Reactor loop fouling monitor for rotating equipment in a petrochemical plant or refinery

Abstract

A plant or refinery may include equipment such as condensers, regenerators, distillation columns, rotating equipment, compressors, pumps, turbines, or the like. Different operating methods may impact deterioration in equipment condition, thereby prolonging equipment life, extending production operating time, or providing other benefits. Mechanical or digital sensors may be used for monitoring equipment to determine whether problems are developing. For example, sensors may be used in conjunction with one or more system components to perform invariant mapping, monitor system operating characteristics, and/or predict pressure, volume, surges, reactor loop fouling, gas quality, or the like. An operating condition (e.g., of one or more pieces of equipment in the plant or refinery) may be adjusted to prolong equipment life or avoid equipment failure.

Description

FIELD

The present disclosure is related to a method and system for improving the performance of components that make up operations in a plant, such as a carbonaceous processing plant, a chemical plant, a petrochemical plant, or a refinery. Typical plants may be those that provide catalytic dehydrogenation or hydrocarbon cracking.

BACKGROUND

A plant or refinery may include one or more pieces of equipment for performing a process. Equipment may break down over time, and need to be repaired or replaced. Additionally, a process may be more or less efficient depending on one or more operating characteristics. There will always be a need for improving process efficiencies and improving equipment reliability.

SUMMARY

The following summary presents a simplified summary of certain features. The summary is not an extensive overview and is not intended to identify key or critical elements.

One or more embodiments may include a system that includes a reactor; a heater; a compressor comprising one or more injection ports; one or more sensors associated with the compressor; a data collection platform, and/or a data analysis platform. The data collection platform may include one or more processors of the data collection platform; a communication interface of the data collection platform; and computer-readable memory storing executable instructions that, when executed, cause the data analysis platform to: receive, from the one or more sensors associated with the compressor, sensor data associated with the compressor and collected by the one or more sensors associated with the compressor; and send the sensor data associated with the compressor and collected by the one or more sensors associated with the compressor. The data analysis platform may include one or more processors of the data analysis platform; a communication interface of the data analysis platform; and computer-readable memory storing executable instructions that, when executed, cause the data analysis platform to: receive the sensor data associated with the compressor and collected by the one or more sensors associated with the compressor; analyze the sensor data associated with the compressor to determine potential fouling within the compressor; and based on determining the potential fouling within the compressor, send a command configured to cause an online wash via the one or more injection ports of the compressor to reduce the potential fouling within the compressor.

One or more embodiments may include one or more non-transitory computer-readable media storing executable instructions that, when executed, cause a data analysis platform to: receive sensor data associated with a compressor comprising one or more injection ports and collected by one or more sensors associated with the compressor; analyze the sensor data associated with the compressor to determine potential fouling within the compressor; and based on determining the potential fouling within the compressor, send a command configured to cause an online wash via the one or more injection ports of the compressor to reduce the potential fouling within the compressor.

One or more embodiments may include a method including receiving, by a data analysis computing device, sensor data associated with a compressor comprising one or more injection ports and collected by one or more sensors associated with the compressor; analyzing, by the data analysis computing device, the sensor data associated with the compressor to determine potential fouling within the compressor; and based on determining the potential fouling within the compressor, sending, by the data analysis computing device, a command configured to cause an online wash via the one or more injection ports of the compressor to reduce the potential fouling within the compressor.

Other technical features may be readily apparent to one skilled in the art from the following figures, descriptions, and claims.

BRIEF DESCRIPTION OF DRAWINGS

The present disclosure is illustrated by way of example and not limited in the accompanying figures in which like reference numerals indicate similar elements and in which:

FIG. 1 depicts an illustrative arrangement for a catalytic dehydrogenation process in accordance with one or more example embodiments;

FIG. 2 depicts an illustrative arrangement for a fluid catalytic cracking process in accordance with one or more example embodiments;

FIG. 3 depicts an illustrative arrangement for a centrifugal compressor configured for use in connection with the arrangement of FIGS. 1 and/or 2 in accordance with one or more example embodiments;

FIG. 4 depicts an illustrative arrangement for an axial compressor configured for use in connection with the arrangement of FIGS. 1 and/or 2 in accordance with one or more example embodiments;

FIG. 5 depicts a graph illustrating typical performance operation of a centrifugal or axial compressor in accordance with one or more example embodiments;

FIG. 6 depicts an illustrative arrangement for a portion of a reciprocating compressor configured for use in connection with the arrangement of FIGS. 1 and/or 2 in accordance with one or more example embodiments;

FIG. 7 depicts an illustrative arrangement for a reciprocating compressor configured for use in connection with the arrangement of FIGS. 1 and/or 2 in accordance with one or more example embodiments;

FIG. 8 depicts an illustrative arrangement for a steam turbine configured for use in connection with the arrangement of FIGS. 1 and/or 2 in accordance with one or more example embodiments;

FIG. 9 depicts an illustrative arrangement for a centrifugal compressor with pressure, temperature, and vibration sensors configured for use in connection with the arrangement of FIG. 1 in accordance with one or more example embodiments;

FIG. 10 depicts an illustrative arrangement for a centrifugal compressor with wash injection ports configured for use in connection with the arrangement of FIGS. 1 and/or 2 in accordance with one or more example embodiments;

FIG. 11A depicts an illustrative computing environment for managing the operation of one or more pieces of equipment in a plant in accordance with one or more example embodiments;

FIG. 11B depicts an illustrative data collection computing platform for collecting data related to the operation of one or more pieces of equipment in a plant in accordance with one or more example embodiments;

FIG. 11C depicts an illustrative data analysis computing platform for analyzing data related to the operation of one or more pieces of equipment in a plant in accordance with one or more example embodiments;

FIG. 11D depicts an illustrative data analysis computing platform for analyzing data related to the operation of one or more pieces of equipment in a plant in accordance with one or more example embodiments;

FIG. 11E depicts an illustrative control computing platform for controlling one or more parts of one or more pieces of equipment in a plant in accordance with one or more example embodiments;

FIGS. 12A-12B depict an illustrative flow diagram of one or more steps that one more devices may perform in controlling one or more aspects of a plant operation in accordance with one or more example embodiments;

FIGS. 13-14 depict illustrative graphical user interfaces related to one or more aspects of a plant operation in accordance with one or more example embodiments; and

FIG. 15 depicts an illustrative flowchart of a process that one or more devices may perform in controlling one or more aspects of a plant operation in accordance with one or more example embodiments.

DETAILED DESCRIPTION

In the following description of various illustrative embodiments, reference is made to the accompanying drawings, which form a part hereof, and in which is shown, by way of illustration, various embodiments in which aspects of the disclosure may be practiced. It is to be understood that other embodiments may be used, and structural and functional modifications may be made, without departing from the scope of the present disclosure.

It is noted that various connections between elements are discussed in the following description. It is noted that these connections are general and, unless specified otherwise, may be direct or indirect, wired or wireless, and that the specification is not intended to be limiting in this respect.

A chemical plant or a petrochemical plant or a refinery may include one or more pieces of equipment that process one or more input chemicals to create one or more products. For example, catalytic dehydrogenation can be used to convert paraffins to the corresponding olefin, e.g., propane to propene, or butane to butene.

A multitude of process equipment may be used in the chemical, refining, and petrochemical industry including, but not limited to, slide valves, rotating equipment, pumps, compressors, heat exchangers, fired heaters, control valves, fractionation columns, reactors, and/or shut-off valves.

Elements of chemical and petrochemical/refinery plants may be exposed to the outside and thus can be exposed to various environmental stresses. Such stresses may be weather related, such as temperature extremes (hot and cold), high-wind conditions, and precipitation conditions such as snow, ice, and rain. Other environmental conditions may be pollution particulates, such as dust and pollen, or salt if located near an ocean, for example. Such stresses can affect the performance and lifetime of equipment in the plants. Different locations may have different environmental stresses. For example, a refinery in Texas may have different stresses than a chemical plant in Montana.

Process equipment may deteriorate over time, affecting the performance and integrity of the process. Such deteriorating equipment may ultimately fail, but before failing, may decrease efficiency, yield, and/or product properties. It is desirable that corrective actions be taken in advance of equipment inefficiencies and/or failure.

FIG. 1 shows one typical arrangement for a catalytic dehydrogenation process 5. The process 5 includes a reactor section 10, a catalyst regeneration section 15, and a product recovery section 20.

The reactor section 10 includes one or more reactors 25. A hydrocarbon feed 30 is sent to a heat exchanger 35 where it exchanges heat with a reactor effluent 40 to raise the feed temperature. The feed 30 is sent to a preheater 45 where it is heated to the desired inlet temperature. The preheated feed 50 is sent from the preheater 45 to the first reactor 25. Because the dehydrogenation reaction is endothermic, the temperature of the effluent 55 from the first reactor 25 is less than the temperature of the preheated feed 50. The effluent 55 is sent to interstage heaters 60 to raise the temperature to the desired inlet temperature for the next reactor 25.

After the last reactor, the reactor effluent 40 is sent to the heat exchanger 35, and heat is exchanged with the feed 30. The reactor effluent 40 is then sent to the product recovery section 20. The catalyst 65 moves through the series of reactors 25. When the catalyst 70 leaves the last reactor 25, it is sent to the catalyst regeneration section 15. The catalyst regeneration section 15 includes a regenerator 75 where coke on the catalyst is burned off and the catalyst may go through a reconditioning step. A regenerated catalyst 80 is sent back to the first reactor 25.

