METHODS AND SYSTEMS FOR DETECTING CATHODIC PROTECTION INTERFERENCE

Abstract

A method includes, using a structure monitoring system, obtaining a source reading of a first cathodic protection system. The method includes, using a structure management system, determining whether the source reading is less than a source threshold; obtaining an operation duration value, if the source reading is less than the source threshold; and determining whether the operation duration value is greater than an operation duration threshold. The method includes obtaining a potential difference, if the operation duration value is greater than an operation threshold; determining whether the potential difference is greater than or equal to a difference threshold; obtaining a surface area, if the potential difference is greater than or equal the difference threshold; and determining whether the surface area is greater than an area threshold. The method includes obtaining a severity probability, if the surface area is greater than the area threshold.

Claims

1. A method of detecting cathodic protection interference for a structure, the method comprising: using a structure monitoring system operatively connected to a first cathodic protection system and the structure, wherein the structure monitoring system is configured to monitor a first current flow from the first cathodic protection system through the structure to a ground connection, wherein the first cathodic protection system comprises a source configured to control the first current flow; and obtaining a source reading regarding the first current flow of the first cathodic protection system; and using a structure management system operatively connected to the structure and the first cathodic protection system, wherein the structure management system is configured to control operation of the structure; determining whether the source reading is less than a source threshold; obtaining an operation duration value, if the source reading is less than the source threshold; determining whether the operation duration value is greater than an operation duration threshold; obtaining a potential difference, if the operation duration value is greater than an operation threshold; determining whether the potential difference is greater than or equal to a difference threshold; obtaining a surface area, if the potential difference is greater than or equal to the difference threshold; determining whether the surface area is greater than an area threshold; and obtaining a severity probability, if the surface area is greater than the area threshold.

2. The method of claim 1, wherein the structure monitoring system comprises: an ammeter configured to obtain the source reading; and a first processor configured to transmit the source reading to the structure management system.

3. The method of claim 1, wherein the source comprises a direct current source.

4. The method of claim 1, wherein the structure is a first flowline configured to transport a fluid.

5. The method of claim 4, wherein the first flowline is buried below a surface, wherein a second flowline comprises a second cathodic protection system, and wherein the cathodic protection interference of the first flowline is caused by stray currents from the second flowline.

6. The method of claim 5, wherein the potential difference is an electrical continuity potential difference between the first flowline and the second flowline.

7. The method of claim 1, wherein the first cathodic protection system is a cathodic protection system.

8. The method of claim 1 further comprising: initiating, by the structure management system, an alarm if the severity probability is greater than a severity threshold; and performing maintenance on the structure to prevent structural failure of the structure.

9. The method of claim 1 further comprising: transmitting, by the structure management system, severity probability data in a severity assessment report to a user device, wherein the user device is coupled to the first cathodic protection system, wherein the user device is configured to obtain a user selection within a user interface regarding an alarm and a maintenance operation of the structure.

10. The method of claim 4, wherein the first cathodic protection system comprises a second processor configured to control the first current flow, wherein the first cathodic protection system is coupled to a gas plant and a gathering system configured to gather gas from a plurality of gas wells and transport the gas via the first flowline.

11. A system of detecting cathodic protection interference for a structure, the system comprising: a structure monitoring system is operatively connected to a first cathodic protection system and the structure, wherein the structure monitoring system is configured to monitor a first current flow from the first cathodic protection system through the structure to a ground connection, wherein the first cathodic protection system comprises a source and is configured to control the first current flow from the source, and wherein the structure monitoring system is configured to obtain a source reading regarding the first current flow of the first cathodic protection system; and a structure management system is operatively connected to the structure and the first cathodic protection system, wherein the structure management system is configured to: control operation of the structure; determine whether the source reading is less than a source threshold; obtain an operation duration value, if the source reading is less than the source threshold; determine whether the operation duration value is greater than an operation duration threshold; obtain a potential difference, if the operation duration value is greater than an operation threshold; determine whether the potential difference is greater than or equal to a difference threshold; obtain a surface area, if the potential difference is greater than or equal to the difference threshold; determine whether the surface area is greater than an area threshold; and obtain a severity probability, if the surface area is greater than the area threshold.

