Claims:We Claim:
1. A method for detecting sediment deposits (206) in a pipeline (205), the method comprising:
generating, by a wave generating module (204), acoustic waves in the pipeline (205);
receiving, by a signal analyzer (201), a plurality of wave signals reflected from the pipeline (205) through each of a plurality of sensors (203a-203l), wherein, the plurality of sensors (203a-203l) are positioned at pre-determined locations along a circumference of the pipeline (205) and communicatively coupled to the signal analyzer (201);
determining, by a processing unit (207), damping rate corresponding to the pre-determined locations of each of the plurality of sensors (203a-203l) based on the plurality of wave signals received from each of the plurality of sensors (203a-203l), wherein, the damping rate corresponding to the pre-determined locations of each of the plurality of sensors (203a-203l) is indicative of the sediment deposit (206) in the pipeline (205).

2. The method as claimed in claim 1 comprising determining concentration of the sediment deposits (206) based on the damping rate corresponding to the pre-determined locations plurality of sensors (203a-203l).

3. The method as claimed in claim 1, wherein the wave generating module (204) is a steel ball hammer configured to generate vibrations in the pipeline (205).

4. The method as claimed in claim 1, wherein each of the plurality of sensors (203a-203l) are spaced equidistantly along the circumference of the pipeline (205).

5. The method as claimed in claim 1, wherein the plurality of sensors (203a-203l) are acoustic sensors.

6. The method as claimed in claim 5, wherein the acoustic sensors is at least one of a piezoelectric sensor.

7. The method as claimed in claim 1 comprises generating, by the processing unit (207), an attenuation curve corresponding to the predetermined locations of each of the plurality of sensors (203a-203l) based on the plurality of wave signals received from each of the plurality of sensors (203a-203l).

8. The method as claimed in claim 1, wherein the plurality of wave signals is analyzed by the signal analyzer (201) with the processing unit (207).

9. The method as claimed in claim 7 comprises segregating, by the processing unit (207), the plurality of wave signals into a pre-determined number of time windows and generating the attenuation curve based on a root mean square value calculated for each of the pre-determined number of time windows.

10. The method as claimed in claims 1 and 7, wherein the damping rate corresponding to pre-determined locations of each of the plurality of sensors (203a-203l) is determined based on the corresponding attenuation curve.

11. The method as claimed in claim 1, wherein the processing unit (207) determines the damping rate by an exponential equation based on an amplitude coefficient and the root mean square value of each of the pre-determined number of time windows.

12. A system (200) for detecting sediment deposits (206) in a pipeline (205), the system (200) comprising:
a wave generating module (204) configured to generate acoustic waves in the pipeline (205); and
a signal analyzer (201) communicatively coupled to a plurality of sensors (203a-203l), wherein the signal analyzer (201) is configured to:
receive a plurality of wave signals reflected from the pipeline (205) through each of a plurality of sensors (203a-203l), wherein, the plurality of sensors (203a-203l) are positioned at pre-determined locations along a circumference of the pipeline (205) and signal analyzer (201) is communicatively coupled to the processing unit (207);
determine damping rate corresponding to the pre-determined locations of each of the plurality of sensors (203a-203l) based on the plurality of wave signals received from each of the plurality of sensors (203a-203l), wherein, the damping rate corresponding to the predetermined locations of each of the plurality of sensors (203a-203l) is indicative of the sediment deposit (206) in the pipeline (205).

13. The system (200) as claimed in claim 12, wherein the by the processing unit (207) generates an attenuation curve corresponding to the location of each of the plurality of sensors (203a-203l) based on the plurality of wave signals received from each of the plurality of sensors (203a-203l).

14. The system as claimed in claim 13 comprises a signal analyzer (201) associated with the processing unit (207), wherein the processing unit (207) is configured to generate the attenuation curve.

15. The system (200) as claimed in claim 12, wherein the wave generating module (204) is a steel ball hammer configured to generate vibrations in the pipeline (205).