The reactor effluent 40 is compressed in the compressor or centrifugal compressor 82. The compressed effluent 115 is introduced to a cooler 120, for instance a heat exchanger. The cooler 120 lowers the temperature of the compressed effluent. The cooled effluent 125 (cooled product stream) is then introduced into a chloride remover 130, such as a chloride scavenging guard bed. The chloride remover 130 includes an adsorbent, which adsorbs chlorides from the cooled effluent 125 and provides a treated effluent 135. Treated effluent 135 is introduced to a drier 84.

The dried effluent is separated in separator 85. Gas 90 is expanded in expander 95 and separated into a recycle hydrogen stream 100 and a net separator gas stream 105. A liquid stream 110, which includes the olefin product and unconverted paraffin, is sent for further processing, where the desired olefin product is recovered and the unconverted paraffin is recycled to the dehydrogenation reactor 25.

FIG. 2 shows a typical fluid catalytic cracking (FCC) process, which includes an FCC fluidized bed reactor and a spent catalyst regenerator. Regenerated cracking catalyst entering the reactor, from the spent catalyst regenerator, is contacted with an FCC feed stream in a riser section at the bottom of the FCC reactor, to catalytically crack the FCC feed stream and provide a product gas stream, comprising cracked hydrocarbons having a reduced molecular weight, on average, relative to the average molecular weight of feed hydrocarbons in the FCC feed stream. As shown in FIG. 2, steam and lift gas are used as carrier gases that upwardly entrain the regenerated catalyst in the riser section, as it contacts the FCC feed. In this riser section, heat from the catalyst vaporizes the FCC feed stream, and contact between the catalyst and the FCC feed causes cracking of this feed to lower molecular weight hydrocarbons, as both the catalyst and feed are transferred up the riser and into the reactor vessel. A product gas stream comprising the cracked (e.g., lower molecular weight) hydrocarbons may be separated from spent cracking catalyst at or near the top of the reactor vessel, preferably using internal solid/vapor separation equipment, such as cyclone separators. This product gas stream, essentially free of spent cracking catalyst, then exits the reactor vessel through a product outlet line for further transport to the downstream product recovery section.

The spent or coked catalyst, following its disengagement or separation from the product gas stream, requires regeneration for further use. This coked catalyst first falls into a dense bed stripping section of the FCC reactor, into which steam is injected, through a nozzle and distributor, to purge any residual hydrocarbon vapors that would be detrimental to the operation of the regenerator. After this purging or stripping operation, the coked catalyst is fed by gravity to the catalyst regenerator through a spent catalyst standpipe. FIG. 2 depicts a regenerator, which can also be referred to as a combustor. Various configurations of regenerators may be used. In the spent catalyst regenerator, a stream of oxygen-containing gas, such as air, is introduced to contact the coked catalyst, burn coke deposited thereon, and provide regenerated catalyst, having most or all of its initial coke content converted to combustion products, including CO2, CO, and H2O vapors that exit in a flue gas stream. The regenerator operates with catalyst and the oxygen-containing gas (e.g., air) flowing upwardly together in a combustor riser that is located within the catalyst regenerator. At or near the top of the regenerator, following combustion of the catalyst coke, regenerated cracking catalyst is separated from the flue gas using internal solid/vapor separation equipment (e.g., cyclones) to promote efficient disengagement between the solid and vapor phases.

In the FCC recovery section, the product gas stream exiting the FCC reactor is fed to a bottom section of an FCC main fractionation column. Several product fractions may be separated on the basis of their relative volatilities and recovered from this main fractionation column. Representative product fractions include, for example, naphtha (or FCC gasoline), light cycle oil, and heavy cycle oil.

Other petrochemical processes produce desirable products, such as turbine fuel, diesel fuel and other products referred to as middle distillates, as well as lower boiling hydrocarbonaceous liquids, such as naphtha and gasoline, by hydrocracking a hydrocarbon feedstock derived from crude oil or heavy fractions thereof. Feedstocks most often subjected to hydrocracking are the gas oils and heavy gas oils recovered from crude oil by distillation.

References herein to a “plant” are to be understood to refer to any of various types of chemical and petrochemical manufacturing or refining facilities. References herein to a plant “operators” are to be understood to refer to and/or include, without limitation, plant planners, managers, engineers, technicians, operators, and others interested in, overseeing, and/or running the daily operations at a plant.

Rotating Equipment Technology

A system or arrangement as described above may include various compressors, pumps, and/or turbines, and FIGS. 1 and 2 illustrate example locations for some of such components, which may be additionally or alternately used in other locations. Compressors may be used to compress gases within the system (e.g., a reactor effluent) to provide a compressed gas. Compression includes increasing a pressure of the gas and may also change other properties such as temperature. Pumps may be used to force fluids through the system. Centrifugal pumps are an example of a frequently used pump in a plant as described herein. Turbines may be used for harnessing heat energy generated by the plant, such as to convert the heat energy into electrical energy and/or to power fans or other rotating equipment. Steam turbines, for example, are often used in a plant as described herein.

There are several types of compressors typically used in chemical and petrochemical plants and refineries, the most common of which are centrifugal compressors, axial compressors, and reciprocating compressors. Many compressors in a plant as described herein are arranged in parallel with a redundant backup compressor, which can be activated to prevent total shutdown when the original compressor needs to be taken offline. Centrifugal and axial compressors are dynamic compressors that operate by transferring energy from a set of rotating impeller blades to a gas, which is then converted into potential energy in the form of increased gas pressure by diffusers that slow the flow of the gas, creating a pressurized output gas. FIG. 3 illustrates an example of a centrifugal compressor 310, which includes an inlet or intake 311, a plurality of impellers 313 mounted on a rotatable shaft 318 and located downstream from the inlet 311, and a plurality of diffusers 316 each located following one of the impellers 313, and an outlet or discharge 317 at the far downstream end of the compressor 310. The compressor 310 operates by building pressure incrementally and sequentially in the diffusers 316. FIG. 4 illustrates an example of an axial compressor 320, which includes an inlet or intake 321 a plurality of impellers 323 mounted on a rotatable shaft 328 and located downstream from the inlet 321, a stator 324 that has a plurality of stator vanes 325 arranged in circumferential rings each located downstream from one of the impellers 323 and operates as a diffuser 326, and an outlet or discharge 327 at the far downstream end of the compressor 320.

Centrifugal or axial compressors may be referred to as dynamic compressors or turbomachinery. Such compressors often have other components immediately upstream and downstream that enhance or enable the functioning of the compressor. Examples of such equipment include isolation valves, a suction strainers, a compressor suction drum or separator, an anti-surge spillback takeoff, a feed mix node and combined feed exchanger for H2 recycle, and an interstage drum or knockout drum.

Performance of all types of compressors may be affected by changes in gas conditions, including gas temperature and the composition and/or molecular weight of the gas, among other factors. Process control of capacity may be made by speed variation, suction throttling, or variable inlet guide vanes. Compressors can be put through a variety of extreme conditions, such as high temperatures and pressures and corrosive and aggressive components.

Surge is a common issue faced by all centrifugal and axial compressors. Surge occurs when the outlet or discharge pressure of the compressor is equal to or greater than the pressure generated by the impellers 313, 323. In a centrifugal or axial compressor, this phenomenon typically occurs within the final diffuser 316, 326 before the outlet 317, 327. When this occurs, the increased outlet pressure drives airflow temporarily backward toward the impeller or impellers 313, 323. Surge typically happens in an oscillatory manner and is often accompanied by rapid (even exponential) temperature increase. Various factors can cause surging, such as increased discharge pressure, improper valve cycling, change in gas composition (e.g., decreased molecular weight of the gas), ramping the feed rate too fast, improper limit stop set point on the valves, and other operational errors or malfunctions, among other factors. Surge can decrease the effectiveness and efficiency of the compressor, and the vibrations, thrust reversals, and temperature increases that result from surging can damage components of the compressor (sometimes quickly) and reduce the functional life of the compressor. For example, vibrations and thrust reversal can cause damage to bearings and seals, and potentially cause contact between rotating and stationary parts. As another example, temperature increases can cause damage to seals, thermal expansion of the rotor/impeller, and contact between rotating and stationary parts.

Each dynamic compressor has a surge limit that represents a limit on operation of the compressor. FIG. 5 illustrates the performance operating of a centrifugal compressor, plotting change in pressure (ΔP) against flow, with the surge limit forming a performance limitation of the compressor. Normal operation occurs between the lines defined by the maximum and minimum compressor speeds and to the right of the surge line, and surge occurs when the surge line is crossed. An axial compressor may perform in a similar manner.

Additional issues faced by centrifugal or axial compressors include bearing and seal failures, wear, fouling, and damage from contact between moving and non-moving components, among others. Such failures may be caused by vibrations, thrust reversals, excessive temperature, and unwanted chemicals in the feed gas. Some of these issues may directly or indirectly result from surging, but these issues may result from other causes as well, including other causes described elsewhere herein.

A reciprocating compressor is a positive-displacement compressor that operates by a moveable member, e.g., a piston and/or a membrane/diaphragm, moving to decrease the volume of a cylinder filled with a gas, thereby compressing the gas within the cylinder. FIG. 6 illustrates an example of a piston-type reciprocating compressor 330, which includes a cylinder 331 with an inlet or intake 332 and an outlet or discharge 333, with a piston 334 that reciprocates to draw gases in through the inlet 332 and compress gases contained in the cylinder 331. The inlet 332 and the outlet 333 may further have inlet and outlet valves to permit intake of gas through the inlet 332 and discharge of compressed gas through the outlet 333 at appropriate times. The opening and closing of such valves is critical to the operation of the compressor. The valves should operate smoothly and timely as well as fully open and close at appropriate times. Vibrations and contaminants can affect the performance and integrity of the valves and their operation The compressor 330 illustrated in FIG. 7 also includes a piston rod, a crosshead connected to the piston rod that rides within a crosshead guide, a crosshead pin, rider rings on the piston 334, a head end or cylinder end (CE) head, a pressure packing case, and a piston rod drop transducer. Many reciprocating compressors may include multiple cylinders 331 as shown in FIG. 6, and the inlets in such an embodiment may be provided through an intake manifold or suction manifold. FIG. 6 also illustrates the valve heads 338 of the compressor 330. The piston(s) 334 in a reciprocating compressor 330 may be driven by a crankshaft 337 in one or more embodiments.

