Pipeline network monitoring

Abstract

A pipeline monitoring system includes: at least one collar configured to be mounted on a pipeline conveying fluid; a transducer coupled to the at least one collar and configured to output a plurality of ultrasonic waves traveling through the pipeline; at least one pulse receiver electrically coupled to the plurality of transducers and configured to generate electrical energy from a power source; and a control system communicatively coupled to the pulse receiver. The control system is configured to perform operations including: operating the pulse receiver to transmit the generated electrical energy to the transducers, thereby outputting ultrasonic waves; receiving feedback data through the transducers, the feedback data including at least one ultrasonic waveform; and determining the location of material anomalies on the pipeline based on the ultrasonic waveforms.

Description

Cross-reference to related applications

[0001] This application claims priority to U.S. Patent Application No. 18 / 519,526, filed November 27, 2023, the entire contents of which are incorporated herein by reference. Technical Field

[0002] This disclosure relates to systems and methods for monitoring materials in pipeline networks, such as using predictive guided wave ultrasonic scanning systems to detect material corrosion. Background Technology

[0003] Corrosion, regardless of type, is always a serious form of degradation for pipeline systems. As materials degrade and are exposed to corrosive environments, corrosion compromises the integrity of the equipment. This is particularly challenging in the oil and gas industry, making measures to combat such obstacles a viable part of corporate strategic objectives. Summary of the Invention

[0004] In one example embodiment, a pipeline monitoring system includes: at least one collar configured to be mounted on a pipeline conveying fluid; a plurality of transducers coupled to the at least one collar and configured to output a plurality of ultrasonic waves that travel through the pipeline in at least one direction parallel to the flow direction of the fluid in the pipeline; at least one pulse receiver electrically coupled to the plurality of transducers and configured to generate electrical energy from a power source; and a control system communicatively coupled to the pulse receiver. The control system is configured to perform operations including: operating the at least one pulse receiver to transmit the generated electrical energy to the plurality of transducers, thereby outputting the plurality of ultrasonic waves; receiving feedback data through the plurality of transducers, the feedback data including at least one ultrasonic waveform; and determining, based on the at least one ultrasonic waveform, the location of a material anomaly on the pipeline.

[0005] In aspects that can be combined with exemplary embodiments, at least one collar includes a plurality of collars, each collar being configured to be installed on the pipe at a unique location on the pipe.

[0006] In another aspect, which can be combined with any of the preceding aspects, the multiple transducers include multiple sets of transducers, wherein each set of transducers is coupled to one of a plurality of collars.

[0007] In the other aspect, which can be combined with any of the previous aspects, each unique location of the pipeline is 50 meters away from the adjacent unique location of the pipeline.

[0008] In another aspect, which can be combined with any of the preceding aspects, the operation includes: operating at least one pulse receiver to transmit the generated electrical energy to multiple sets of transducers to output multiple ultrasonic waves; receiving feedback data through the multiple sets of transducers, the feedback data including at least one ultrasonic waveform; and determining multiple locations on the pipe, each including a specific material anomaly, based on the at least one ultrasonic waveform.

[0009] In another aspect, which can be combined with any of the preceding aspects, the operation includes: generating a model of the pipe, the model including multiple locations on the pipe, each including a specific material anomaly; performing continuous iterations of the following operations over a time period: operating at least one pulse receiver to transmit the generated electrical energy to multiple sets of transducers, thereby outputting multiple ultrasonic waves; receiving feedback data through the multiple sets of transducers, the feedback data including at least one ultrasonic waveform; and determining, based on at least one ultrasonic waveform, multiple locations on the pipe, each including a specific material anomaly.

[0010] The other side, which can be combined with any of the previous aspects, includes the operation of updating the pipeline model on each successive iteration.

[0011] In another aspect, which can be combined with any of the previous aspects, the model includes a machine learning model.

[0012] In another aspect, which can be combined with any of the preceding aspects, one or more characteristics of a plurality of ultrasonic waves are selected based on at least one of the pipe material or pipe size, such that the plurality of ultrasonic waves travel through the pipe in at least one direction parallel to the flow direction of the fluid in the pipe.

[0013] In another aspect that can be combined with any of the preceding aspects, one or more characteristics include at least one of amplitude or frequency.

[0014] In another aspect, which can be combined with any of the preceding aspects, at least one collar is configured to be mounted around the outer periphery of the pipe, and a plurality of transducers are coupled to at least one collar around the outer periphery at equally spaced radial intervals.