16. The system (200) as claimed in claim 12, wherein the plurality of sensors (203a-203l) is an acoustic sensor.

17. The system (200) as claimed in claim 16, wherein the acoustic sensors is at least one of a piezoelectric sensor .

18. A coke-oven gas pipeline comprising the system (200) as claimed in claim 12 for determining sediment deposits (206) in the gas pipeline.
, Description:TECHNICAL FIELD:
The present disclosure relates to the field of metallurgy. Particularly, but not exclusively, the present disclosure relates to a system and method for detecting deposits in a pipeline. Further embodiments of the present disclosure disclose system and method for detecting the concentration of sediment deposits in the industrial pipeline such as pipeline used in steel plants.

BACKGROUND OF THE DISCLOSURE:

Generally, during carbonization of coking coal in a coke oven battery for the production of coke, around 25-30% of the coal charged is driven off as effluent gases rich in volatile matter and moisture. This gas is known as coke oven gas (CO gas). Coke oven gas (CO gas) is a byproduct gas produced during the production of metallurgical coke in a byproduct coke oven battery, where metallurgical coal is carbonized by heating it in absence of air. During carbonization, the volatile matter in the coal is vaporized and driven off. This volatile matter leaves the coke oven chambers as hot, raw coke oven gas. Coke-oven gas is a fuel gas having a medium calorific value that is produced during the manufacture of metallurgical coke by heating bituminous coal to temperatures of 900°C to 1000°C in a chamber from which air is excluded. The main constituents are, by volume, about 50% hydrogen, 30% methane and 3% higher hydrocarbons, 7% carbon monoxide, 3% carbon dioxide and 7% nitrogen. The gas has a heating value of about 20,000 kJ/m3.

Typically, coke-oven gas is obtained from a battery comprising number of narrow, vertical chambers, or ovens built of silica brick that are separated by heating ducts, such that heat is transmitted to the coal through both sides of the chamber walls. The ovens are slightly tapered so that one end is wider than the other to facilitate the horizontal discharge of the coke. Crushed coal is charged from overhead bunkers into the ovens, which are sealed at each end by refractory-lined sheet doors and heated. The hot coke is then discharged. About 12%, by weight, of the coal is converted into gas. The hot gases evolved from the coal pass through a gas space at the top of the oven and into a collecting main prior to quenching and treatment to remove dust, tar and oil, and gaseous impurities such as ammonia and hydrogen sulfide. Also, the coke-oven gas includes impurities such as naphthalene and tar.

After leaving the coke oven chambers, the raw coke oven gas may be directed into the coke-oven gas pipeline. As the pressure in the gas pipeline is significantly equal to the atmospheric pressure, impurities/sediments begin depositing in the pipeline. As a result, over a period of time the sediments completely get deposited in the pipeline which may result in several downsides in the production process. Also, due to the sediment deposits, the pipelines get blocked which is a substantially bigger problem in the steel industry. The sediment deposition hinders the flow of coke oven gas which affects the production process. Blockage of pipelines lead to a poor operating efficiency and increase the risk of potential accidents.

There are also known prior arts to determine deposition of sediments in the pipeline. For instance, the prior art US20050041775A1 discloses a method for high-speed radiographic inspection of a fluid vessel using a radiation source and a radiation detector. The source and detector move longitudinally (and circumferentially) with respect to vessel to map the image of deposit present inside the pipeline. The device of US20050041775A1 poses a serious radiation hazard; it can’t be used for pipeline at greater heights. Moreover, the method disclosed in US20050041775A1 will fail to map the bends. In another known prior art, WO2007008636A1 discloses a conventional method for determining deposition parameters within an industrial heating system using phased array probe. In the method disclosed in WO2007008636A1, sediment deposit must be intact with the surface of pipe so that reflected acoustic wave is received by phased array probe. In gas pipelines, sediment get deposited with time; they are porous in nature and hence acoustic wave will not be able to travel back to the probe.
The present disclosure is directed to overcome one or more limitations stated above or other such limitations associated with the conventional systems.

