the first polarity 506 and the magnetized line of the second polarity 508.The orientation of the magnetization domains in the magnetized lines of the first polarity 506 and in the magnetized lines of the second polarity 508 can be changed when the riser 502 is subjected to stress . As noted earlier, riser 502 may experience a change in stress as a result of pressure variation in riser 502. Also, the pressure variation in riser 502 may occur due to an anomaly in riser 502. As noted in this document above, the optical fiber 510 is sensitive to changes in a magnetic field and, therefore, the optical fiber 510 can be sensitive to changes in the orientation of the magnetization domains which, in turn, can affect the signal in the optical fiber. Also, the optical properties of the 510 optical fiber can be changed. Therefore, the light guided by the optical fiber 510 is also altered which, in turn, helps to identify the stress experienced by the riser 502.
    [034] In one embodiment, the optical fiber 510 can be wound in a spiral configuration along the magnetized lines of the first polarity 506 and the magnetized lines of the second polarity 508.In another embodiment, the optical fiber 510 can be wound in the configuration spiraled on the outer periphery of the magnetized lines of the first polarity 506 and of the magnetized lines of the second polarity 508.While the example in Figure 7 represents a spiral configuration of the optical fiber winding 510, other optical fiber winding configurations are also contemplated.
    [035] Referring now to Figure 8, a diagrammatic representation 600 of another embodiment of a portion of the system for monitoring the tubular components of the subsea structure 100, in accordance with aspects of the present invention, is depicted. In particular, Figure 8 represents a cross-sectional view of a system for sensing based on acoustics in a riser. In the example of Figure 8, the system for sensing based on acoustics 600 includes a riser 602 that has a coating 604 on the outer periphery of riser 602. Acoustic sensors 608 can be arranged on riser 602 and / or coating 604. As noted earlier, coating 604 can include a cement coating or a polymer coating.
    [036] Furthermore, an acoustic signal 606 can be guided through the riser 602. Consequently, the riser 602 can be configured to behave as a sensor. Any anomalies in the riser 602 can result in a variation in pressure in the riser 602, due to the variation in pressure on riser 602, riser 602 may experience stress. Also, stress on riser 602 may cause the flight time of acoustic signal 606 to vary. Consequently, the variation in flight time of acoustic signal 606 can be perceived acoustic sensors 608 to determine the stress in the riser 602 can be determined. The determined stress can then be analyzed to detect any anomalies in the riser 602. In a similar way, anomalies in one or more tubular components of the subsea structure can also In a non-limiting example, the 608 acoustic sensor can be configured to accept signals within a specified flight time window, thereby unwanted euphonies and / or interference from any reflected signals. Although the realization of Figures 2 to 8 are described in reference to the monitoring of the riser, the monitoring of the flow lines, the submarine umbilicals and other tubular components of the subsea structures is also contemplated.
    [037] Turning now to Figures 9 and 10, the diagrammatic representations of the locking mechanisms for coupling a sensor, such as sensor 106 in Figure 1, to the tubular component of the subsea structure, according to the aspects of the present invention, are portrayed. In particular, the locking mechanism can be used to operatively couple a sensor in close proximity to a riser.
    [038] Figure 9 depicts a diagrammatic representative 700 of a locking mechanism for locking a sensor in close proximity to a riser. The system 700 in Figure 9 may include a riser 702 with a polymer and / or cement coating 704. A sensor 706 can be attached to cover 704 using a mechanical belt such as a pressure belt 708. Similarly, sensor 706 can also be coupled to cover 704 with the use of a mechanical fastener 710, such as, but without limitation, a screw and a dowel. In one example, sensor 706 can be attached to riser 702 and can be incorporated within coating 704. Also, sensor 706 can be attached to riser 702 and / or coating 704 using adhesives.
    [039] Referring again to Figure 10, a diagrammatic representation 720 of another embodiment of the locking mechanism for locking a sensor726 in close proximity to a riser722 is depicted. The sensor 726 can be operatively coupled in close proximity to the riser 722 using a set of tracks 728. In addition, a liner 724 can be arranged on the outer periphery of the riser 722. In one example, the sensor 726 can be attached to the riser 722 or coating 724 using a device used remotely. Track set 728 can include a motor 730. Motor 730 can assist in moving track set 728 along a length of riser 722. Furthermore, track set 728 can be controlled using a controller 732, such as the controller 110 of Figure 1. Controller 732 can be configured to control the movement of the set of tracks 728. Also, a communication link and / or power supply can be provided using a cable 734. Alternatively, the connection link communication and / or power supply can be provided using a wireless link. Although the examples in Figures 9 and 10 depict realizations of a locking mechanism to lock the sensor in close proximity to the riser, similar locking mechanisms can be employed to lock the sensor to the flow lines, submarine umbilical and other tubular component of the subsea structure .