[0015] In another aspect that can be combined with any of the preceding aspects, at least one direction parallel to the flow direction of the fluid in the pipe includes: a first direction parallel to the flow direction of the fluid in the pipe; and a second direction parallel to the flow direction of the fluid in the pipe and opposite to the first direction.

[0016] In another aspect that can be combined with any of the preceding aspects, material anomalies include corrosive materials in the pipeline.

[0017] In another aspect that can be combined with any of the preceding aspects, the fluid includes hydrocarbon fluids.

[0018] In another example embodiment, a method for monitoring pipeline material includes: operating at least one pulse receiver to transmit electrical energy from a power source to a plurality of transducers, the plurality of transducers being coupled to at least one collar mounted on a pipeline conveying fluid; outputting a plurality of ultrasonic waves based on the electrical energy transmitted from the at least one pulse receiver to the plurality of transducers, the plurality of ultrasonic waves traveling through the pipeline in at least one direction parallel to the flow direction of the fluid in the pipeline; receiving feedback data through the plurality of transducers, the feedback data including at least one ultrasonic waveform; and determining, based on the at least one ultrasonic waveform, the location on the pipeline including a material anomaly.

[0019] Aspects that can be combined with the example implementation include: operating at least one pulse receiver to transmit electrical energy from a power source to multiple sets of transducers, wherein each set of transducers is coupled to a specific collar among multiple collars mounted on a pipe; and outputting multiple sets of ultrasonic waves based on the electrical energy transmitted from the at least one pulse receiver to the multiple sets of transducers, the multiple sets of ultrasonic waves traveling through the pipe in at least one direction.

[0020] Another aspect, which can be combined with any of the preceding aspects, includes: installing each of the plurality of collars at a unique location on the pipe.

[0021] Another aspect, which can be combined with any of the preceding aspects, includes: receiving feedback data via multiple sets of transducers, the feedback data including at least one ultrasonic waveform; and determining multiple locations on the pipeline, each including a specific material anomaly, based on at least one ultrasonic waveform.

[0022] Another aspect, which can be combined with any of the preceding aspects, includes: generating a model of a pipe, the model including multiple locations on the pipe, each including a specific material anomaly; performing continuous iterations of the following operations over a time period: operating at least one pulse receiver to transmit the generated electrical energy to multiple sets of transducers, thereby outputting multiple ultrasonic waves; receiving feedback data through the multiple sets of transducers, the feedback data including at least one ultrasonic waveform; and determining multiple locations on the pipe, each including a specific material anomaly, based on at least one ultrasonic waveform.

[0023] Another aspect that can be combined with any of the previous aspects includes: updating the pipeline model on each successive iteration.

[0024] In another aspect, which can be combined with any of the previous aspects, the model includes a machine learning model.

[0025] Another aspect, which can be combined with any of the preceding aspects, includes: selecting one or more characteristics of a plurality of ultrasonic waves based on at least one of the pipe material or pipe size, such that the plurality of ultrasonic waves travel through the pipe in at least one direction parallel to the flow direction of the fluid in the pipe.

[0026] In another aspect that can be combined with any of the preceding aspects, one or more characteristics include at least one of amplitude or frequency.

[0027] Another aspect, which can be combined with any of the preceding aspects, includes: mounting at least one collar around the outer periphery of the pipe; and connecting a plurality of transducers around the outer periphery to at least one collar at equal radial intervals.

[0028] In another aspect that can be combined with any of the preceding aspects, at least one direction parallel to the flow direction of the fluid in the pipe includes: a first direction parallel to the flow direction of the fluid in the pipe; and a second direction parallel to the flow direction of the fluid in the pipe and opposite to the first direction.

[0029] In another aspect that can be combined with any of the preceding aspects, material anomalies include corrosive materials in the pipeline.

[0030] In another aspect that can be combined with any of the preceding aspects, the fluid includes hydrocarbon fluids.

[0031] Details of one or more embodiments of the subject matter described in this disclosure are set forth in the accompanying drawings and the following description. Other features, aspects, and advantages of the subject matter will become apparent from the specification, the drawings, and the claims. Attached Figure Description

[0032] Figure 1 This is a schematic diagram of an example implementation of the pipeline monitoring system according to the present disclosure.

[0033] Figure 2A and Figure 2B This is a schematic diagram of an example implementation of the pipeline monitoring system according to the present disclosure.

[0034] Figure 3 This is a schematic diagram of a portion of a pipeline network in which guided ultrasonic waves are propagated to monitor corrosion, according to this disclosure.