12. The system of claim 11, wherein the structure monitoring system comprises: an ammeter configured to obtain the source reading; and a first processor configured to transmit the source reading to the structure management system.

13. The system of claim 11, wherein the source comprises a direct current source.

14. The system of claim 11, wherein the structure is a first flowline configured to transport a fluid.

15. The system of claim 14, wherein the first flowline is buried below a surface, wherein a second flowline comprises a second cathodic protection system, and wherein the cathodic protection interference of the first flowline is caused by stray currents from the second flowline.

16. The system of claim 15, wherein the potential difference is an electrical continuity potential difference between the first flowline and the second flowline.

17. The system of claim 11, wherein the first cathodic protection system is a cathodic protection system.

18. The system of claim 11, wherein the structure management system is configured to: initiate an alarm if the severity probability is greater than a severity threshold; and perform maintenance on the structure to prevent structural failure of the structure.

19. The system of claim 11 further comprising: transmitting, by the structure management system, severity probability data in a severity assessment report to a user device, wherein the user device is coupled to the first cathodic protection system, wherein the user device is configured to obtain a user selection within a user interface regarding an alarm and a maintenance operation of the structure.

20. The system of claim 15, wherein the first cathodic protection system comprises a second processor configured to control the first current flow, wherein the first cathodic protection system is coupled to a gas plant and a gathering system configured to gather gas from a plurality of gas wells and transport the gas via the first flowline.

Description

BRIEF DESCRIPTION OF DRAWINGS

[0006] Specific embodiments of the disclosed technology will now be described in detail with reference to the accompanying figures. Like elements in the various figures are denoted by like reference numerals for consistency.

[0007] FIG. 1 shows a schematic of a system of detecting cathodic protection interference in accordance with one or more embodiments.

[0008] FIG. 2 illustrates a cathodic protection system in accordance with one or more embodiments.

[0009] FIG. 3 illustrates a plurality of flowlines and cathodic protection interference in accordance with one or more embodiments.

[0010] FIG. 4 shows a flowchart for a method in accordance with one or more embodiments.

[0011] FIG. 5 depicts a computer in accordance with one or more embodiments.

DETAILED DESCRIPTION

[0012] In the following detailed description of embodiments of the disclosure, numerous specific details are set forth in order to provide a more thorough understanding of the disclosure. However, it will be apparent to one of ordinary skill in the art that the disclosure may be practiced without these specific details. In other instances, well-known features have not been described in detail to avoid unnecessarily complicating the description.

[0013] Throughout the application, ordinal numbers (e.g., first, second, third, etc.) may be used as an adjective for an element (i.e., any noun in the application). The use of ordinal numbers is not to imply or create any particular ordering of the elements nor to limit any element to being only a single element unless expressly disclosed, such as using the terms before, after, single, and other such terminology. Rather, the use of ordinal numbers is to distinguish between the elements. By way of an example, a first element is distinct from a second element, and the first element may encompass more than one element and succeed (or precede) the second element in an ordering of elements.

[0014] It is to be understood that the singular forms a, an, and the include plural referents unless the context clearly dictates otherwise.

[0015] Terms such as approximately, substantially, etc., mean that the recited characteristic, parameter, or value need not be achieved exactly, but that deviations or variations, including for example, tolerances, measurement error, measurement accuracy limitations and other factors known to those of skill in the art, may occur in amounts that do not preclude the effect the characteristic was intended to provide.

[0016] It is to be understood that one or more of the steps shown in the flowchart may be omitted, repeated, and/or performed in a different order than the order shown. Accordingly, the scope disclosed herein should not be considered limited to the specific arrangement of steps shown in the flowchart.

[0017] Although multiple dependent claims are not introduced, it would be apparent to one of ordinary skill that the subject matter of the dependent claims of one or more embodiments may be combined with other dependent claims.