    [040] Figure 11 is a flow chart 900 that represents a method for monitoring the tubular component of the underwater structure, according to the aspects of the present invention. The method is described in relation to Figures 1 to 10. In step 902, a sensor 106 it can be arranged on or on a riser 114, a flow line116, an underwater umbilical118 and other tubular components of the subsea structure. More particularly, sensor 106 can be disposed on the outer periphery of riser 114, of the flow line116, of the subsea umbilical118 and other tubular components of the subsea structure. Sensor 106 can be configured to measure a parameter. The parameter can include pressure, compression stress, circumferential stress, residual stress, longitudinal stress, tension stress, curvature stress, stress induced by torque and their equivalents. In one embodiment, the parameter may include a signature that is representative of a change in pressure with time at rise r.Additionally, sensor 106 can be located in one or more of the riserl 14, the flow line116 and other tubular components of the subsea structure by means of a locking mechanism, such as the mechanical fixing locking mechanisms 710 and set of 728 mats.
    [041] In addition, in step 904, the measured parameter can be analyzed using a controller, such as controller 110 in Figure 1. Analysis of the measured parameter can include comparing the measured parameter to a threshold value. , the threshold value may include a signature that is representative of a change in pressure over time under normal riserl 14 operating conditions and / or other components such as flow lines 116 and submarine umbilicals 118 or in the absence of any anomalies in the riserl 14 and / or other components of the subsea structure. In a non-limiting example, the threshold value may include the stress measured or calculated under normal operating conditions of the riser 202. Also, in one example, the threshold value can be stored in the controller.
    [042] In step 906, an anomaly in the riser 114 and / or other components can be identified based on the analysis of the measured parameter. In one embodiment, the anomaly in the riser 114 and / or the other tubular components of the subsea structure can be identified using one or more of an analytical model, a physics-based model and a self-teaching mechanism to analyze the parameter. As noted earlier, the term anomaly may include a condition that could lead to a failure in one or more of the riser 114, the flow line 116 and other tubular components of the subsea structure.
    [043] In one embodiment, in the identification of any anomalies in one or more tubular components of the subsea structure, an alarm or an indicator can be generated. Also, since the anomaly in riser 114, flow line 116 and others tubular components of the subsea structure are identified, the controller can be configured to regulate pressure and / or stress in the riserl 14, in the flow line116 and in another tubular component of the subsea structure to avoid additional variation in pressure and / or stress in the components subsea structure. In one example, the controller may include built-in intelligence to control pressure / stress in the subsea structure tubular components. Alternatively, since the riser, flow line, and other tubular components anomaly submarine is identified, an operator can manually regulate pressure and / or stress in riserl 14, flow line 116 and the like.
    [044] Furthermore, the previous examples, demonstrations and process steps such as those that can be performed by the system can be deployed by suitable code in a processor-based system, such as a general purpose or special purpose computer. it should also be noted that different deployments of the present technology may perform some or all of the steps described in this document in different orders or substantially concurrently, that is, in parallel. Furthermore, functions can be implemented in a variety of programming languages, including, but not limited to, C ++ or Java. Such code may be stored or adapted for storage in one or more machine-readable tangible media, such as on data repository chips, local or remote hard drives, optical disks (ie, CDs or DVDs), memory or other means that can be accessed by a processed based system to execute the stored code.Note that tangible media can comprise paper or another suitable medium on which instructions are printed. For example, instructions can be captured electronically by scanning the paper or otherwise, then compiled, interpreted or otherwise processed in a properly if necessary and then stored in memory or data repository.
    [045] The various achievements of the system and method for monitoring an undersea structure described in this document above help to improve the effectiveness of monitoring a riser, a flow line and other tubular components of the subsea structure. system and method use a magnetostrictive technology, the sensing is robust against aging, dirt, humidity, changes in the composition of the ambient fluid and the like.Additionally, since the magnetostrictive properties vary with the mechanical properties of the riser, the flow line and of other tubular components of the subsea structure, the usable life and stability of the tubular components can be improved.
    [046] Although the invention has been described with reference to the achievements, it will be understood by the person skilled in the art that various changes can be made and equivalents can be replaced by elements of the same without departing from the scope of the invention. In addition, many changes can be made to adapt a particular situation or material to the teachings of the invention without departing from its essential scope.