[0035] Figure 4 This is a schematic diagram of a controller or control system for a pipeline monitoring system according to this disclosure. Detailed Implementation

[0036] This disclosure describes an example implementation of a pipeline monitoring system that can utilize guided wave ultrasonic testing to determine one or more material anomalies, such as corrosion, in a pipeline network (or pipeline). For example, guided wave ultrasonic testing can be performed repeatedly or periodically over time to monitor pipeline corrosion or other anomalies in real time, such as while the pipeline is transporting fluids (e.g., hydrocarbon fluids).

[0037] According to an example implementation, guided wave ultrasonic testing utilizes one or more collar-transducer assemblies installed at specific locations within a pipe to apply relatively low-frequency ultrasonic waves. The ultrasonic waves are able to penetrate and pass through the pipe's wall thickness and propagate a distance along the pipe's longitudinal axis based on wave intensity. When any surface / subsurface defects or metal loss are present in the pipe, the ultrasonic waves will be interfered with; these waves will be reflected in waveform form, which can be analyzed to detect such defects or other anomalies.

[0038] Implementations of pipeline monitoring systems may include multiple collar-transducer assemblies installed in or on pipelines (e.g., pipeline networks in hydrocarbon processing facilities) to initiate guided wave ultrasonic detection. The collar-transducer assemblies may be communicatively coupled to a pulse / receiver device that powers the transducers to generate acoustic waves passing through the pipeline. The pulse / receiver device may also collect or receive acoustic waveforms in response to the acoustic waves. The control system may analyze the characteristics of the acoustic waveforms to determine the characteristics of material anomalies in the pipeline, such as the size, type, and location of defects. The acoustic waveforms may also be analyzed to provide estimates of the rate of material (e.g., metal) loss over a specific time period, which can serve as a proactive measure for developing appropriate contingency plans to ensure pipeline continuity.

[0039] Embodiments of the pipeline monitoring system and method disclosed herein enable comprehensive, predictive, real-time corrosion mapping of pipelines and facilitate advanced corrosion correlation analysis of one or more pipeline characteristics using artificial intelligence and machine learning. In some aspects, the pipeline monitoring system can be used for metallic pipelines, where guided ultrasonic waves are selected or configured based on pipeline characteristics, such as material type (e.g., carbon steel, stainless steel, alloys of the metal or other metals) and pipeline geometry (e.g., outer diameter, inner diameter, cross-sectional shape, wall thickness, etc.). In some aspects, a coupling agent (in other words, a liquid layer on the outer surface of the pipeline used to form the ultrasonic transmission medium) is not required to facilitate ultrasonic transmission between the transducer and the pipeline material.

[0040] The implementation of pipeline monitoring systems offers significant improvements over traditional corrosion monitoring techniques, which typically involve manual testing of coupons inserted into the pipeline for corrosion detection. In fact, current corrosion monitoring methods, such as coupon testing and on-stream inspection (OSI), are performed manually and may pose safety risks. Furthermore, traditional techniques are retrospective, with data optimized on a monthly basis, unlike the predictive analytics provided by the embodiments of this disclosure (which will be described in more detail herein). Moreover, traditional techniques focus only on critical points identified by localized corrosion (usually by operators), thus providing limited coverage across the pipeline system. Therefore, such techniques are susceptible to human error due to improper handling during manual data collection at test locations or during coupon inspection in the laboratory.

[0041] Figure 1 This is a schematic diagram of an example embodiment of the pipeline monitoring system 100 according to the present disclosure. As shown, the system 100 can be installed on and used with a pipeline 102 that delivers fluid 106 through a conduit 104. In some aspects, the fluid 106 includes hydrocarbon fluids or hydrocarbon fluids (e.g., oil, natural gas, or multiphase hydrocarbon fluids).

[0042] As shown in the figure, collar 108 is mounted or disposed on pipe 102 (e.g., around the entire circumference of pipe 102). In an example embodiment, collar 108 may be a clamping ring made of metal or rubber (or other material), comprising a hinge located at one point along the ring and a locking mechanism located at another point along the ring, approximately 180 degrees from the hinge. Figure 2A As shown in more detail, the collar 108 includes a platform on which the transducer 110 is mounted and arranged in a balanced orientation around the conduit 102 (e.g., arranged at equal radial intervals around the circumference of the conduit 102).

[0043] like Figure 1 As shown, transducer 110 converts the electrical signal 116 generated by pulse / receiver device 114 into ultrasonic wave 112a, which flows or propagates in pipe 102 (e.g., Figure 2A and Figure 2B (Shown in more detail). In response, the acoustic waveform 112b returns from the conduit 102 to the transducer 110 (and is provided to the control system 122 via the pulse / receiver device 114, as will be described in more detail herein).