[0018] In the following description of FIGS. 1-5, any component described with regard to a figure, in various embodiments disclosed herein, may be equivalent to one or more like-named components described with regard to any other figure. For brevity, descriptions of these components will not be repeated with regard to each figure. Thus, each and every embodiment of the components of each figure is incorporated by reference and assumed to be optionally present within every other figure having one or more like-named components. Additionally, in accordance with various embodiments disclosed herein, any description of the components of a figure is to be interpreted as an optional embodiment which may be implemented in addition to, in conjunction with, or in place of the embodiments described with regard to a corresponding like-named component in any other figure.

[0019] In general, embodiments of the disclosure include methods and systems for detection of cathodic protection interference. In some embodiments, for example, various structures such as flowlines are proactively evaluated for cathodic protection interference of the various structures while on-stream (i.e., being used in gas production and/or distribution). More specifically, some embodiments determine risk of corrosion if cathodic protection interference is detected of a particular structure such as flowlines using flowline data, such as operational parameters of gas plants, structure dimensions, and protection system data. Using the protection system data, a severity assessment may be performed on the corresponding structure. In some embodiments, severity probabilities may be obtained. The severity assessment and severity probabilities may be used to determine whether to perform a maintenance operation on the structure, as well as which type of maintenance operation to perform. Using the severity assessment data, a severity assessment report (142) and a ranking report (136) may be performed on the structure within the production system to prioritize maintenance operations. While embodiments have been described with reference to cathodic interference, those skilled in the art will recognize that these techniques may be applied more generally to corrosion protection of other kinds as well.

[0020] FIG. 1 shows a schematic diagram of a system for detection of cathodic protection interference (hereafter detection system) (10) in accordance with one or more embodiments. As shown in FIG. 1, a gas production system (100) may include a gas well (101), a gas plant (105), and a gathering system (103). The detection system (10) includes a first structure (117) operably connected to a first cathodic protection system (120) having a ground connection. The first structure (e.g., a flowline) (117) may be buried beneath earth's surface (surface). The first structure (117) may be constructed of any material such as metal that is suitable for transporting fluid. The first structure (117) may include, but is not limited to, flowlines and storage facilities.

[0021] Each component of the gas production system (100) may be operably connected by one or more structures, such as flowlines, configured to transport a fluid such as water, oil, gas, and the like. Each flowline may include one or more flowline components such as pipe segments. In some embodiments, gas flowline data (130) may be collected over the gas production system (100) and/or the structures. Likewise, the gas production system (100) may also determine severity assessment data (132) regarding one or more structures such as flowlines operably connected to the gas production system (100). The detection system (10) may include a structure management system (110).

[0022] The structure management system (110) is operatively connected to the first structure (117) and the first cathodic protection system (120). The structure management system (110) is configured to control operation of the first structure (117). In one or more embodiments, the structure management system (110) may be a gas plant server. In one or more embodiments, gas flowline data (130) are collected over the gas production system (100). Gas flowline data (130) may include, but not limited to production flow rates, and production fluid composition. While FIG. 1 may show only one structure and cathodic protection system, the invention may employ more than one structure and cathodic protection system.

[0023] Furthermore, the gas well (101) may include a well system (102) located in a well environment that includes a hydrocarbon reservoir (reservoir) located in a hydrocarbon-bearing formation. The hydrocarbon-bearing formation may include a porous or fractured rock formation that resides underground, beneath the surface. In the case of the well system (102) being a hydrocarbon well, the reservoir may include a portion of the hydrocarbon-bearing formation. The hydrocarbon-bearing formation and the reservoir may include different layers of rock having varying characteristics, such as varying degrees of permeability, porosity, and resistivity. In the case of the well system (102) being operated as a production well, the well system (102) may facilitate the extraction of hydrocarbons (or production) from the reservoir.