Reciprocating compressors often have other components immediately upstream and downstream that enhance or enable the functioning of the compressor. Examples of such equipment include an isolation valve, a suction strainer, an interstage cooler or aftercooler, and a discharge drum.

One issue facing reciprocating compressors is ingress of liquid contaminants, which may occur through a variety of mechanisms, such as improper separation between gas and liquid components at some point along the line, seal leakage, condensation caused by insufficient temperature at some point along the line and compounded by poor suction pipe layout. Liquids are incompressible, and therefore, ingress of liquids into the compressor can negatively affect operation of the compressor. Other contaminants, such as particulates or debris entrained in the gas flow, also present issues for reciprocating compressors. Ingress of liquid or other contaminants can damage a reciprocating compressor, and in particular may cause valve distress and failure. Ingress of such contaminants may also cause fouling of equipment, process drifting, and/or decreasing capacity and efficiency.

A turbine is a device that extracts energy from a fluid flow and converts it into work, e.g., mechanical or electrical power. FIG. 8 illustrates an example of a steam turbine 340 that may be used in a plant as described herein. The turbine 340 includes an inlet 341 that receives steam 342 from a steam source, a rotor 343 with blades 344 that are acted on by the impulse of the steam 342 flowing through the inlet 341 to turn the rotor 343, and a shaft 345 that is rotated by the rotor 343 to generate mechanical power (e.g., by connection to gears) or electrical power (e.g., by use of induction equipment). The steam then escapes through an outlet 346. Heat generated by various components of the plant may be harnessed to create steam at the steam source, which is passed to the steam turbine 340 for conversion to mechanical or electrical power.

Issues faced by turbines in petrochemical plants include failure of trip and throttle valves, damage to flow path components (e.g., stationary or rotating blades) due to “wet” steam that is not of sufficiently high temperature, and failure of the turbine for mechanical reasons.

In various embodiments described herein, as described in further detail below, different types of sensors may be used in and around rotating equipment components such as compressors and turbines, including centrifugal compressors, axial compressors, reciprocating compressors, and/or steam turbines as described above. Data from such sensors can then be analyzed in a manual and/or automated manner, and corrective actions or recommendations for such actions can be generated based on such analysis. It is understood that any sensor described herein may be configured for communicating the data gathered by the sensor to a computer system, including by various wired or wireless technologies. In one or more embodiments, each sensor described herein may include a wireless transmitter (or transceiver) for wirelessly communicating with a computer system. In another embodiment, some or all of the sensors described herein may include an individual processor and/or memory configured for processing communications to/from the computer system or processing and/or storing data independently or in conjunction with the computer system.

Sensor Data Collection and Processing

The system may include one or more computing devices or platforms for collecting, storing, processing, and analyzing data from one or more sensors. FIG. 11A depicts an illustrative computing system that may be implemented at one or more components, pieces of equipment (e.g., rotating equipment), and/or plants. FIG. 11A-FIG. 11E (hereinafter collectively “FIG. 11”), show, by way of illustration, various components of the illustrative computing system in which aspects of the disclosure may be practiced. It is to be understood that other components may be used, and structural and functional modifications may be made, in one or more other embodiments without departing from the scope of the present disclosure. Moreover, various connections between elements are discussed in the following description, and these connections are general and, unless specified otherwise, may be direct or indirect, wired or wireless, and/or combination thereof, and that the specification is not intended to be limiting in this respect.

FIG. 11A depicts an illustrative operating environment in which various aspects of the present disclosure may be implemented in accordance with example embodiments. The computing system environment 1000 illustrated in FIG. 11A is only one example of a suitable computing environment and is not intended to suggest any limitation as to the scope of use or functionality contained in the disclosure. The computing system environment 1000 may include various sensor, measurement, and data capture systems, a data collection platform 1002, a data analysis platform 1004, a control platform 1006, one or more networks, one or more remote devices 1054, 1056, and/or one or more other elements. The numerous elements of the computing system environment of FIG. 11A may be communicatively coupled through one or more networks. For example, the numerous platforms, devices, sensors, and/or components of the computing system environment may be communicatively coupled through a private network 1008. The sensors be positioned on various components in the plant and may communicate wirelessly or wired with one or more platforms illustrated in FIG. 11A. The private network 1008 may include, in some examples, a network firewall device to prevent unauthorized access to the data and devices on the private network 1008. Alternatively or additionally, the private network 1008 may be isolated from external access through physical means, such as a hard-wired network with no external, direct access point. The data communicated on the private network 1008 may be optionally encrypted for further security. Depending on the frequency of collection and transmission of sensor measurements and other data to the data collection platform 1002, the private network 1008 may experience large bandwidth usage and be technologically designed and arranged to accommodate for such technological issues. Moreover, the computing system environment 1000 may also include a public network 1010 that may be accessible to remote devices (e.g., remote device 1054, remote device 1056). In some examples, a remote device may be located not in the proximity (e.g., more than one mile away) of the various sensor, measurement, and data capture systems illustrated in FIG. 11A. In other examples, the remote device may be physically located inside a plant, but restricted from access to the private network 1008; in other words, the adjective “remote,” need not necessarily require the device to be located at a great distance from the sensor systems and other components.

Although the computing system environment of FIG. 11A illustrates logical block diagrams of numerous platforms and devices, the disclosure is not so limited. In particular, one or more of the logical boxes in FIG. 11 may be combined into a single logical box or the functionality performed by a single logical box may be divided across multiple existing or new logical boxes. For example, aspects of the functionality performed by the data collection platform 1002 may be incorporated into one or each of the sensor devices illustrated in FIG. 11A. As such, the data collection may occur local to the sensor device, and the enhanced sensor system may communicate directly with one or more of the control platform 1006 and/or data analysis platform 1004. An illustrative example of such an embodiment is contemplated by FIG. 11A. Moreover, in such an embodiment, the enhanced sensor system may measure values common to a sensor, but may also filter the measurements such just those values that are statistically relevant or of-interest to the computing system environment are transmitted by the enhanced sensor system. As a result, the enhanced sensor system may include a processor (or other circuitry that enables execution of computer instructions) and a memory to store those instructions and/or filtered data values. The processor may be embodied as an application-specific integrated circuit (ASIC), FPGA, or other hardware- or software-based module for execution of instructions. In another example, one or more sensors illustrated in FIG. 11A may be combined into an enhanced, multi-purpose sensor system. Such a combined sensor system may provide economies of scale with respect to hardware components such as processors, memories, communication interfaces, and others.

In yet another example, the data collection platform 1002 and data analysis platform 1004 may reside on a single server computer and depicted as a single, combined logical box on a system diagram. Moreover, a data store may be illustrated in FIG. 11A separate and apart from the data collection platform 1002 and data analysis platform 1004 to store a large amount of values collected from sensors and other components. The data store may be embodied in a database format and may be made accessible to the public network 1010; meanwhile, the control platform 1006, data collection platform 1002, and data analysis platform 1004 may be restricted to the private network 1008 and left inaccessible to the public network 1010. As such, the data collected from a plant may be shared with users (e.g., engineers, data scientists, others), a company's employees, and even third parties (e.g., subscribers to the company's data feed) without compromising potential security requirements related to operation of a plant. The data store may be accessible to one or more users and/or remote devices over the public network 1010.

Referring to FIG. 11A, process measurements from various sensor and monitoring devices may be used to monitor conditions in, around, and on process equipment (e.g., rotating equipment). Such sensors may include, but are not limited to, pressure sensors 1024, differential pressure sensors 1036, various flow sensors (including but not limited to orifice plate type 1013, disc sensors 1022, venturi 1038, other flow sensors 1030), temperature sensors 1012 including thermal cameras 1020 and skin thermocouples, capacitance sensors 1034, weight sensors 1032, gas chromatographs 1014, moisture sensors 1016, ultrasonic sensors 1018, position sensors, timing sensors, vibration sensors 1026, microphones 1028, level sensors 1046, liquid level (hydraulic fluid) sensors, and other sensors used in the refining and petrochemical industry. Further, process laboratory measurements may be taken using gas chromatographs 1014, liquid chromatographs, distillation measurements, octane measurements, and other laboratory measurements. System operational measurements also can be taken to correlate the system operation to the rotating equipment measurements.

In addition, sensors may include transmitters and/or deviation alarms. One or more sensors may be programmed to set off an alarm or alert. For example, if an actuator fails, sensor data may be used to automatically trigger an alarm or alert (e.g., an audible alarm or alert, a visual alarm or alert). Other sensors may transmit signals to a processor or a hub that collects the data and sends to a processor. For example, temperature and pressure measurements may be sent to a hub (e.g., data collection platform 1002). In one or more embodiments, temperature sensors 1012 may include thermocouples, fiber optic temperature measurement, thermal cameras 1020, and/or infrared cameras. Skin thermocouples may be applied to rotating equipment casing, or alternatively, to tubes, plates, or placed directly on a wall of a rotating equipment component. Alternatively, thermal (infrared) cameras 1020 may be used to detect temperature in one or more aspects of the equipment. A shielded (insulated) tube skin thermocouple assembly may be used to obtain accurate measurements. One example of a thermocouple may be a removable Xtracto™ Pad. A thermocouple can be replaced without any additional welding. Clips and/or pads may be used for ease of replacement. Fiber Optic cable can be attached to the pipe, line, and/or vessel to provide a complete profile of temperatures.