[0044] although Figure 1Only one collar 108 and transducer 110 (collectively referred to as collar-transducer assemblies) are shown, but more than one collar-transducer assembly may exist, and in some respects, multiple collar-transducer assemblies may be installed on the pipe 102. For example, within the pipe 102 (or pipe network), there may be multiple pipe branches conveying fluid 106. Therefore, collar-transducer assemblies may be installed at various locations on the pipe 102 to ensure that sound wave 112a (and reflected sound wave waveform 112b) propagates and reflects in all, most, or some parts of the pipe 102. In some respects, the distance between collar-transducer assemblies on the pipe 102 may be based at least in part on the intensity (amplitude) or frequency (or both) of sound wave 112a. In some respects, the distance between collar-transducer assemblies (where each assembly is installed at a unique location on the pipe 102) may be up to 50 meters. Where the collar-transducer assembly cannot be installed on pipe 102, manual on-site inspection techniques can be used (and these output data, together with the acoustic waveform 112b data, can be provided for analysis as described herein).

[0045] The pulse / receiver device 114 includes a power source or is electrically coupled to a power source (e.g., mains or off-grid power, such as a battery) to generate electrical energy 116 to supply to the transducer 110. The transducer 110 then uses the electrical energy 116 to generate sound waves 112a. In some aspects, the pulse / receiver device 114 is also operable to change the voltage and current intensity as needed, for example, to change the amplitude or frequency (or both) of the sound waves 112a.

[0046] Control system 122 (via wired or wireless signal 120) is communicatively coupled to pulse / receiver device 114 to control the operation of pulse / receiver device 114 and analyze acoustic waveform 112b to identify one or more material anomalies (corrosion, defects, or other anomalies) in pipe 102. Typically, control system 122 includes control unit 124 for bidirectional communication with pulse / receiver device 114 and data processing unit 126 (with one or more hardware processors) communicating with control unit 124 via electrical (or optical) signals 138. Data processing unit 126 also communicates with database 128 via electrical (or optical) signals 140. Database 128 may store data related to the control of pulse / receiver device 114, such as the amplitude and / or frequency of acoustic wave 112a, and protocols and timing patterns that allow pulse / receiver device 114 to generate electrical energy 116.

[0047] In this example, the control system 122 also includes an amplifier 130. In some aspects, the amplifier 130 can be operated to compensate for signal loss that occurs during long-distance transmission (e.g., signal loss at signal connection 120). Data attenuates during transmission, weakening signal strength. The power amplifier 130 can be used to amplify or enhance the weakened signal and restore its power level to ensure reliable and accurate data streamlining. In some aspects, the power amplifier 130 is used to receive electrical signals from the control unit 124 and amplify these electrical signals to a higher power level or amplitude for further transmission. The power amplifier 130 helps overcome signal loss and maintain signal quality throughout the transmission path.

[0048] As illustrated in this example, the control system 122 also includes advanced data processing capabilities, such as an advanced data processing unit 132, which includes an artificial intelligence (AI) module 134 and a machine learning (ML) module 136. The advanced data processing unit 132 communicates with the database 128 via an electrical signal (or optical signal) 142. Typically, the advanced data processing unit 132 utilizes the AI ​​module 134 and / or the ML module 136 to analyze and optimize predictive solutions based on data feedback from the system 100 (e.g., acoustic waveform 112b data and anomaly detection). Other data, such as online monitoring data of the pipeline 102, can also be provided to the advanced data processing unit 132. Using continuous or semi-continuous data, or online detection data (or both) provided by system 100, advanced processing unit 132 can provide output data for reliable service, including but not limited to: redefining equipment end-of-life calculations with more detailed and accurate anomaly (e.g., corrosion) output data; developing optimal contingency plans for events caused by corrosion or other anomalies; proposing more efficient operating modes with less corrosion impact; and providing predictive solutions that help reduce the risk of adverse future operation.