The information disclosed in this background of the disclosure section is only for enhancement of understanding of the general background of the invention and should not be taken as an acknowledgement or any form of suggestion that this information forms the prior art already known to a person skilled in the art.

SUMMARY OF THE DISCLOSURE

One or more shortcomings of the conventional method are overcome by process as claimed and additional advantages are provided through the provision of processes as claimed in the present disclosure.

Additional features and advantages are realized through the techniques of the present disclosure. Other embodiments and aspects of the disclosure are described in detail herein and are considered a part of the claimed disclosure.

In one non-limiting embodiment of the disclosure, a method for detecting sediment deposits in a pipeline is disclosed. The method includes firstly generating acoustic waves in the pipeline by a wave generating module. A plurality of wave signals reflected from the pipeline is received by a signal analyser, wherein the plurality of sensors is positioned at pre-determined locations along a circumference of the pipeline and communicatively coupled to the signal analyser. The processing unit determines the damping rate corresponding to the predetermined location of each of the plurality of sensors based on the plurality of wave signals received from each of the plurality of sensors. The damping rate corresponding to the predetermined location of each of the plurality of sensors is indicative of the sediment deposit in the pipeline.

In an embodiment of the disclosure, concentration of the sediment deposits is determined based on the damping rate corresponding to the pre-determined location the plurality of sensors.

In an embodiment of the disclosure, the wave generating module is a steel ball hammer configured to generate vibrations in the pipeline.

In an embodiment of the disclosure, each of the plurality of sensors are spaced equidistantly along the circumference of the pipeline.

In an embodiment of the disclosure, the plurality of sensors are acoustic sensors. The acoustic sensors is a piezoelectric sensor

In an embodiment of the disclosure, the method comprises generating by the processing unit an attenuation curve corresponding to the pre-determined location of the each of the plurality of sensors based on the plurality of wave signals received from each of the plurality of sensors.

In an embodiment of the disclosure, the method includes segregating by the processing unit, the plurality of wave signals into a pre-determined number of time sample windows and generating the attenuation curve based on a root mean square value calculated for each of the predetermined number of time windows.

In an embodiment of the disclosure, the damping rate corresponding to pre-determined location of each of the plurality of sensors is determined based on the corresponding attenuation curve. The processing unit determines the damping rate by an exponential equation based on an amplitude coefficient and the root mean square value of each of the pre-determined number of time windows.

In another embodiment of the disclosure, a system for detecting sediment deposits in a pipeline is disclosed. The system includes a wave generating module configured to generate acoustic waves in the pipeline. A signal analyser communicatively coupled to a plurality of sensors; the signal analyser is configured to receive a plurality of wave signals reflected from the pipeline through each of the plurality of sensors. The plurality of sensors is positioned at predetermined locations along a circumference of the pipeline and communicatively coupled to the signal analyser. The processing unit determines damping rate corresponding to the pre-determined location of each of the plurality of sensors based on the plurality of wave signals received from each of the plurality of sensors. The damping rate corresponding to predetermined location of each of the plurality of sensors is indicative of the sediment deposits in the pipeline.

In an embodiment of the disclosure, the processing unit generates an attenuation curve corresponding to the location of each of the plurality of sensors based on the plurality of wave signals received from each of the plurality of sensors. The processing unit is configured to generate the attenuation curve using root mean square analysis.

It is to be understood that the aspects and embodiments of the disclosure described above may be used in any combination with each other. Several of the aspects and embodiments may be combined to form a further embodiment of the disclosure.

The foregoing summary is illustrative only and is not intended to be in any way limiting. In addition to the illustrative aspects, embodiments, and features described above, further aspects, embodiments, and features will become apparent by reference to the drawings and the following detailed description.

BRIEF DESCRIPTION OF THE ACCOMPANYING FIGURES

The novel features and characteristic of the disclosure are set forth in the appended claims. The disclosure itself, however, as well as a preferred mode of use, further objectives and advantages thereof, will best be understood by reference to the following detailed description of an illustrative embodiment when read in conjunction with the accompanying figures. One or more embodiments are now described, by way of example only, with reference to the accompanying figures wherein like reference numerals represent like elements and in which:

FIG.1a and FIG.1b illustrates schematic views of a system used for detecting sediment deposits in a pipeline, in accordance with an embodiment of the present disclosure.