Sensors may be also used throughout a plant or rotating equipment to detect and monitor various issues such as PV detection, surge detection, fouling, gas quality, dew point characteristics, and/or production levels. Sensors might be able to detect whether feed composition into the rotating equipment, such as pH, are outside of acceptable ranges leading to a corrosive environment or whether consumption of sacrificial anodes (in water services) is nearing completion and resulting in a corrosive environment. Sensors detecting outlet temperatures and pressure drops may be used to determine/predict flow and production rate changes.

Furthermore, flow sensors may be used in flow paths such as the inlet to the path, outlet from the path, or within the path. If multiple tubes are used, the flow sensors may be placed in corresponding positions in each of the rotating machines. In this manner, one can determine if one of the rotating machines is behaving abnormally compared to one or more others. Flow may be determined by pressure-drop across a known resistance, such as by using pressure taps. In other examples, flow may be inferred using fluid density in addition to suction and discharge pressures. Other types of flow sensors include, but are not limited to, ultrasonic, turbine meter, hot wire anemometer, vane meter, Kármán™, vortex sensor, membrane sensor (membrane has a thin film temperature sensor printed on the upstream side, and one on the downstream side), tracer, radiographic imaging (e.g. identify two-phase vs. single-phase region of channels), an orifice plate (e.g., which may in some examples, be placed in front of one or more tube or channels), pitot tube, thermal conductivity flow meter, anemometer, internal pressure flow profile.

Sensor data, process measurements, and/or calculations made using the sensor data or process measurements may be used to monitor and/or improve the performance of the equipment and parts making up the equipment, as discussed in further detail below. For example, sensor data may be used to detect that a desirable or an undesirable chemical reaction is taking place within a particular piece of equipment, and one or more actions may be taken to encourage or inhibit the chemical reaction. Chemical sensors may be used to detect the presence of one or more chemicals or components in the streams, such as corrosive species, oxygen, hydrogen, and/or water (moisture). Chemical sensors may use gas chromatographs, liquid chromatographs, distillation measurements, and/or octane measurements. In another example, equipment information, such as wear, efficiency, production, state, or other condition information, may be gathered and determined based on sensor data. Corrective action may be taken based on determining this equipment information. For example, if the equipment is showing signs of wear or failure, corrective actions may be taken, such as taking an inventory of parts to ensure replacement parts are available, ordering replacement parts, and/or calling in repair personnel to the site. Certain parts of equipment may be replaced immediately. Other parts may be safe to use, but a monitoring schedule may be adjusted. Alternatively or additionally, one or more inputs or controls relating to a process may be adjusted as part of the corrective action. These and other details about the equipment, sensors, processing of sensor data, and actions taken based on sensor data are described in further detail below.

Monitoring the rotating equipment and the processes using rotating equipment includes collecting data that can be correlated and used to predict behavior or problems in different rotating equipment used in the same plant or in other plants and/or processes. Data collected from the various sensors (e.g., measurements such as flow, pressure drop, thermal performance, vessel skin temperature at the top, expansion bellows leak, vibration, etc.) may be correlated with external data, such as environmental or weather data. Process changes or operating conditions may be able to be altered to preserve the equipment until the next scheduled maintenance period. Fluids may be monitored for corrosive contaminants and pH may monitored in order to predict higher than normal corrosion rates within the rotating equipment.

Systems Facilitating Sensor Data Collection

Sensor data may be collected by a data collection platform 1002. The sensors may interface with the data collection platform 1002 via wired or wireless transmissions. The data collection platform 1002 may continuously or periodically (e.g., every second, every minute, every hour, every day, once a week, once a month) transmit collected sensor data to a data analysis platform 1004, which may be nearby or remote from the data collection platform 1002.

Sensor data (e.g., temperature data) may be collected continuously or at periodic intervals (e.g., every second, every five seconds, every ten seconds, every minute, every five minutes, every ten minutes, every hour, every two hours, every five hours, every twelve hours, every day, every other day, every week, every other week, every month, every other month, every six months, every year, or another interval). Data may be collected at different locations at different intervals. For example, data at a known hot spot may be collected at a first interval, and data at a spot that is not a known hot spot may be collected at a second interval. The data collection platform transmit collected sensor data to a data analysis platform, which may be nearby or remote from the data collection platform.

The computing system environment of FIG. 11A includes logical block diagrams of numerous platforms and devices that are further elaborated upon in FIG. 11B, FIG. 11C, FIG. 11D, and FIG. 11E. FIG. 11B is an illustrative data collection platform 1002. FIG. 11C is an illustrative data analysis platform 1004. FIG. 11D is an illustrative control platform 1006. FIG. 11E is an illustrative remote device 1054. These platforms and devices of FIG. 11 include one or more processing units (e.g., processors) to implement the methods and functions of certain aspects of the present disclosure in accordance with the example embodiments. The processors may include general-purpose microprocessors and/or special-purpose processors designed for particular computing system environments or configurations. For example, the processors may execute computer-executable instructions in the form of software and/or firmware stored in the memory of the platform or device. Examples of computing systems, environments, and/or configurations that may be suitable for use with the disclosed embodiments include, but are not limited to, personal computers (PCs), server computers, hand-held or laptop devices, smart phones, multiprocessor systems, microprocessor-based systems, programmable consumer electronics, network PCs, minicomputers, mainframe computers, distributed computing environments that include any of the above systems or devices, and the like.

In addition, the platform and/or devices in FIG. 11 may include one or more memories include any of a variety of computer readable media. Computer-readable media may be any available media that may be accessed by the data collection platform 1002, may be non-transitory, and may include volatile and nonvolatile, removable and non-removable media implemented in any method or technology for storage of information such as computer-readable instructions, object code, data structures, database records, program modules, or other data. Examples of computer-readable media may include random access memory (RAM), read only memory (ROM), electronically erasable programmable read only memory (EEPROM), flash memory or other memory technology, compact disk read-only memory (CD-ROM), digital versatile disks (DVD) or other optical disk storage, magnetic cassettes, magnetic tape, magnetic disk storage or other magnetic storage devices, or any other medium that can be used to store the desired information and that can be accessed by the data collection platform 1002. The memories in the platform and/or devices may further store modules that may include compiled software code that causes the platform, device, and/or overall system to operate in a technologically improved manner as disclosed herein. For example, the memories may store software used by a computing platform, such as operating system, application programs, and/or associated database.

Furthermore, the platform and/or devices in FIG. 11 may include one or more communication interfaces including, but are not limited to, a microphone, keypad, keyboard, touch screen, and/or stylus through which a user of a computer (e.g., a remote device) may provide input, and may also include a speaker for providing audio output and a video display device for providing textual, audiovisual and/or graphical output. Input may be received via one or more graphical user interfaces, which may be part of one or more dashboards (e.g., dashboard 1003, dashboard 1005, dashboard 1007). The communication interfaces may include a network controller for electronically communicating (e.g., wirelessly or wired) over a public network 1010 or private network 1008 with one or more other components on the network. The network controller may include electronic hardware for communicating over network protocols, including TCP/IP, UDP, Ethernet, and other protocols.

In some examples, one or more sensor devices in FIG. 11A may be enhanced by incorporating functionality that may otherwise be found in a data collection platform 1002. These enhanced sensor system may provide further filtering of the measurements and readings collected from their sensor devices. For example, with some of the enhanced sensor systems in the operating environment illustrated in FIG. 11A, an increased amount of processing may occur at the sensor so as to reduce the amount of data needing to be transferred over a private network 1008 in real-time to a computing platform. The enhanced sensor system may filter at the sensor itself the measured/collected/captured data and only particular, filtered data may be transmitted to the data collection platform 1002 for storage and/or analysis.

Referring to FIG. 11B, in one or more embodiments, a data collection platform 1002 may include one or more processors 1060, one or more memories 1062, and communication interfaces 1068. The memory 1062 may include a database 1064 for storing data records of various values collected from one or more sources. In addition, a data collection module 1066 may be stored in the memory 1062 and assist the processor 1060 in the data collection platform 1002 in communicating with, via the communications interface 1068, one or more sensor, measurement, and data capture systems, and processing the data received from these sources. In some embodiments, the data collection module 1066 may include computer-executable instructions that, when executed by the processor 1060, cause the data collection platform 1002 to perform one or more of the steps disclosed herein. In other embodiments, the data collection module 1066 may be a hybrid of software-based and/or hardware-based instructions to perform one or more of the steps disclosed herein. In some examples, the data collection module 1066 may assist an enhanced sensor system with further filtering the measurements and readings collected from the sensor devices. Although the elements of FIG. 11B are illustrated as logical block diagrams, the disclosure is not so limited. In particular, one or more of the logical boxes in FIG. 11B may be combined into a single logical box or the functionality performed by a single logical box may be divided across multiple existing or new logical boxes. Moreover, some logical boxes that are visually presented as being inside of another logical box may be moved such that they are partially or completely residing outside of that logical box. For example, while the database 1064 in FIG. 11B is illustrated as being stored inside one or more memories 1062 in the data collection platform 1002, FIG. 11B contemplates that the database 1064 may be stored in a standalone data store communicatively coupled to the data collection module 1066 and processor 1060 of the data collection platform 1002 via the communications interface 1068 of the data collection platform 1002.