[0049] In an example aspect according to this disclosure, the pipeline monitoring system 100 may provide one, some, or all of the following features: guided wave ultrasonic detection and scanning coverage, transducer control and functionality, pipeline surface preparation, and network connectivity. One, some, or all of these features can help ensure the efficiency of the system 100, thereby providing accurate real-time analysis of potential material anomalies in the pipeline 102. For example, the scanning coverage of the acoustic wave 112a, specified by the distance the emitted signal / wave can travel longitudinally through the pipeline 102, is determined based on the capabilities of the pulse / receiver device 114. In some respects, this capability may vary depending on the model of the pulse / receiver device 114. The transducer functionality can be maintained through regular calibration sessions and periodic preventative maintenance procedures. Surface preparation involves the cleanliness and contamination-free nature of the outer surface of the pipeline 102. Finally, network connectivity ensures streamlined data transmission between the pulse / receiver device 114 and the control system 122. Any potential network disconnection could affect the real-time data optimization of the control system 122, and consequently its determination of material anomalies in the pipeline 102.

[0050] Figure 2A and Figure 2B This is a schematic diagram of an example embodiment of the pipeline monitoring system 100 according to the present disclosure. Figure 2A Another view showing at least a portion of the pipeline monitoring system 100 includes a collar 108 and a transducer 110 mounted on the collar 108 (the collar 108 is further circumferentially mounted around the pipeline 102). As shown in the figure, sound waves 112a are capable of bidirectional propagation parallel to the longitudinal axis 152 of the pipeline 102 (in other words, parallel to the flow direction of the fluid 106). Figure 2B A cross-section taken from pipe 102 is shown, illustrating the acoustic wave 112a generated by transducer 110. (See diagram.) Figure 2B As shown, since the transducers 110 are arranged radially spaced around the pipe 102, multiple sound waves 112a propagate through the pipe 102, with each group of sound waves 112a radially spaced around the pipe 102. As shown in the figure, the radial spacing 150 can separate radially adjacent sound waves 112a. In some respects, the radial spacing 150 between each pair of radially adjacent sound waves 112a is equal or approximately equal (difference of a few degrees).

[0051] Figure 3 This is a schematic diagram of a portion of a pipeline network in which guided ultrasonic waves are propagated to monitor corrosion, according to this disclosure. As shown in the figure, a portion of a pipeline monitoring system 100 in operation is illustrated. Here, a collar 108 and a transducer 110 (collectively referred to as the collar-transducer assembly) are mounted at specific locations on the pipeline 102. An acoustic waveform 112b is schematically shown (reflected back to the collar-transducer assembly).

[0052] As schematically illustrated here, the acoustic waveform 112b may include amplitude variations that indicate one or more material anomalies in the pipe 102. For example, certain amplitude variations in the acoustic waveform 112b indicate anomalies in the form of welds between pipe segments in the pipe 102. While such "defects" may be harmless, other amplitude variations in the acoustic waveform 112b may indicate anomalies in the form of corrosion propagation, as shown in the figure. Furthermore, certain amplitude variations in the acoustic waveform 112b indicate anomalies in the form of thinning of the pipe wall of the pipe 102 due to corrosion (located inside or outside the pipe 102).

[0053] refer to Figure 1 , Figure 2A , Figure 2B as well as Figure 3 Example operation of the pipeline monitoring system 100 can be implemented as follows. In some aspects, certain steps of the operation can be implemented by the control system 122 (e.g., by software instructions stored in the database 128 and executed by the data processing unit 126 to control the control system 122 or other components of the system 100 itself).

[0054] In some respects, system 100 can be installed on pipe 102 and calibrated before it is run in real time to determine one or more material anomalies. For example, one, some, or more collar-transducer assemblies can be installed at unique locations on pipe 102 (e.g., the clamping ring portion of collar 108 is installed onto pipe 102). At least one pulse / receiver device 114 (together with transducer 110) can be calibrated to confirm functionality. Calibration can be performed on specific or separate pipe sections (e.g., sections separate from pipe 102) with man-made anomalies (e.g., defects), and these components are considered calibrated once the man-made anomaly is detected.

[0055] In some cases, the collar-transducer assembly can be installed on a relatively clean section of pipe 102 free of surface defects. The pulse / receiver device 114 is controlled by the control system 122 via signal connection 120. Before operation, the operator can input information into the control system 122, such as the material and geometry of pipe 102 (or, if different, information on multiple sections of pipe 102). The operator can then initiate operation of system 100 via control system 122.

[0056] During real-time operation, the collar-transducer assembly is powered by pulse / receiver device 114 (or multiple pulse / receiver devices 114) to generate sound wave 112a. The generation of sound wave 112a can occur periodically over specific time periods, or even continuously during the operation of the conduit 102 conveying fluid 106. In some respects, control system 122 controls the pulse / receiver device 114 to generate sound waves 112a of different frequencies or amplitudes (or both).