    权利要求:
    Claims (23)
    [0001]
    1. SYSTEM (100, 200, 300, 400, 500, 600, 700) FOR MONITORING A SUBMARINE STRUCTURE (102), characterized by the system (100) comprising: a sensor (106, 204, 210, 216, 302, 410, 510, 608, 706, 726) arranged on or on one or more tubular components of the underwater structure (102), wherein the one or more tubular components of the underwater structure (102) comprise a riser (114, 202, 302, 402, 502, 602, 702, 722), a flow line (116, 208) and a submarine umbilical (118, 214), and where the sensor comprises a fiber optic sensor (510) configured to detect a change in a field magnetic and to measure a parameter based on changing the magnetic field; and a controller (110, 732) operatively coupled to one or more tubular components of the subsea structure (102) and configured to detect an anomaly in one or more tubular components of the subsea structure (102).
    [0002]
    2. SYSTEM (100, 200, 300, 400, 500, 600, 700) according to claim 1, characterized in that it additionally comprises an energy capture unit (104) operatively coupled to the sensor (106, 204, 210, 216, 302, 410, 510, 608, 706, 726) and configured to energize the sensor (106, 204, 210, 216, 302, 410, 510, 608, 706, 726).
    [0003]
    3. SYSTEM (100, 200, 300, 400, 500, 600, 700) according to claim 2, characterized in that it additionally comprises a communication unit (108) operatively coupled to the sensor (106, 204, 210, 216, 302, 410, 510, 608, 706, 726) and configured to transmit or receive a parameter measured by the sensor (106, 204, 210, 216, 302, 410, 510, 608, 706, 726).
    [0004]
    4. SYSTEM (100, 200, 300, 400, 500, 600, 700), according to claim 3, characterized in that the energy capture unit (104) and the communication unit (108) are operatively coupled to the sensor using a wired connection, a wireless connection, or a combination of both.
    [0005]
    5. SYSTEM (100, 200, 300, 400, 500, 600, 700), according to claim 2, characterized by the energy capture unit (104) being configured to generate electricity with the use of vibrations from one or more tubular components of the subsea structure (102), a temperature variation of the one or more tubular components of the subsea structure (102), light, seawater movement or combinations thereof.
    [0006]
    6. SYSTEM (100, 200, 300, 400, 500, 600, 700), according to claim 1, characterized in that the controller (110) is additionally configured to: control the operation of one or more sensors (106, 204, 210, 216, 302, 410, 510, 608, 706, 726) to measure pressure, flow and stress in one or more tubular components of the subsea structure (102); and regulating one or more of the pressure, flow and stress in one or more tubular components of the underwater structure (102).
    [0007]
    7. SYSTEM (100, 200, 300, 400, 500, 600, 700), according to claim 1, characterized by the sensor (106, 204, 210, 216, 302, 410, 510, 608, 706, 726) comprising a magnetostrictive sensor (410), a magnetic sensor (410), an acoustic transducer (608), a temperature sensor or combinations thereof.
    [0008]
    8. SYSTEM (100, 200, 300, 400, 500, 600, 700), according to claim 1, characterized in that one or more tubular components of the subsea structure (102) comprise one or more segments with sensing capacity.
    [0009]
    9. SYSTEM (100, 200, 300, 400, 500, 600, 700) according to claim 8, characterized in that the one or more segments capable of sensing comprise one or more magnetically encoded regions.
    [0010]
    10. SYSTEM (100, 200, 300, 400, 500, 600, 700) according to claim 9, characterized in that one or more magnetically encoded regions comprise a plurality of magnetized lines with at least two polarities (406, 408, 506, 508) formed along a length of one or more tubular components of the subsea structure (102).
    [0011]
    11. SYSTEM (100, 200, 300, 400, 500, 600, 700) according to claim 9, characterized in that the one or more magnetically encoded regions additionally comprise a plurality of magnetized lines with at least two polarities (406, 408 , 506, 508) in a spiral configuration around one or more tubular components of the subsea structure (102).
    [0012]
    12. SYSTEM (100, 200, 300, 400, 500, 600, 700), according to claim 11, characterized in that the optical fiber sensor (510) is wound along the plurality of magnetized lines in the spiral configuration around one or more tubular components of the subsea structure (102).
    [0013]
    13. SYSTEM (100, 200, 300, 400, 500, 600, 700) according to claim 1, characterized in that it additionally comprises a coating (304, 404, 504, 604, 704, 724) arranged in one or more tubular components of the underwater structure (102).
    [0014]
    14. SYSTEM (100, 200, 300, 400, 500, 600, 700), according to claim 13, characterized by the sensor (106, 204, 210, 216, 302, 410, 510, 608, 706, 726) be incorporated into the coating (304, 404, 504, 604, 704, 724), arranged in the coating (304, 404, 504, 604, 704, 724) or a combination thereof.
    [0015]
    15. SYSTEM (100, 200, 300, 400, 500, 600, 700), according to claim 1, characterized in that it additionally comprises a locking mechanism configured to operatively couple the sensor to one or more tubular components of the structure underwater (102).