FIG.2 is a flowchart of a method for detecting sediment deposits in the pipeline, in accordance with an embodiment of the present disclosure.

FIG.3 illustrates an exemplary process of analyzing the plurality of wave signals and generating an attenuation curve, in accordance with an embodiment of the present disclosure.

FIG.4 illustrates graphical representation of an attenuation curve plotted by the system of FIG. 1 for plurality of wave signals corresponding to the plurality of sensors at pre-determined locations, in accordance with an embodiment of the present disclosure.

The figures depict embodiments of the disclosure for purposes of illustration only. One skilled in the art will readily recognize from the following description that alternative embodiments of the structures and methods illustrated herein may be employed without departing from the principles of the disclosure described herein.

DETAILED DESCRIPTION

The foregoing has broadly outlined the features and technical advantages of the present disclosure in order that the detailed description of the disclosure that follows may be better understood. Additional features and advantages of the disclosure will be described hereinafter which form the subject of the claims of the disclosure. It should be appreciated by those skilled in the art that the conception and specific embodiment disclosed may be readily utilized as a basis for modifying or designing other structures for carrying out the same purposes of the present disclosure. It should also be realized by those skilled in the art that such equivalent processes do not depart from the spirit and scope of the disclosure as set forth in the appended claims. The novel features which are believed to be characteristic of the disclosure, both as to its organization and method of operation, together with further objects and advantages will be better understood from the following description when considered in connection with the accompanying figures. It is to be expressly understood, however, that each of the figures is provided for the purpose of illustration and description only and is not intended as a definition of the limits of the present disclosure. It will be readily understood that the aspects of the present disclosure, as generally described herein, and illustrated in the figures, can be arranged, substituted, combined, and designed in a wide variety of different configurations, all of which are explicitly contemplated and make part of this disclosure.

Embodiments of the present disclosure discloses a system for detecting sediment deposits in a pipeline such pipeline employed in the steel industry. The system also detects the concentration of sediment deposits in the pipeline. With the system of the present disclosure sediment depositions can be detected with ease and the system also helps in timely detection of the sediment deposits, so that maintenance operations can be performed even before the pipeline fails due to sedimentation. The system when employed in the steel industry ensures that the flow of coke-oven gas in the pipeline is not hindered, and thus avoid downsides that may be caused in the pipeline that may affect production rates. Further, the system ensures that the operating efficiency of the coke-oven system is not hindered. Also, the potential damages that may be caused to a production plant or production system, may be eliminated by the system of the present disclosure.

According to various embodiments of the present disclosure, the system of includes a wave generating module. The wave generating module may be a steel ball hammer. The wave generating module may be configured to generate acoustic waves in the pipeline. In an embodiment, the wave generating module may be configured to generate vibrations in the pipeline. The wave generating module strike an outer surface of the pipeline to generate the acoustic waves. The acoustic waves may be sound waves. The system further includes a plurality of sensors that may be positioned over the surface of the pipeline. In an embodiment, the plurality of sensors may be positioned on an entire circumference of the pipeline. Each of the plurality of sensors may be equidistantly positioned from one another on the circumference of the pipeline.

Each of the plurality of sensors may further be coupled to a signal analyzer. In an embodiment, each of the plurality of sensors may be communicatively coupled to the signal analyzer. Each of the plurality of sensors may be configured to sense a plurality of wave signals reflected from the pipeline. The plurality of sensors that may receive the plurality of wave signals further transmit the plurality of wave signals to the signal analyzer. The signal analyzer receives each of the plurality of wave signals corresponding to pre-determined location of each of the plurality of sensors.

In an embodiment, a processing unit may be configured to analyze the plurality of wave signals and generates an attenuation curve. Based on the attenuation curve, the processing unit may determine damping rates corresponding to predetermined location of each of the plurality of sensors. In an embodiment, the damping rate may be indicative of the sediment deposits in the pipeline. In some embodiments, the sediment deposits may be analyzed based on the damping rates by the processing unit or by an operator.