[0057] The reflected acoustic waveform 112b is caused by the generated acoustic wave 112a. This type of reflected waveform 112b can be reflected onto one or more collar-transducer assemblies on the pipe 102 and transmitted to the control system 122. The control system 122 analyzes the reflected waveform 112b (e.g., its amplitude, frequency, or both) to determine the location of one or more material anomalies in the pipe 102.

[0058] In some respects, the control system 122 (e.g., via the advanced data processing unit 132) can create a model (e.g., a machine learning model) of the pipe 102 with determined locations of material anomalies. This model can be updated over time as more acoustic waves 112a are iteratively generated (and acquired) (and thus more acoustic waveforms 112b are obtained). Therefore, the model of the pipe 102 is capable of providing a predictive solution for determining the location of material anomalies such as corrosion or other defects, as well as potential future defects or anomalies.

[0059] Figure 4 This is a schematic diagram of an example controller 400 (or control system) for a pipeline monitoring system. For example, controller 400 can be used for the aforementioned operations, such as as part of control system 122. For example, controller 400 can be communicatively coupled to, or as part of, a pipeline monitoring system as described herein.

[0060] The controller 400 is intended to include various forms of digital computers, such as printed circuit boards (PCBs), processors, digital circuit systems, or additionally, components of a vehicle. Furthermore, the system may include portable storage media, such as Universal Serial Bus (USB) flash drives. For example, a USB flash drive can store an operating system and other applications. The USB flash drive may include input / output components, such as a USB connector or a wireless transmitter that can be plugged into a USB port of another computing device.

[0061] Controller 400 includes processor 410, memory 420, storage device 430, and input / output device 440. Each of components 410, 420, 430, and 440 is interconnected using system bus 450. Processor 410 is capable of processing instructions for execution within controller 400. The processor can be designed using any of a variety of architectures. For example, processor 410 can be a CISC (Complex Instruction Set Computer) processor, a RISC (Reduced Instruction Set Computer) processor, or a MISC (Minimum Instruction Set Computer) processor.

[0062] In one embodiment, processor 410 is a single-threaded processor. In another embodiment, processor 410 is a multi-threaded processor. Processor 410 is capable of processing instructions stored in memory 420 or storage device 430 to display graphical information for a user interface on input / output device 440.

[0063] Memory 420 stores information within controller 400. In one embodiment, memory 420 is a computer-readable medium. In one embodiment, memory 420 is a volatile memory cell. In another embodiment, memory 420 is a non-volatile memory cell.

[0064] Storage device 430 provides mass storage for controller 400. In one embodiment, storage device 430 is a computer-readable medium. In various other embodiments, storage device 430 may be a floppy disk device, hard disk device, optical disk device, magnetic tape device, flash memory, solid-state device (SSD), or a combination thereof.

[0065] Input / output device 440 provides input / output operations for controller 400. In one embodiment, input / output device 440 includes a keyboard and / or a pointing device. In another embodiment, input / output device 440 includes a display unit for displaying a graphical user interface.

[0066] The described features can be implemented in digital electronic circuit systems or in computer hardware, firmware, software, or a combination thereof. The apparatus can be implemented as a computer program product tangibly embodied in an information carrier (e.g., in a machine-readable storage device) for execution by a programmable processor; and the method steps can be executed by a programmable processor executing a program of instructions to perform the functions of the described embodiments by manipulating input data and generating output. The described features can advantageously be implemented in one or more computer programs that can be executed on a programmable system including at least one programmable processor coupled to receive and send data and instructions from a data storage system, at least one input device, and at least one output device. A computer program is a set of instructions that can be used directly or indirectly in a computer to perform a particular activity or produce a particular result. A computer program can be written in any form of programming language, including compiled or interpreted languages, and can be deployed in any form, including as a standalone program or as a module, component, subroutine, or other unit suitable for use in a computing environment.

[0067] Suitable processors for executing instructions include, for example, general-purpose and special-purpose microprocessors, and a single processor or one or more processors in any type of computer. Typically, the processor receives instructions and data from read-only memory or random access memory, or both. Essential components of a computer are the processor for executing instructions and one or more memories for storing instructions and data. Typically, a computer will also include one or more mass storage devices for storing data files, or be operatively coupled to and in communication with one or more mass storage devices for storing data files; such devices include: disks, such as internal hard disks and removable disks; magneto-optical disks; and optical disks. Storage devices suitable for tangibly representing computer program instructions and data include all forms of non-volatile memory, including: for example, semiconductor memory devices, such as EPROM, EEPROM, solid-state drives (SSDs), and flash memory devices; disks, such as internal hard disks and removable disks; magneto-optical disks; and CD-ROMs and DVD-ROMs. The processor and memory can be supplemented by or incorporated into an ASIC (Application-Specific Integrated Circuit).