[0024] In some embodiments, the well system (102) includes a wellbore, a well sub-surface system, a well surface system, and a well control system. The wellbore may include a bored hole that extends from the surface into a target zone of the hydrocarbon-bearing formation, such as the reservoir. The wellbore may facilitate the circulation of drilling fluids during drilling operations, the flow of hydrocarbon production (production) (e.g., oil and gas) from the reservoir to the surface during production operations, the injection of substances (e.g., water) into the hydrocarbon-bearing formation or the reservoir during injection operations, or the communication of monitoring devices (e.g., logging tools) into the hydrocarbon-bearing formation or the reservoir during monitoring operations (e.g., during in situ logging operations).

[0025] A control system in a well system (102) may control various operations of the well system (102), such as well production operations, well completion operations, well maintenance operations, and reservoir monitoring, assessment, and development operations. In some embodiments, the control system includes a computer system that is the same as or similar to that of a computer (502) described below in FIG. 5 and the accompanying description. While FIG. 1 may show only one gas well, the gas production system (100) may employ more than one gas well.

[0026] In some embodiments, one or more gas wells are operably coupled to the gathering system (103) and the gas plant (105). The gathering system (103) may include various hardware arrangements and flowline components that connect gas flowlines from several gas wells into a single gathering line. For example, the gathering system (103) may include flowline networks, headers, pumping facilities, separators, emulsion treaters, compressors, dehydrators, tanks, valves, regulators, and/or associated equipment. In particular, a remote header may have production valves and testing valves to control a mixed stream for a flowline of a respective gas well. Thus, the gathering system (103) may direct various hydrocarbon fluids to a processing or testing facility, such as the gas plant (105).

[0027] In some embodiments, the gathering system (103) manages individual fluid ratios (e.g., a particular gas-to-water ratio or condensate-to-gas ratio) as well as supply rates of oil, gas, and water. For example, the gathering system (103) may assign a particular production value or ratio value to a particular gas well by opening and closing selected valves among the remote headers and using individual metering equipment or separators. Furthermore, the gathering system (103) may be a radial system or a trunk line system. A radial system may bring various flowlines to a single central header. In contrast, a trunk-line system may use several remote headers to collect oil and gas from fields that cover a large geographic area. Once collected, the gathering system (103) may transport and control the flow of oil or gas to a storage facility, a gas processing plant, or a shipping point.

[0028] Keeping with FIG. 1, gas may be transported from one or more gas wells to one or more gas plants (105), such as through one or more fluid streams (e.g., single composition fluid stream or mixed fluid stream) (185). More specifically, the gas plant (105) may refer to various types of industrial plants such as a gas processing plant, a gas cycling plant, or a compressor plant. A gas processing plant (also referred to as a natural gas processing plant) may be a facility that processes natural gas to recover natural gas liquids (e.g., condensate, natural gasoline, and liquefied petroleum gas) and sometimes other substances such as sulfur. A gas cycling plant may refer to an oilfield installation coupled to a gas-condensate reservoir. In particular, a gas cycling plant may extract various liquids from natural gas. Consequently, the remaining dry gas may be compressed prior to returning to a producing formation (e.g., to maintain reservoir pressure). Moreover, various components of natural gas may be classified according to their vapor pressures, such as low-pressure liquid (i.e., condensate), intermediate pressure liquid (i.e., natural gasoline), and high-pressure liquid (i.e., liquefied petroleum gas). Examples of natural gas liquids include propane, butane, pentane, hexane, and heptane. With respect to compressor plants, a compressor plant may be a facility that includes multiple compressors, auxiliary treatment equipment, and pipeline installations for pumping natural gas over long distances. A compressor station may also repressurize gas in large gas pipelines or link offshore gas fields to their final terminals.

[0029] Keeping with gas plants, the gas plant (105) may include water processing equipment that includes hardware and/or software for extracting, treating, and/or disposing of water associated with gas processing. More specifically, the gas plant (105) may extract produced water during the separation of oil or gas from a mixed fluid stream (185) acquired from the gas well (101). This produced water may be a kind of brackish and saline water brought to the surface from underground formations.