The terms “comprises”, “comprising”, or any other variations thereof used in the specification, are intended to cover a non-exclusive inclusion, such that system that comprises a list of components or steps does not include only those components or steps but may include other components or steps not expressly listed or inherent to such setup or method. In other words, one or more elements in an assembly proceeded by “comprises… a” does not, without more constraints, preclude the existence of other elements or additional elements in the assembly.

Henceforth, the present disclosure is explained with the help of one or more figures of exemplary embodiments. However, such exemplary embodiments should not be construed as limitation of the present disclosure.

The following paragraphs describe the present disclosure with reference to FIGS.1 to 4. In the figures, the same element or elements which have similar functions are indicated by the same reference signs.

FIG.1a is an exemplary embodiment of the present disclosure, which shows a schematic view of a system (200) used for detecting sediment deposits (206) in a pipeline (205). The sediments may be deposited in any portion of the pipeline (205). In some embodiments, the cross-section of the pipeline (205) may be at least one of but not limiting it to a circular, an oval or a square cross section. In an embodiment, the pipeline (205) may be a coke-oven gas pipeline. Generally, the coke-oven gas includes effluents such as but not limiting to Benzene (C6H6), Ammonia (NH3), Hydrogen sulphide (H2S) and other unwanted impurities like tar and naphthalene. The said effluents over a period of time may get deposited as sediments on the inner surface of the pipeline (205) as the pressure within the pipeline (205) is significantly close to atmospheric pressure. The sediment deposits (206) may hinder the flow of coke-oven gas, thereby affecting the production. Also, the sediment deposits (206) may cause blockages in the pipeline (205) which may lead to poor operating efficiency and may also increase the risk of a potential accident. The system (200) of the present disclosure ensures that the sediment deposition (206) may be detected on a real-time basis and eliminated, thereby avoiding potential losses that may be caused over period of time. In an embodiment, the system (200) includes a wave generating module (204). The wave generating module (204) may be configured to generate acoustic waves in the pipeline (205). The wave generating module (204) may be struck over the pipeline (205) to generate the acoustic waves. In an embodiment, the wave generating module (204) may be automated using a plurality of actuators which may aid in operating the wave generating module (204). In some embodiments, the wave generating module (204) may be operated by an operator. The wave generating module (204) may be struck on the pipeline (205) at a location desired to be tested by the operator. In another embodiment, the wave generating module (204) may be configured to generate sound waves in the pipeline (205). In an embodiment, the wave generating module (205) may be such as but not limiting to a ball hammer made of steel or other such materials suitable for the purpose.

Further, the system (200) includes a plurality of sensors (203a-203l) [best shown in FIG.1B]. In an embodiment, each of the plurality of sensors (203a-203l) may be positioned or communicatively connected to the pipeline (205). Each of the plurality of sensors (203a-203l) may be positioned over the circumference of the pipeline (205). In some embodiments, the plurality of sensors (203a-203l) may be positioned equidistantly from each other on the circumference of the pipeline (205). Each of the plurality of sensors (203a-203l) may be configured to convert the reflected acoustic waves from the pipeline to a plurality of wave signals. In an embodiment, the plurality of sensors (203a-203l) such as but not limiting an acoustic wave sensor. In another embodiment, the acoustic wave sensors may be at least one of but not limiting to a piezoelectric sensor. In some embodiments, the plurality of sensors (203a-203l) may be connectable at desired locations on the pipeline (205) by the operator.