In addition, the data collection module 1066 may assist the processor 1060 in the data collection platform 1002 in communicating with, via the communications interface 1068, and processing data received from other sources, such as data feeds from third-party servers and manual entry at the field site from a dashboard graphical user interface (e.g., via dashboard 1003). For example, a third-party server may provide contemporaneous weather data to the data collection module. Some elements of chemical and petrochemical/refinery plants may be exposed to the outside and thus may be exposed to various environmental stresses. Such stresses may be weather related such as temperature extremes (hot and cold), high wind conditions, and precipitation conditions such as snow, ice, and rain. Other environmental conditions may be pollution particulates such as dust and pollen, or salt if located near an ocean, for example. Such stresses can affect the performance and lifetime of equipment in the plants. Different locations may have different environmental stresses. For example, a refinery in Texas will have different stresses than a chemical plant in Montana. In another example, data manually entered from a dashboard graphical user interface (e.g., via dashboard 1003) (or other means) may be collected and saved into memory by the data collection module. Production rates may be entered and saved in memory. Tracking production rates may indicate issues with flows. For example, as fouling occurs, the production rate may fall if a specific outlet temperature can no longer be achieved at the targeted capacity and capacity has to be reduced to maintain the targeted outlet temperature.

Referring to FIG. 11C, in one or more embodiments, a data analysis platform 1004 may include one or more processors 1070, one or more memories 1072, and communication interfaces 1082. The memory 1072 may include a database 1074 for storing data records of various values collected from one or more sources. Alternatively or additionally, the database 1074 may be the same database as that depicted in FIG. 11B and the data analysis platform 1004 may communicatively couple with the database 1074 via the communication interface of the data analysis platform 1004. At least one advantage of sharing a database between the two platforms is the reduced memory requirements due to not duplicating the same or similar data. In addition, a data analysis module 1076 may be stored in the memory 1072 and assist the processor 1070 in the data analysis platform 1004 in processing and analyzing the data values stored in the database 1074. In some embodiments, the data analysis module 1076 may include computer-executable instructions that, when executed by the processor 1070, cause the data analysis platform 1004 to perform one or more of the steps disclosed herein. In other embodiments, the data analysis module 1076 may be a hybrid of software-based and/or hardware-based instructions to perform one or more of the steps disclosed herein. In some embodiments, the data analysis module 1076 may perform statistical analysis, predictive analytics, and/or machine learning on the data values in the database 1074 to generate predictions and models. For example, the data analysis platform 1004 may analyze sensor data to detect new problems and/or to monitor existing problems (e.g., to determine if an existing problem is growing, maintaining the same severity, or shrinking) in the equipment of a plant. The data analysis platform 1004 may compare temperature or other data from different dates to determine if changes are occurring. Such comparisons may be made on a monthly, weekly, daily, hourly, real-time, or some other basis.

Referring to FIG. 11C, the recommendation module 1078 in the data analysis platform 1004 may coordinate with the data analysis module 1076 to generate recommendations for adjusting one or more parameters for the operation of the plant environment depicted in FIG. 11A. In some embodiments, the recommendation module 1078 may communicate the recommendation to the command module 1080, which may generate command codes that may be transmitted, via the communications interface, to cause adjustments or halting/starting of one or more operations in the plant environment. The command codes may be transmitted to a control platform 1006 for processing and/or execution. In one or more embodiments, the command codes may be directly communicated, either wirelessly or in a wired fashion, to physical components at the plant such that the physical components include an interface to receive the commands and execute on them.

Although the elements of FIG. 11C are illustrated as logical block diagrams, the disclosure is not so limited. In particular, one or more of the logical boxes in FIG. 11C may be combined into a single logical box or the functionality performed by a single logical box may be divided across multiple existing or new logical boxes. Moreover, some logical boxes that are visually presented as being inside of another logical box may be moved such that they are partially or completely residing outside of that logical box. For example, while the database is visually depicted in FIG. 11C as being stored inside one or more memories in the data analysis platform 1004, FIG. 11C contemplates that the database may be stored in a standalone data store communicatively coupled to the data analysis module and processor of the data analysis platform 1004 via the communications interface of the data analysis platform 1004. Furthermore, the databases from multiple plant locations may be shared and holistically analyzed to identify one or more trends and/or patterns in the operation and behavior of the plant and/or plant equipment. In such a crowdsourcing-type example, a distributed database arrangement may be provided where a logical database may simply serve as an interface through which multiple, separate databases may be accessed. As such, a computer with predictive analytic capabilities may access the logical database to analyze, recommend, and/or predict the behavior of one or more aspects of plants and/or equipment. In another example, the data values from a database from each plant may be combined and/or collated into a single database where predictive analytic engines may perform calculations and prediction models.

Referring to FIG. 11D, in one or more embodiments, a control platform 1006 may include one or more processors 1084, one or more memories 1086, and communication interfaces 1092. The memory 1086 may include a database 1088 for storing data records of various values transmitted from a user interface, computing device, or other platform. The values may include parameter values for particular equipment at the plant. For example, some illustrative equipment at the plant that may be configured and/or controlled by the control platform 1006 include, but is not limited to, a feed switcher 1042, sprayer 1052, one or more valves 1044, one or more pumps 1040, one or more gates 1048, and/or one or more drains 1050. In addition, a control module 1090 may be stored in the memory and assist the processor in the control platform 1006 in receiving, storing, and transmitting the data values stored in the database. In some embodiments, the control module 1090 may include computer-executable instructions that, when executed by the processor 1084, cause the control platform 1006 to perform one or more of the steps disclosed herein. In other embodiments, the control module may be a hybrid of software-based and/or hardware-based instructions to perform one or more of the steps disclosed herein.

In a plant environment such as illustrated in FIG. 11A, if sensor data is outside of a safe range, this may be cause for immediate danger. As such, there may be a real-time component to the system such that the system processes and responds in a timely manner. Although in some embodiments, data could be collected and leisurely analyzed over a lengthy period of months, numerous embodiments contemplate a real-time or near real-time responsiveness in analyzing and generating alerts, such as those generated or received by the alert module in FIG. 11E.

Referring to FIG. 11E, in one or more embodiments, a remote device 1054 may include one or more processors 1093, one or more memories 1094, and communication interfaces 1099. The memory 1094 may include a database 1095 for storing data records of various values entered by a user or received through the communications interface. In addition, an alert module 1096, command module 1097, and/or dashboard module 1098 may be stored in the memory 1094 and assist the processor 1093 in the remote device 1054 in processing and analyzing the data values stored in the database. In some embodiments, the aforementioned modules may include computer-executable instructions that, when executed by the processor, cause the remote device 1054 to perform one or more of the steps disclosed herein. In other embodiments, the aforementioned modules may be a hybrid of software-based and/or hardware-based instructions to perform one or more of the steps disclosed herein. In some embodiments, the aforementioned modules may generate alerts based on values received through the communications interface. The values may indicate a dangerous condition or even merely a warning condition due to odd sensor readings. The command module 1097 in the remote device 1054 may generate a command that when transmitted through the communications interface to the platforms at the plant, causes adjusting of one or more parameter operations of the plant environment depicted in FIG. 11A. In some embodiments, the dashboard module 1098 may display a graphical user interface to a user of the remote device 1054 to enable the user to enter desired parameters and/or commands. These parameters/commands may be transmitted to the command module 1097 to generate the appropriate resulting command codes that may be then transmitted, via the communications interface, to cause adjustments or halting/starting of one or more operations in the plant environment. The command codes may be transmitted to a control platform 1006 for processing and/or execution. In one or more embodiments, the command codes may be directly communicated, either wirelessly or in a wired fashion, to physical components at the plant such that the physical components include an interface to receive the commands and execute them.

Although FIG. 11E is not so limited, in some embodiments the remote device 1054 may include a desktop computer, a smartphone, a wireless device, a tablet computer, a laptop computer, and/or the like. The remote device 1054 may be physically located locally or remotely, and may be connected by one of communications links to the public network 1010 that is linked via a communications link to the private network 1008. The network used to connect the remote device 1054 may be any suitable computer network including the Internet, an intranet, a wide-area network (WAN), a local-area network (LAN), a wireless network, a digital subscriber line (DSL) network, a frame relay network, an asynchronous transfer mode (ATM) network, a virtual private network 1008 (VPN), or any combination of any of the same. Communications links may be any communications links suitable for communicating between workstations and server, such as network links, dial-up links, wireless links, hard-wired links, as well as network types developed in the future, and the like. Various protocols such as transmission control protocol/Internet protocol (TCP/IP), Ethernet, file transfer protocol (FTP), hypertext transfer protocol (HTTP) and the like may be used, and the system can be operated in a client-server configuration to permit a user to retrieve web pages from a web-based server. Any of various conventional web browsers can be used to display and manipulate data on web pages.

Although the elements of FIG. 11E are illustrated as logical block diagrams, the disclosure is not so limited. In particular, one or more of the logical boxes in FIG. 11E may be combined into a single logical box or the functionality performed by a single logical box may be divided across multiple existing or new logical boxes. Moreover, some logical boxes that are visually presented as being inside of another logical box may be moved such that they are partially or completely residing outside of that logical box. For example, while the database is visually depicted in FIG. 11E as being stored inside one or more memories in the remote device 1054, FIG. 11E contemplates that the database may be stored in a standalone data store communicatively coupled, via the communications interface, to the modules stored at the remote device 1054 and processor of the remote device 1054.

Referring to FIG. 11, in some examples, the performance of operation in a plant may be improved by using a cloud computing infrastructure and associated methods, as described in US Patent Application Publication No. US2016/0260041, which was published Sep. 8, 2016, and which is herein incorporated by reference in its entirety. The methods may include, in some examples, obtaining plant operation information from the plant and/or generating a plant process model using the plant operation information. The method may include receiving plant operation information over the Internet, or other computer network (including those described herein) and automatically generating a plant process model using the plant operation information. These plant process models may be configured and used to monitor, predict, and/or optimize performance of individual process units, operating blocks and/or complete processing systems. Routine and frequent analysis of predicted versus actual performance may further allow early identification of operational discrepancies, which may be acted upon to optimize impact.