[0068] To provide user interaction, these features can be implemented on a computer with a display device for showing information to the user (such as a CRT (cathode ray tube), LCD (liquid crystal display), or LED (light-emitting diode) monitor) and a keyboard and pointing device (such as a mouse or trackball) through which the user can provide input to the computer. Furthermore, such activities can be implemented via a touchscreen flat panel display and other appropriate mechanisms.

[0069] These features can be implemented in a control system that includes back-end components (such as data servers), middleware components (such as application servers or internet servers), front-end components (such as client computers with graphical user interfaces or internet browsers), or any combination thereof. The system's components can be connected via any form or medium of digital data communication, such as a communication network. Examples of communication networks include local area networks (“LANs”), wide area networks (“WANs”), peer-to-peer networks (with ad-hoc or static members), grid computing infrastructure, and the Internet.

[0070] While this specification contains numerous details of specific embodiments, these should not be construed as limiting the scope of any invention or potentially claimed matter, but rather as descriptions of features specific to particular embodiments of a particular invention. Certain features described herein, even in the context of separate embodiments, may also be implemented in combination in a single embodiment. Conversely, various features described in the context of a single embodiment may also be implemented individually or in any suitable sub-combination in multiple embodiments. Furthermore, although features may have been previously described as functioning in certain combinations and even initially claimed in this way, in some cases, one or more features from a claimed combination may be removed from the combination, and the claimed combination may involve sub-combinations or variations of sub-combinations.

[0071] Similarly, although the operations are depicted in a specific order in the accompanying drawings, this should not be construed as requiring such operations to be performed in the specific order shown or in an ordered sequence, or requiring the execution of all shown operations to achieve the desired result. In some cases, multitasking and parallel processing may be advantageous. Furthermore, the separation of the various system components in the previously described embodiments should not be construed as requiring such separation in all embodiments, but rather as meaning that the described program components and systems can generally be integrated together in a single software product or packaged into multiple software products.

[0072] Various embodiments have been described. However, it will be understood that various modifications can be made without departing from the spirit and scope of this disclosure. For example, the example operations, methods, or processes described herein may include more or fewer steps than those described. Furthermore, the steps in such example operations, methods, or processes may be performed in a different order than that described or shown in the accompanying drawings. Therefore, other embodiments are within the scope of the appended claims.

Claims

1. A pipeline monitoring system, comprising: At least one collar is configured to be installed on a conduit for conveying fluid; Multiple transducers are coupled to the at least one collar and configured to output multiple ultrasonic waves that travel through the pipe in at least one direction parallel to the flow direction of the fluid in the pipe. At least one pulse receiver is electrically coupled to the plurality of transducers and configured to generate electrical energy from a power source; as well as The control system, communicatively coupled to the pulse receiver, is configured to perform operations including: Operate the at least one pulse receiver to transmit the generated electrical energy to the plurality of transducers, thereby outputting the plurality of ultrasonic waves; Feedback data is received through the plurality of transducers, and the feedback data includes at least one ultrasonic waveform. as well as Based on the at least one ultrasonic waveform, the location of the material anomaly on the pipe is determined.

2. The pipeline monitoring system according to claim 1, wherein: The at least one collar includes a plurality of collars, each collar being configured to be installed on the pipe at a unique location on the pipe, and The plurality of transducers includes multiple sets of transducers, each set of transducers being coupled to one of the plurality of collars.

3. The pipeline monitoring system of claim 2, wherein, Each unique location of the pipeline is 50 meters away from its adjacent unique location.

4. The pipeline monitoring system according to claim 2, wherein, The operation includes: Operate the at least one pulse receiver to transmit the generated electrical energy to the plurality of transducers, thereby outputting the plurality of ultrasonic waves; Feedback data is received through the multiple sets of transducers, the feedback data including at least one ultrasonic waveform; and Based on the at least one ultrasonic waveform, multiple locations on the pipe, each containing a specific material anomaly, are determined.

5. The pipeline monitoring system according to claim 4, wherein, The operation includes: Generate a model of the pipeline, the model including the plurality of locations on the pipeline, each including the specific material anomaly; A series of iterations performing the following operations within a given time period: Operate the at least one pulse receiver to transmit the generated electrical energy to the plurality of transducers, thereby outputting the plurality of ultrasonic waves; Feedback data is received through the multiple sets of transducers, the feedback data including at least one ultrasonic waveform; and Based on the at least one ultrasonic waveform, determine the plurality of locations on the pipe, each including the specific material anomaly; and The model of the pipeline is updated in each successive iteration.