A signal analyzer (201) may be communicatively coupled to each of the plurality of sensors (203a-203l) [as shown in FIG.1A]. The signal analyzer (201) may be configured to receive the plurality of wave signals from each of the plurality of sensors (203a-203l) corresponding to predetermined location of each of the plurality of sensors (203a-203l). In an embodiment, the signal analyzer (201) may include at least one of signal analyzer or an oscilloscope [not shown]. A processing unit (207) associated with the signal analyzer (201) may be configured to analyze each of the plurality of wave signals corresponding to each of the plurality of sensors (203a-203l) at the predetermined locations. In an embodiment, the signal analyzer (201) associated with the processing unit (207) may be configured to analyze each of the plurality of wave signals corresponding to the pre-determined locations of each of the plurality of sensors (203a-203l). Once the plurality of wave signals is analyzed by the signal analyzer (201), the processing unit (207) may generate an attenuation curve based on the plurality of wave signals corresponding to the pre-determined location of each of the plurality of sensors (203a-203l). In an embodiment, the processing unit (207) may segregate the plurality of wave signals into a pre-determined number of time windows. Further, a root mean square (RMS) value for each of the pre-determined time windows may be calculated and based on the number of the time windows and the RMS value, the attenuation curve may be plotted. In an embodiment, the signal analyzer (201) associated with the processing unit (207) may be configured to generate the attenuation curve for the plurality of wave signals.

In an exemplary embodiment, the processing unit considers two thousand-time samples of the plurality of wave signals, the attenuation curve may be plotted by calculating root mean square of the plurality of wave signals. In an embodiment, the attenuation curve analysis of the plurality of wave signals may be calculated by selecting a window of four hundred samples [as shown in FIG.3 and depicted by A] from the plurality of acoustic signals, then the time window may be moved by one sample. In the said case a second time window may be formed by excluding a first element of the first-time window [as shown in FIG.3 and depicted by B]. An exemplary attenuation curve may be plotted as depicted in the exemplary FIG.3. Further, FIG.4 indicates the attenuation curve plotted or generated for plurality of wave signals corresponding to the plurality of sensors (203a-203l) at the pre-determined locations. The processing unit (207) may be configured to determine damping rates corresponding to pre-determined location of each of the plurality of sensors (203a-203l). In another embodiment, the processing unit (207) may determine the damping rates based on the plurality of wave signals received from the plurality of sensors (203a-203l). In some embodiments, the processing unit (207) may determine the damping rate by an exponential equation y=A.e^((-x)/a). In some embodiments, the processing unit (207) may determine the damping rate by the exponential equation based on an amplitude coefficient and the root mean square value of each of the pre-determined number of time windows. In an embodiment, the damping rates may be indicative of the sediment deposits (206) in the pipeline. Exemplary values (Table—1) indicating the damping rates determined based on the attenuation curve corresponding to the pre-determined locations of the plurality of sensors (203a-203l) is provided below. However, such values should not be construed as a limitation to the present disclosure as the damping rates may vary based on the sediment deposits (206) in the pipeline (205).

Measurement Point a Damping Rate (1/a)
203a 141.67 0.0071
203b 94.02 0.0106
203c 75.79 0.0131
203d 49.54 0.0201
203e 56.90 0.0175
203f 28.51 0.0350
203g 48.73 0.0205
203h 29.61 0.0337
203i 47.10 0.0212
203j 80.02 0.0124
203k 93.09 0.0107
203l 172.42 0.0058

Table-1: Exemplary values of the damping rates corresponding to the attenuation curve.

As shown in the Table-1, the damping rate values may vary based on the plurality of wave signals measured at the pre-determined locations by the plurality of sensors (203a-203l). In an embodiment, if the damping rate of the plurality of wave signals (i.e. acoustic waves) is more, it is indicative that the sediment may be deposited in that location of the pipeline.

Referring now to FIG.2, it is an exemplary embodiment of the present disclosure, illustrating a flowchart of a method for detecting sediment deposits in a pipeline (205).).

As illustrated in FIG.2, the method comprises one or more blocks illustrating a method for detecting the sediment deposits (206) in the pipeline (205). The method may be described in the general context of computer-executable instructions. Generally, computer-executable instructions can include routines, programs, objects, components, data structures, procedures, modules, and functions, which perform functions or implement abstract data types.