The aforementioned cloud computing infrastructure may use a data collection platform 1002 associated with a plant to capture data, e.g., sensor measurements, which may be automatically sent to the cloud infrastructure, which may be remotely located, where it may be reviewed to, for example, eliminate errors and biases, and used to calculate and report performance results. The data collection platform 1002 may include an optimization unit that acquires data from a customer site, other site, and/or plant (e.g., sensors and other data collectors at a plant) on a recurring basis. For cleansing, the data may be analyzed for completeness and corrected for gross errors by the optimization unit. The data may also be corrected for measurement issues (e.g., an accuracy problem for establishing a simulation steady state) and overall mass balance closure to generate a duplicate set of reconciled plant data. The corrected data may be used as an input to a simulation process, in which the process model is tuned to ensure that the simulation process matches the reconciled plant data. An output of the reconciled plant data may be used to generate predicted data using a collection of virtual process model objects as a unit of process design.

The performance of the plant and/or individual process units of the plant is/are compared to the performance predicted by one or more process models to identify any operating differences or gaps. Furthermore, the process models and collected data (e.g., plant operation information) may be used to run optimization routines that converge on an optimal plant operation for a given values of, e.g., feed, products, and/or prices. A routine may be understood to refer to a sequence of computer programs or instructions for performing a particular task.

The data analysis platform 1004 may include an analysis unit that determines operating status, based on at least one of a kinetic model, a parametric model, an analytical tool, and/or a related knowledge and/or best practice standard. The analysis unit may receive historical and/or current performance data from one or a plurality of plants to proactively predict one or more future actions to be performed. To predict various limits of a particular process and stay within the acceptable range of limits, the analysis unit may determine target operational parameters of a final product based on actual current and/or historical operational parameters. This evaluation by the analysis unit may be used to proactively predict future actions to be performed. In another example, the analysis unit may establish a boundary or threshold of an operating parameter of the plant based on at least one of an existing limit and an operation condition. In yet another example, the analysis unit may establish a relationship between at least two operational parameters related to a specific process for the operation of the plant. Finally in yet another example, one or more of the aforementioned examples may be performed with or without a combination of the other examples.

The plant process model predicts plant performance that is expected based upon the plant operation information. The plant process model results can be used to monitor the health of the plant and to determine whether any upset or poor measurement occurred. The plant process model is desirably generated by an iterative process that models at various plant constraints to determine the desired plant process model.

Using a web-based system for implementing the method of this disclosure may provide one or more benefits, such as improved plant performance due to an increased ability by plant operators to identify and capture opportunities, a sustained ability to bridge plant performance gaps, and/or an increased ability to leverage personnel expertise and improve training and development. Some of the methods disclosed herein allow for automated daily evaluation of process performance, thereby increasing the frequency of performance review with less time and effort required from plant operations staff.

Further, the analytics unit may be partially or fully automated. In one or more embodiments, the system is performed by a computer system, such as a third-party computer system, remote from the plant and/or the plant planning center. The system may receive signals and parameters via the communication network, and displays in real time related performance information on an interactive display device accessible to an operator or user. The web-based platform allows all users to work with the same information, thereby creating a collaborative environment for sharing best practices or for troubleshooting. The method further provides more accurate prediction and optimization results due to fully configured models. Routine automated evaluation of plant planning and operation models allows timely plant model tuning to reduce or eliminate gaps between plant models and the actual plant performance. Implementing the aforementioned methods using the web-based platform also allows for monitoring and updating multiple sites, thereby better enabling facility planners to propose realistic optimal targets.

FIGS. 12A-12B depict illustrative system flow diagrams in accordance with one or more embodiments described herein. As shown in FIG. 12A, in step 201, data collection platform 1002 may collect sensor data. In step 202, data collection platform 1002 may transmit sensor data to data analysis platform 1004. In step 203, data analysis platform 1004 may analyze data. In step 204, data analysis platform 1004 may send an alert to remote device 1054 and/or remote device 1056.

As shown in FIG. 12B, in step 205, data analysis platform 1004 may receive a command from remote device 1054 and/or remote device 1056. In some embodiments, the control platform 1006 may receive the command from remote device 1054 and/or remote device 1056. In step 206, data analysis platform 1004 may send a command to control platform 1006. In some embodiments, the command may be similar to the command received from remote device 1054 and/or remote device 1056. In some embodiments, data analysis platform 1004 may perform additional analysis based on the received command from remote device 1054 and/or remote device 1056 before sending a command to control platform 1006. In step 207, control platform 1006 may take corrective action. The corrective action may be based on the command received from data analysis platform 1004, remote device 1054, and/or remote device 1056. The corrective action may be related to one or more pieces of equipment (e.g., rotating equipment) associated with sensors that collected the sensor data in step 201.

FIG. 15 depicts an illustrative flow diagram in accordance with one or more embodiments described herein. The flow may be performed by one or more devices, which may be interconnected via one or more networks.

First, the one or more devices may collect 1402 sensor data. The sensor data may be from one or more sensors attached to one or more pieces of equipment (e.g., rotating equipment) in a plant. The sensor data may be locally collected and processed and/or may be locally collected and transmitted for processing.

After the sensor data is collected, the one or more devices may process 1404 the sensor data. The one or more devices may compare the data to past data from the one or more pieces of equipment, other pieces of equipment at a same plant, one or more pieces of equipment at a different plant, manufacturer recommendations or specifications, or the like.

After the sensor data is processed, the one or more devices may determine 1406 one or more recommendations based on the sensor data. The one or more recommendations may include recommendations of one or more actions to take based on the sensor data.

The one or more devices may send 1408 one or more alerts, which may include the determined recommendation. The one or more alerts may include information about the sensor data, about other data, or the like.

The one or more devices may receive 1410 a command to take an action (e.g., the recommended action, an action other than the recommended action, or no action). After receiving the command, the one or more devices may take 1412 the action. The action may, in some embodiments, include one or more corrective actions, which may cause one or more changes in the operation of the one or more pieces of equipment. The corrective action(s) may be taken automatically or after user confirmation, and/or the corrective action(s) may be taken without an accompanying alert being generated (and vice-versa).

FIG. 13 depicts an illustrative graphical user interface 1200 of an application that may be used for providing information received from one or more sensors or determined based on analyzing information received from one or more sensors, according to one or more embodiments described herein. The graphical user interface may be displayed as part of a smartphone application (e.g., running on a remote device, such as remote device 1054 or remote device 1056), a desktop application, a web application (e.g., that runs in a web browser), a web site, an application running on a plant computer, or the like.

The graphical user interface 1200 may include one or more visual representations of data (e.g., chart, graph, etc.) that shows information about a plant, a particular piece of equipment in a plant, or a process performed by a plant or a particular piece or combination of equipment in the plant. For example, a graph may show information about an operating condition, an efficiency, a production level, or the like. The graphical user interface 1200 may include a description of the equipment, the combination of equipment, or the plant to which the visual display of information pertains.

The graphical user interface 1200 may display the information for a particular time or period of time (e.g., the last five minutes, the last ten minutes, the last hour, the last two hours, the last 12 hours, the last 24 hours, etc.). The graphical user interface may be adjustable to show different ranges of time, automatically or based on user input.

The graphical user interface 1200 may include one or more buttons that allow a user to take one or more actions. For example, the graphical user interface may include a button (e.g., an “Actions” button) that, when pressed, shows one or more actions available to the user. The graphical user interface may include a button (e.g., a “Change View” button) that, when pressed, changes one or more views of one or more elements of the graphical user interface. The graphical user interface may include a button (e.g., a “Settings” button) that, when pressed, shows one or more settings of the application of which the graphical user interface is a part. The graphical user interface may include a button (e.g., a “Refresh Data” button) that, when pressed, refreshes data displayed by the graphical user interface. In some aspects, data displayed by the graphical user interface may be refreshed in real time, according to a preset schedule (e.g., every five seconds, every ten seconds, every minute, etc.), and/or in response to a refresh request received from a user. The graphical user interface may include a button (e.g., a “Send Data” button) that, when pressed, allows a user to send data to one or more other devices. For example, the user may be able to send data via email, SMS, text message, iMessage, FTP, cloud sharing, AirDrop, or via some other method. The user may be able to select one or more pieces of data, graphics, charts, graphs, elements of the display, or the like to share or send. The graphical user interface may include a button (e.g., an “Analyze Data” button) that, when pressed, causes one or more data analysis functions to be performed. In some aspects, the user may provide additional input about the desired data analysis, such as desired input, desired output, desired granularity, desired time to complete the data analysis, desired time of input data, or the like.

FIG. 14 depicts an illustrative graphical user interface 1300 of an application that may be used for providing alerts and/or receiving or generating commands for taking corrective action, in accordance with one or more embodiments described herein. The graphical user interface 1300 may include an alert with information about a current state of a piece of equipment (e.g., rotating equipment), a problem being experienced by a piece of equipment (e.g., rotating equipment), a problem with a plant, or the like.

The graphical user interface 1300 may include one or more buttons that, when pressed, cause one or more actions to be taken. For example, the graphical user interface 1300 may include a button that, when pressed, causes a flow rate to change. In another example, the graphical user interface 1300 may include a button that, when pressed, sends an alert to a contact (e.g., via a remote device), the alert including information similar to the information included in the alert provided via the graphical user interface. In a further example, the graphical user interface 1300 may include a button that, when pressed, shows one or more other actions that may be taken (e.g., additional corrective actions).