6. The pipeline monitoring system according to claim 5, wherein, The model includes a machine learning model.

7. The pipeline monitoring system according to claim 1, wherein, One or more characteristics of the plurality of ultrasonic waves are selected based on at least one of the pipe material or pipe size, such that the plurality of ultrasonic waves travel through the pipe in at least one direction parallel to the flow direction of the fluid in the pipe.

8. The pipeline monitoring system according to claim 7, wherein, The one or more characteristics include at least one of amplitude or frequency.

9. The pipeline monitoring system according to claim 1, wherein, The at least one collar is configured to be mounted around the outer periphery of the pipe, and the plurality of transducers are coupled to the at least one collar around the outer periphery at equally spaced radial intervals.

10. The pipeline monitoring system according to claim 1, wherein, The at least one direction parallel to the flow direction of the fluid in the pipe includes: A first direction parallel to the flow direction of the fluid in the pipe; and A second direction that is parallel to the flow direction of the fluid in the pipe and opposite to the first direction.

11. The pipeline monitoring system according to claim 1, wherein, The material anomaly includes corrosive materials in the pipeline.

12. The pipeline monitoring system according to claim 1, wherein, The fluid includes hydrocarbon fluids.

13. A method for monitoring pipeline materials, comprising: Operate at least one pulse receiver to transfer electrical energy from a power source to a plurality of transducers, the plurality of transducers being coupled to at least one collar mounted on a pipe for conveying fluid; Based on the electrical energy transmitted from the at least one pulse receiver to the plurality of transducers, a plurality of ultrasonic waves are output, the plurality of ultrasonic waves traveling through the pipe in at least one direction parallel to the flow direction of the fluid in the pipe; Feedback data is received through the plurality of transducers, the feedback data including at least one ultrasonic waveform; and Based on the at least one ultrasonic waveform, the location of the material anomaly on the pipe is determined.

14. The method of claim 13, comprising: Operate the at least one pulse receiver to transmit electrical energy from the power source to multiple sets of transducers, each set of transducers being coupled to a specific collar among multiple collars mounted on the pipe; as well as Based on the electrical energy transmitted from the at least one pulse receiver to the plurality of transducers, a plurality of ultrasonic waves are output, which travel through the pipe in at least one direction.

15. The method of claim 14, comprising: Each of the plurality of collars is installed on the pipe at a unique location on the pipe.

16. The method of claim 14, comprising: Feedback data is received through the multiple sets of transducers, and the feedback data includes at least one ultrasonic waveform. as well as Based on the at least one ultrasonic waveform, multiple locations on the pipe, each containing a specific material anomaly, are determined.

17. The method of claim 16, comprising: Generate a model of the pipeline, the model including the plurality of locations on the pipeline, each including the specific material anomaly; A series of iterations performing the following operations within a given time period: Operate the at least one pulse receiver to transmit the generated electrical energy to the plurality of transducers, thereby outputting the plurality of ultrasonic waves; Feedback data is received through the multiple sets of transducers, and the feedback data includes at least one ultrasonic waveform. as well as Based on the at least one ultrasonic waveform, determine the plurality of locations on the pipe, each including the specific material anomaly; and The model of the pipeline is updated in each successive iteration.

18. The method according to claim 17, wherein, The model includes a machine learning model.

19. The method of claim 13, comprising: One or more characteristics of the plurality of ultrasonic waves are selected based on at least one of the pipe material or pipe size, such that the plurality of ultrasonic waves travel through the pipe in at least one direction parallel to the flow direction of the fluid in the pipe.

20. The method according to claim 19, wherein, The one or more characteristics include at least one of amplitude or frequency.

21. The method of claim 13, comprising: Install the at least one collar around the outer periphery of the pipe; as well as The plurality of transducers are connected to the at least one collar at equal radial intervals around the outer periphery.

22. The method according to claim 13, wherein, The at least one direction parallel to the flow direction of the fluid in the pipe includes: A first direction parallel to the flow direction of the fluid in the pipe; and A second direction that is parallel to the flow direction of the fluid in the pipe and opposite to the first direction.

23. The method according to claim 13, wherein, The material anomaly includes corrosive materials in the pipeline.

24. The method according to claim 13, wherein, The fluid includes hydrocarbon fluids.

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