The order in which the method is described is not intended to be construed as a limitation, and any number of the described method blocks can be combined in any order to implement the method. Additionally, individual blocks may be deleted from the methods without departing from the spirit and scope of the subject matter described herein. Furthermore, the method can be implemented in any suitable hardware, software, firmware, or combination thereof.

As shown at block 101, the wave generating module (204) may be configured to generate the acoustic waves in the pipeline (205). In an embodiment, the wave generating module (204) may be struck upon the pipeline (205) to generate the acoustic waves in the pipeline (205). The acoustic waves maybe reflected by the pipeline (205) and may be received by the plurality of sensors (203a-203l) positioned at pre-determined locations on the pipeline (205). In an embodiment, the plurality of sensors (203a-203l) may be configured to convert the reflected acoustic waves (mechanical wave) to the plurality of wave signals (electrical pulse). In some embodiments, the plurality of sensors (203a-203l) may be configured to transmit the plurality of wave signals to the signal analyzer (201).

As shown at block 102, the signal analyzer (201) may receive the plurality of wave signals from the plurality of sensors (203a-203l) positioned at the predetermined locations along the circumference of the pipeline (205). Further, as depicted in block 103, upon receiving the plurality of wave signals, the processing unit (207) may analyze the plurality of wave signals corresponding to each of the plurality of sensors (203a-203l). In an embodiment, the analyzer associated with the processing unit (207) may aid in analysis of the plurality of wave signals. Once the plurality of wave signals is analyzed, the processing unit (207) may be configured to generate the attenuation curve corresponding to the pre-determined locations of the plurality of sensors (203a-203l). As described earlier in the present disclosure, the processing unit (207) may segregate the plurality of wave signals into the pre-determined number of time windows and the RMS value for each of the pre-determined time window may be calculated. Based on the number of time window and the RMS value the attenuation curve may be plotted or generated by the processing unit (207).

As shown at block 104, based on the attenuation curve generated, the processing unit (207) may be configured to determine the damping rate of the plurality of wave signals. The processing unit (207) may determine the damping rate of the plurality of wave signals corresponding to the plurality of sensors (203a-203l) positioned at pre-determine locations. The damping rates (as shown in table 1) may be tabulated in but not limiting to a display device. In an embodiment, based on the damping rate of the plurality of wave signals, an operator may detect the sediment deposits in the pipeline (205). In some embodiments, the system (200) may be configured to indicate the sediment deposits in the pipeline (205) based on the damping rates of the plurality of wave signals corresponding to the pre-determined location. In an embodiment, the damping rates corresponding to the plurality of wave signals may be indicative of the concentration of the sediment deposits (206) in the pipeline (205). In some embodiment, plurality of trials may be performed to detect the sediment deposits (206) in the pipeline (205).

In an embodiment, the system (200) may be configured to detect the concentration of sediment deposits (206) in the pipeline (205). The system (200) of the present disclosure ensures timely detection and thus enable timely elimination of the sediment deposits (206). Also, the system (200) ensures that the flow of gas is not hindered, thereby eliminating any such downsides that may be caused in the pipeline (205) that may affect production rates. Further, the system (200) ensures the operating efficiency of the system (200) is not hindered. Also, the potential damages that may be caused to production plant or production system may be eliminated by the system (200) of the present disclosure.

In an embodiment of the disclosure, the processing unit (207) may be a centralized control unit, or a dedicated control unit associated with the system (200). The control unit may be implemented by any computing systems that is utilized to implement the features of the present disclosure. The control unit may be comprised of a processing unit. The processing unit may comprise at least one data processor for executing program components for executing user- or system-generated requests. The processing unit may be a specialized processing unit such as integrated system (bus) controllers, memory management control units, floating point units, graphics processing units, digital signal processing units, etc. The processing unit may be a hardware unit which include a microprocessor, such as AMD Athlon, Duron or Opteron, ARM’s application, embedded or secure processors, IBM PowerPC, Intel’s Core, Itanium, Xeon, Celeron or other line of processors, etc. The processing unit may be implemented using a mainframe, distributed processor, multi-core, parallel, grid, or other architectures. Some embodiments may utilize embedded technologies like application-specific integrated circuits (ASICs), digital signal processors (DSPs), Field Programmable Gate Arrays (FPGAs), etc.