Reactor Loop Fouling Monitor

In one or more embodiments, one or more sensors may be used in conjunction with a centrifugal or axial compressor to detect potential fouling in the equipment and allow corrective actions to be taken. Fouling can occur in multiple locations on a dynamic compressor, and a frequent source of problems is fouling from buildup of nitrogen salts on the impeller blades, especially in a recycle gas compressor. If fouling can be detected at an early stage, corrective actions can be taken to address the fouling rather than shutting down the entire process. An automated technique for detecting and managing potential fouling can prevent unscheduled shutdowns of equipment.

A centrifugal compressor 310 as shown in FIG. 3 or an axial compressor 320 as shown in FIG. 4 may include one or more vibration sensors (A) 362 mounted on the compressor shaft 318, 328 and configured to measure vibrations in the shaft. The vibration sensor(s) 355 may be a proximity probe in one or more embodiments, and may be mounted adjacent to one of the bearings of the compressor 310, 320. In addition, a centrifugal or axial compressor 310, 320 as shown in FIGS. 3 and 4 may include one or more pressure sensors 356 and, optionally, one or more temperature sensors (T) configured to measure the pressure (P) and temperature (T), respectively, within the compressor 310 and/or at suction/discharge. In one or more embodiments, the compressor 310, 320 may include multiple pressure sensors 356 disposed after each of the impellers 313, 323, to permit measurement of the ΔP for each impeller 313, 323. Temperature sensors 355 may likewise be disposed adjacent each impeller 313, 323 to permit measurement of temperature for each impeller 313, 323. FIG. 9 illustrates this in connection with a centrifugal compressor 310, but it is understood that a similar configuration can be used with an axial compressor, with sensors 355, 356 following each impeller 323. Such sensors 355, 356 may be mounted in the stationary flow passage of the diffuser 316 following each impeller 313 of a centrifugal compressor in one or more embodiments. The sensors 355, 356 may be positioned at each diffuser 326 in an axial compressor 320. In another embodiment, the compressor 310 may additionally or alternately include pressure sensors 356 disposed within the inlet 311, 321 and outlet 317, 327, measuring P based on suction pressure and discharge pressure. Likewise, the temperature sensors 355 may be disposed at each end of the shaft 318, 328. One or both sensors 355, 356 may be disposed elsewhere in another embodiment. The sensors 355, 356, 362 are configured for continuous or substantially continuous detection, to permit collection of data dynamically during the operation of the compressor 310. This vibration and pressure data may include one or more of: maximum/minimum P, maximum/minimum vibration, and a continuous track of P and/or vibration throughout the operation (e.g., multiple measurement points per second). Increased vibrations and decreased output pressures are often indicative of fouling. Additional sensors may be positioned and configured for measuring parameters such as temperature. For example, temperature sensors could be located in similar positions as those described above for the pressure sensors 356. In other embodiments, the compressor 310 may not include pressure, temperature, and vibration sensors. For example, in one or more embodiments, the compressor 310 may include only pressure sensors 356 and temperature sensors 355, and in another embodiment, the compressor 310 may include only pressure sensors 356 and vibration sensors 362.

Sensors placed in and around the compressor can collect data relevant to potential fouling and transmit the data to a computer system, which can analyze the data to determine whether fouling exists, determine a degree of fouling, or predict a future occurrence and/or degree of fouling. In particular, the system may be configured to detect and/or predict fouling of the impeller blades for the compressor. In one or more embodiments, pressure and vibration data collected by the sensors 355, 356 may be used in this analysis. Additionally, the pressure and vibration data and analysis thereof may be based on the compressor as a whole or, in the case of a centrifugal compressor 310, may be based on each individual impeller 313. Analysis of data on a per-impeller basis can permit detection of whether fouling is limited to a particular impeller or impellers, so that corrective actions can be taken with respect to the particular impeller(s). The computer system may be configured to determine the extent of the vibration and pressure and/or the deviation of the vibration and pressure from standard operation.

Sensor information may be gathered by one or more sensors and transmitted to data collection platform. Data collection platform may transmit the collected sensor data to data analysis platform, which may be at a plant or remote from a plant (e.g., in the cloud). Data analysis platform may analyze the received sensor data. Data analysis platform may compare the sensor data to one or more rules to determine if any of the issues disclosed herein are occurring. For example, detecting of fouling of the impeller blades for a compressor may be indicated if in one or more conditions are met: (1) sensing of increased vibrations and/or (2) measuring of decreased output pressure. Furthermore, data analysis platform may compare current sensor data to past sensor data from the rotating equipment, from other rotating equipment at the same plant, from other rotating equipment at other plants, from a manufacturer, or the like. Data analysis platform may determine if one or more data characteristics of the sensor data match data that may indicate any of the issues disclosed herein.

Data analysis platform may further run process simulations to suggest changes to operating parameters of the rotating equipment and associated components to avoid or limit further damage by one or more of the issues disclosed herein. In some aspects, data analysis platform may communicate with one or more vendors regarding the results of the simulation, and receive recommendations from the vendor on how to change or optimize parameters (e.g., geometry) of the equipment. Data analysis platform may use this information to create or expand a searchable database.

In one or more embodiments, the P and vibration data may be compared to current or archived P and vibration data for the same compressor and/or other compressors, and the computer system can analyze the data to make useful determinations, such as whether the data indicates that potential fouling exists or will exist and/or making predictions regarding future operation. Corrective actions can be taken if deviations are determined to exist, and if such deviations are determined to be potentially indicative of fouling. The data comparison may be made across a variety of time frames, from a time frame of a few minutes or hours, to real-time continuous comparison, to historical comparison over a period of months or more, and may include absolute and proportional comparisons. As one example, fouling may be detected if the P and/or vibration of the compressor (or an individual impeller) is found to differ by a set percentage (e.g., +/−5% or 10%) from normal operation data. As another example, a deviation may be detected if the P and/or vibration of the compressor (or an individual impeller) exceeds a specific absolute threshold, either as a set threshold or as a set absolute difference from normal operation data. The data analysis may be done over one or more different time frames, and the deviation percentage or threshold may depend on the time frame for comparison. In one or more embodiments, the difference from normal operation data required to detect a deviation over a short time frame may be relatively large as compared to analysis of a longer time frame, which may require a relatively smaller difference to detect a deviation. For example, a gradual but consistent increase or decrease in pressure or vibration over a long time frame may be used in predicting long-term failure. For detecting fouling of impeller blades in particular, vibration data often follows a predictable increase over time when monitored continuously. But such vibration data may, in some embodiments, be more effective in predicting fouling when considered in conjunction with other data (e.g., pressure data).

The data comparison may also be made with respect to various different pieces of equipment. As one example, the data comparison may be limited to only the compressor (or impeller) in question. As another example, the data comparison may be made relative to other compressors (or impellers) in the system, and potentially to all other compressors (or impellers) of the same type within the system. As a further example, the data comparison may be made relative to historical data, including historical data for the same compressor (or impeller) or historical data for other compressors (or impellers). It is understood that data analysis does not necessarily need to be done for the purpose of detecting deviations, as described in greater detail below. For example, data comparison that indicates consistency with historical data for a compressor (or impeller) that exhibited fouling may be valuable in predicting whether and when a specific degree of fouling will occur.

The data used for the comparison may also depend on the stage of operation of the compressor. For example, start-up or shut-down of the machine may place increased stresses on the system and may require different data comparison. Different criteria (% or threshold) for deviation from normal operation may be applied during start-up or shut-down. Different comparison data may be used for analysis during start-up or shut-down as well, such as comparison to other start-up or shut-down data, rather than data from steady operation. As another example, different criteria and/or comparison data may be used during particular environmental conditions, such as based on a particular season or weather phenomenon.

In another example, the P and vibration data can be compared to previous trend or pattern P or vibration data from the same or other compressors (or impellers). In this example, the overall trend or pattern of the P and vibration data for a compressor (or impeller) may be analyzed to determine which previous data sets match most closely to the present data. Once one or more similar trends in P or vibration data are matched, the matched data sets may provide useful predictive value. For example, matched data may be valuable in predicting whether and when a specific degree of fouling will occur and/or which solutions may be effectively implemented to address an actual or potential fouling issue. In particular, corrective actions that were effective for treating issues for a past compressor or impeller with matching data may be used with some expectation of effectiveness.

Based on the analysis and comparison of data described herein, the computer system may take various actions, including corrective actions, notifications, predictions, etc. Corrective actions may include actions to correct a present fouling condition or prophylactic actions to address predicted future fouling conditions. The corrective actions taken may depend on a degree of fouling detected or predicted. For example, the system can recommend and/or initiate alternative processes to preserve the life of the compressor. Such alternative processes that can be implemented include running an online wash, adjusting processing parameters, feed type/quality, and/or upstream or downstream unit operations, slowing the impeller speed, adding (or putting online) a guard bed that pulls nitrogen out of the feed gas, using a feed gas with less nitrogen, or a combination of such actions, or other actions. In a centrifugal compressor, some alternative processes or other corrective actions may be taken on an individual impeller or impellers where possible. For example, as shown in FIG. 10, a centrifugal compressor 310 may be provided with individual injection ports 357 in front of each impeller 313 to permit a wash to be injected in advance of a desired impeller 313. An axial compressor 320 may be configured in a similar manner. The effect of a wash may decrease for each successive impeller 313 that the wash passes through, because the heat of compression can vaporize a portion of the wash fluid. Thus, the configuration of the ports 357 in FIG. 10 enables the wash to be injected at a downstream impeller or impellers 313, bypassing upstream impellers 313 that exhibit no fouling issues. For a naphtha wash, this permits a smaller amount of naphtha wash to be used, which is advantageous in improving conversion of the system. For a reformate wash, this can reduce reprocessing costs. This data collection also allows multiple parties within the supply chain to share data and more quickly recognize underperformance or troubleshoot reported field problems, thereby adjusting process operations earlier or discovering the causes of problems and/or solutions more quickly. Further, the system can predict a failure date for a compressor (or an impeller) so that corrective actions can be taken. Taking corrective actions as described herein to address a detected or predicted fouling condition may permit the compressor to maintain normal operation until an appropriate time for repair, such as when the system reaches a turn-around event or scheduled shutdown, in order to avoid unscheduled shutdowns.