    [0016]
    16. SYSTEM (100, 200, 300, 400, 500, 600, 700), according to claim 15, characterized in that the locking mechanism comprises a track motor, a remotely employed device, an adhesive, a mechanical coupling, a mechanical fastener, or a combination of both.
    [0017]
    17. METHOD (900) FOR MONITORING A SUBMARINE STRUCTURE (102), characterized by comprising: having (902) a sensor (106) in or on one or more tubular components of the subsea structure (102), in which one or more components tubes of the subsea structure (102) comprise a riser (114), a flow line (116) and a subsea umbilical (118) and where the sensor (106) comprises a fiber optic sensor configured to detect a change in a field magnetic and to measure a parameter based on changing the magnetic field; analyze (904) the parameter measured using a controller (110); and identifying (906) an anomaly in one or more of the riser (114), the flow line (116) and the submarine umbilical (118) based on an analysis of the parameter.
    [0018]
    18. METHOD (900), according to claim 17, characterized in that it further comprises magnetizing one or more of the riser (114), the flow line (116) and the submarine umbilical (118).
    [0019]
    19. METHOD (900), according to claim 18, characterized by magnetizing one or more of the riser (114), the flow line (116) and the submarine umbilical (118) comprising magnetizing one or more of the riser ( 114), the flow line (116) and the submarine umbilical (118) in a spiral configuration.
    [0020]
    20. METHOD (900), according to claim 18, characterized by magnetizing one or more of the riser (114), the flow line (116) and the submarine umbilical (118) comprising magnetizing one or more of the riser ( 114), the flow line (116) and the submarine umbilical (118) in a longitudinal configuration.
    [0021]
    21. METHOD (900), according to claim 18, characterized by magnetizing one or more of the riser (114), the flow line (116) and the submarine umbilical (118) comprising applying a determined value of an electric current , a determined value of a magnetic field or a combination thereof to one or more of the riser (114), the flow line (116) and the submarine umbilical (118).
    [0022]
    22. METHOD (900), according to claim 17, characterized by the parameter comprising a pressure, a load, compression stress, residual stress, longitudinal stress, tension stress, curvature stress, torque-induced stress, a flow property of a production fluid or combinations thereof.
    [0023]
    23. SYSTEM (100, 200, 300, 400, 500, 600, 700) characterized by comprising: a monitoring subsystem configured to monitor one or more tubular components of an underwater structure (102), in which the one or more tubular components of the subsea structure (102) comprise a riser (114, 202, 302, 402, 502, 602, 702, 722), a flow line (116, 208) and a subsea umbilical (118, 214) and in which the subsystem monitoring system comprises: a sensor (106, 204, 210, 216, 302, 410, 510, 608, 706, 726) disposed in or on one or more tubular components of the subsea structure (102) in which the sensor comprises a sensor optical fiber (510) configured to detect a change in a magnetic field and measure a parameter associated with one or more tubular components of the subsea structure (102) based on the change in the magnetic field; a controller (110, 732) operatively coupled to one or more tubular components of the subsea structure (102) and configured to detect an anomaly in one or more tubular components of the subsea structure (102); an energy capture unit (104) operatively coupled to the monitoring subsystem and configured to energize the sensor (106, 204, 210, 216, 302, 410, 510, 608, 706, 726); and a communication unit (108) operatively coupled to the monitoring subsystem and configured to transmit or receive the parameter measured by the sensor (106, 204, 210, 216, 302, 410, 510, 608, 706, 726).
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    同族专利:
    公开号 | 公开日
    SG2013093612A|2014-07-30|
    AU2013273664A1|2014-07-10|
    AU2013273664B2|2017-03-02|
    CN103899294A|2014-07-02|
    BR102013031656A2|2015-11-10|
    BR102013031656A8|2016-07-19|
    US20140174752A1|2014-06-26|
    US9228428B2|2016-01-05|
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    法律状态:
    2015-11-10| B03A| Publication of a patent application or of a certificate of addition of invention [chapter 3.1 patent gazette]|
    2016-07-19| B03H| Publication of an application: rectification [chapter 3.8 patent gazette]|Free format text: REFERENTE A RPI 2340 DE 10/112015, QUANTO AO ITEM (30). |
    2018-11-21| B06F| Objections, documents and/or translations needed after an examination request according [chapter 6.6 patent gazette]|
    2020-04-07| B06U| Preliminary requirement: requests with searches performed by other patent offices: procedure suspended [chapter 6.21 patent gazette]|
    2020-07-28| B09A| Decision: intention to grant [chapter 9.1 patent gazette]|
    2020-10-06| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 09/12/2013, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US13/726,667|2012-12-26|
    US13/726,667|US9228428B2|2012-12-26|2012-12-26|System and method for monitoring tubular components of a subsea structure|
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