In some embodiments, the processing unit may be disposed in communication with one or more memory devices (e.g., RAM, ROM etc.) via a storage interface. The storage interface may connect to memory devices including, without limitation, memory drives, removable disc drives, etc., employing connection protocols such as serial advanced technology attachment (SATA), integrated drive electronics (IDE), IEEE-1394, universal serial bus (USB), fiber channel, small computing system interface (SCSI), etc. The memory drives may further include a drum, magnetic disc drive, magneto-optical drive, optical drive, redundant array of independent discs (RAID), solid-state memory devices, solid-state drives, etc.

It is to be understood that a person of ordinary skill in the art may develop a system of similar configuration without deviating from the scope of the present disclosure. Such modifications and variations may be made without departing from the scope of the present invention. Therefore, it is intended that the present disclosure covers such modifications and variations provided they come within the ambit of the appended claims and their equivalents.

Equivalents

With respect to the use of substantially any plural and/or singular terms herein, those having skill in the art can translate from the plural to the singular and/or from the singular to the plural as is appropriate to the context and/or application. The various singular/plural permutations may be expressly set forth herein for sake of clarity.

It will be understood by those within the art that, in general, terms used herein, are generally intended as "open" terms (e.g., the term "including" should be interpreted as "including but not limited to," the term "having" should be interpreted as "having at least," the term "includes" should be interpreted as "includes but is not limited to," etc.). It will be further understood by those within the art that if a specific number of an introduced claim recitation is intended, such an intent will be explicitly recited in the claim, and in the absence of such recitation no such intent is present. For example, as an aid to understanding the description may contain usage of the introductory phrases "at least one" and "one or more" to introduce claim recitations. However, the use of such phrases should not be construed to imply that the introduction of a claim recitation by the indefinite articles "a" or "an" limits any particular claim containing such introduced claim recitation to inventions containing only one such recitation, even when the same claim includes the introductory phrases "one or more" or "at least one" and indefinite articles such as "a" or "an" (e.g., "a" and/or "an" should typically be interpreted to mean "at least one" or "one or more"); the same holds true for the use of definite articles used to introduce claim recitations. In addition, even if a specific number of an introduced claim recitation is explicitly recited, those skilled in the art will recognize that such recitation should typically be interpreted to mean at least the recited number (e.g., the bare recitation of "two recitations," without other modifiers, typically means at least two recitations, or two or more recitations). Furthermore, in those instances where a convention analogous to "at least one of A, B, and C, etc." is used, in general such a construction is intended in the sense one having skill in the art would understand the convention (e.g., "a system having at least one of A, B, and C" would include but not be limited to systems that have A alone, B alone, C alone, A and B together, A and C together, B and C together, and/or A, B, and C together, etc.). In those instances where a convention analogous to "at least one of A, B, or C, etc." is used, in general such a construction is intended in the sense one having skill in the art would understand the convention (e.g., "a system having at least one of A, B, or C" would include but not be limited to systems that have A alone, B alone, C alone, A and B together, A and C together, B and C together, and/or A, B, and C together, etc.). It will be further understood by those within the art that virtually any disjunctive word and/or phrase presenting two or more alternative terms, whether in the description, or drawings, should be understood to contemplate the possibilities of including one of the terms, either of the terms, or both terms. For example, the phrase "A or B" will be understood to include the possibilities of "A" or "B" or "A and B."

While various aspects and embodiments have been disclosed herein, other aspects and embodiments will be apparent to those skilled in the art. The various aspects and embodiments disclosed herein are for purposes of illustration and are not intended to be limiting, with the true scope and spirit being indicated in the description.

Referral Numerals
Description Reference Number
Flowchart 101-104
System 200
Signal analyzer 201
Plurality of sensors 203a-203l
Wave generating module 204
Pipeline 205
Sediment deposit 206
Processing unit 207
First time window A
Second time window B
Nth time window N