The above analysis and/or actions may further incorporate additional data gathered by additional sensors in and around the compressor and/or elsewhere in the system in other embodiments. This additional data may influence determinations of potential problems and goals or may influence the corrective actions that are suggested and implemented. For example, temperature sensors may be used in addition to or instead of vibration sensors for detecting and predicting fouling in one or more embodiments. As another example, the ΔP data from a suction strainer or a CFE may be used to detect or predict fouling in those components.

Additionally, the principles for detection and prediction of fouling described herein may be applied to detection and prediction of fouling for other equipment within the plant or components of such equipment. Examples of other equipment that may be suitable for use with these principles include (without limitation) an FCC main air blower, an FCC wet gas compressor, an Oleflex main reactor effluent compressor, a hydrotreating recycle machine, compressors in MTO and olefin recovery applications, and a crude saturated gas compressor.

Aspects of the disclosure have been described in terms of illustrative embodiments thereof. Numerous other embodiments, modifications, and variations within the scope and spirit of the appended claims will occur to persons of ordinary skill in the art from a review of this disclosure. For example, one or more of the steps illustrated in the illustrative figures may be performed in other than the recited order, and one or more depicted steps may be optional in accordance with aspects of the disclosure.

Claims

1. A system for monitoring a compressor in a petrochemical plant or refinery for fouling, the system comprising: a reactor;a heater;a compressor comprising one or more injection ports and an impeller;

2. The system of claim 1, wherein the computer-readable memory of the data analysis platform stores executable instructions that, when executed, cause the data analysis platform to: analyze the sensor data associated with the compressor to determine the potential fouling within the compressor based on increased vibration associated with the compressor.

3. The system of claim 1, wherein the computer-readable memory of the data analysis platform stores executable instructions that, when executed, cause the data analysis platform to: analyze the sensor data associated with the compressor to determine the potential fouling within the compressor based on decreased pressure associated with the compressor.

4. The system of claim 1, wherein the computer-readable memory of the data analysis platform stores executable instructions that, when executed, cause the data analysis platform to: analyze the sensor data associated with the compressor to determine the potential fouling within the compressor based comparing current sensor data of the sensor data to past sensor data associated with the compressor.

5. The system of claim 1, comprising: a vibration sensor as part of the one or more sensors associated with the compressor,wherein the computer-readable memory of the data analysis platform stores executable instructions that, when executed, cause the data analysis platform to: receive, from the vibration sensor, vibration data associated with the compressor, the vibration data including multiple measurement points per second of: maximum vibration associated with the compressor, minimum vibration associated with the compressor, and a current vibration associated with the compressor; anduse the received vibration data associated with the compressor to determine potential fouling of the impeller.

6. One or more non-transitory computer-readable media storing executable instructions that, when executed, cause a data analysis platform of a system for monitoring a compressor in a petrochemical plant or refinery for fouling to: receive first pressure sensor data associated with a first pressure upstream of an impeller within the compressor and collected by a first pressure sensor located upstream of the impeller;receive second pressure sensor data associated with a second pressure downstream of the impeller within the compressor and collected by a second pressure sensor located downstream of the impeller, wherein the first pressure data and the second pressure data each include multiple measurement points per second of: maximum pressure associated with the compressor, minimum pressure associated with the compressor, and a current pressure associated with the compressor;compare the maximum pressure, the minimum pressure, and the current pressure of the first pressure data and the second pressure data to determine potential fouling of the impeller; andbased on determining the potential fouling within the compressor, send a command configured to cause an online wash via the one or more injection ports of the compressor to reduce the potential fouling within the compressor.

7. The one or more non-transitory computer-readable media of claim 6, storing executable instructions that, when executed, cause the data analysis platform to: receive vibration sensor data collected by a vibration sensor associated with the compressor;analyze the vibration sensor data associated with the compressor to determine the potential fouling within the compressor based on increased vibration associated with the compressor.

8. The one or more non-transitory computer-readable media of claim 6, storing executable instructions that, when executed, cause the data analysis platform to: analyze the first and second pressure sensor data associated with the compressor to determine the potential fouling within the compressor based on decreased pressure associated with the compressor.

9. The one or more non-transitory computer-readable media of claim 6, storing executable instructions that, when executed, cause the data analysis platform to: analyze the first and/or second pressure sensor data associated with the compressor to determine the potential fouling within the compressor based comparing current pressure sensor data to past pressure sensor data associated with the compressor.

10. The one or more non-transitory computer-readable media of claim 6, storing executable instructions that, when executed, cause the data analysis platform to: receive vibration data collected by a vibration sensor associated with the compressor, the vibration data including multiple measurement points per second of: maximum vibration associated with the compressor, minimum vibration associated with the compressor, and a current vibration associated with the compressor.

11. A method comprising: receiving, by a data analysis computing device, first pressure sensor data associated with a first pressure upstream of an impeller within a compressor and collected by a first pressure sensor located upstream of the impeller;receiving, by the data analysis computing device, second pressure sensor data associated with a second pressure downstream of the impeller and collected by a second pressure sensor located downstream of the impeller, wherein the first pressure data and the second pressure data each include multiple measurement points per second of: maximum pressure associated with the compressor, minimum pressure associated with the compressor, and a current pressure associated with the compressor;comparing, by the data analysis computing device, the maximum pressure, the minimum pressure, and the current pressure of the first pressure data and the second pressure data to determine potential fouling of the impeller; andbased on determining the potential fouling within the compressor, sending, by the data analysis computing device, a command configured to cause an online wash via the one or more injection ports of the compressor to reduce the potential fouling within the compressor.

12. The method of claim 11, comprising: receiving vibration sensor data collected by a vibration sensor associated with the compressor;analyzing, by the data analysis computing device, the vibration sensor data associated with the compressor to determine the potential fouling within the compressor based on increased vibration associated with the compressor and decreased pressure associated with the compressor.

13. The method of claim 11, comprising: analyzing, by the data analysis computing device, the first and/or second pressure sensor data associated with the compressor to determine the potential fouling within the compressor based comparing current pressure sensor data to past pressure sensor data associated with the compressor.

14. The method of claim 11, comprising: receiving, by the data analysis computing device, vibration data collected by a vibration sensor associated with the compressor, the vibration data including multiple measurement points per second of: maximum vibration associated with the compressor, minimum vibration associated with the compressor, and a current vibration associated with the compressor.

15. The system of claim 1, wherein the compressor comprises a plurality of impellers, and wherein the first pressure sensor is positioned upstream of a first impeller and is configured to collect first pressure data associated with a first pressure upstream of the first impeller, and the second pressure sensor is positioned downstream of the first impeller and upstream of a second impeller and is configured to collect second pressure data associated with a second pressure downstream of the first impeller, and a third pressure sensor is positioned downstream of the second impeller and is configured to collect third pressure data associated with a third pressure downstream of the second impeller; andwherein the computer-readable memory storing executable instructions, when executed, cause the data analysis platform to: receive the first pressure data associated with the first pressure upstream of the first impeller;receive the second pressure data associated with the second pressure downstream of the first impeller;receive the third pressure data associated with the third pressure downstream of the second impeller andcompare the first pressure data, the second pressure data, and the third pressure data to determine potential fouling of the impeller;based on determining the potential fouling within the compressor, send a command configured to cause an online wash via the one or more injection ports of the compressor to reduce the potential fouling within the compressor.

16. The one or more non-transitory computer-readable media of claim 6, storing executable instructions that, when executed, cause the data analysis platform to: wherein the first pressure sensor is positioned upstream of a first impeller and is configured to collect first pressure sensor data associated with a first pressure upstream of the first impeller, and the second pressure sensor is positioned downstream of the first impeller and upstream of a second impeller and is configured to collect second pressure sensor data associated with a second pressure downstream of the first impeller, and a third pressure sensor is positioned downstream of the second impeller and is configured to collect third pressure sensor data associated with a third pressure downstream of the second impeller; andwherein the computer-readable memory storing executable instructions, when executed, cause the data analysis platform to: receive the third pressure sensor data associated with the third pressure downstream of the second impeller andcompare the first pressure sensor data, the second pressure sensor data, and the third pressure sensor data to determine potential fouling of the impeller;based on determining the potential fouling within the compressor, send a command configured to cause an online wash via the one or more injection ports of the compressor to reduce the potential fouling within the compressor.

17. The method of claim 11: wherein the first pressure sensor is positioned upstream of a first impeller within the compressor and is configured to collect first pressure sensor data associated with a first pressure upstream of the first impeller, and the second pressure sensor is positioned downstream of the first impeller and upstream of a second impeller within the compressor and is configured to collect second pressure sensor data associated with a second pressure downstream of the first impeller, and a third pressure sensor is positioned downstream of the second impeller and is configured to collect third pressure sensor data associated with a third pressure downstream of the second impeller;the method further comprising receiving the third pressure sensor data associated with the third pressure downstream of the second impeller andwherein the act of comparing comprises comparing the first pressure sensor data, the second pressure sensor data, and the third pressure sensor data to determine potential fouling of the impeller.