[0030] In particular, oil and gas reservoirs may have water in addition to hydrocarbons in various zones underneath the hydrocarbons, and even in the same zone as the oil and gas. However, most produced water is of very poor quality and may include high levels of natural salts and minerals that have dissociated from geological formations in the target reservoir. Likewise, produced water may also acquire dissolved constituents from fracturing fluids (e.g., substances added to the fracturing fluid to help prevent pipe corrosion, minimize friction, and aid the fracking process). However, through various water treatments, produced water may be reused in one or more gas wells (e.g., through waterflooding where produced water is injected into the reservoirs). By injecting produced water into an injection well, the injected water may force oil and gas to one or more production wells.

[0031] Keeping with produced water, the gas plant (105) may use various treatment technologies in order to reuse or dispose of produced water, such as conventional treatments and advanced treatments. For example, conventional treatments may include flocculation, coagulation, sedimentation, filtration, and lime softening water treatment processes. Thus, conventional treatment processes may include functionality for removing suspended solids, oil and grease, hardness compounds, and other insoluble water components.

[0032] With advanced treatment technologies, water processing equipment may include functionality for performing reverse osmosis membranes, thermal distillation, evaporation and/or crystallization processes. These advanced treatment technologies may treat dissolved solids, such as chlorides, salts, barium, strontium, and sometimes dissolved radionuclides. In some embodiments, produced water is sent to a wastewater treatment plant that is equipped to remove barium and strontium (e.g., using sulfate precipitation). Outside of treatments for reusing produced water, water processing equipment may dispose of produced water using various water management options. For example, produced water may be disposed of in saltwater wells. Likewise, produced water may also be eliminated through a deep well injection.

[0033] In some embodiments, the gas plant (105) may include one or more storage facilities, and one or more production control systems (107). For example, different forms of gas may be stored in various storage facilities that include surface containers as well as various underground reservoirs, such as depleted gas reservoirs, aquifer reservoirs and salt cavern reservoirs. With respect to production control systems, a production control system (107) may include hardware and/or software that monitors and/or operates equipment, such as at a gas well or in a gas plant. Examples of production control systems may include one or more of the following: an emergency shut down (ESD) system, a safety control system, a video management system (VMS), process analyzers, other industrial systems, etc. In particular, a control system may include a programmable logic controller that may control valve states, fluid levels, pipe pressures, warning alarms, pressure releases and/or various hardware components for implementing a gas flowline. Thus, a programmable logic controller may be a ruggedized computer system with functionality to withstand vibrations, extreme temperatures, wet conditions, and/or dusty conditions, such as those around a gas plant, gas well, and/or a gathering system.

[0034] With respect to production control systems, the production control system (107) may be a computer system for managing various processes at a facility using multiple control loops. As such, the production control system (107) may include various autonomous controllers (such as remote terminal units (RTUs)) positioned at different locations throughout the facility to manage operations and monitor processes. Likewise, the production control system (107) may include no single centralized computer for managing control loops and other operations. On the other hand, a supervisory control and data acquisition system may include a control system that includes functionality for enabling monitoring and issuing of process commands through local control at a facility as well as remote control outside the facility. With respect to an RTU, an RTU may include hardware and/or software, such as a microprocessor, which connects sensors and/or actuators using network connections to perform various processes in the automation system.

[0035] Keeping with production control systems, the production control system (107) may be operably coupled to facility equipment. Facility equipment may include various machinery such as one or more hardware components, such as pipe components, which may be monitored using one or more sensors. Examples of hardware components coupled to a control system may include crude oil preheaters, heat exchangers, pumps, valves, compressors, loading racks, and storage tanks among various other types of hardware components. Hardware components may also include various network elements or control elements for implementing control systems, such as switches, routers, hubs, programmable logic controllers, remote terminal units, user equipment, or any other technical components for performing specialized processes. Examples of sensors may include pressure sensors, flow rate sensors, temperature sensors, torque sensors, rotary switches, weight sensors, position sensors, microswitches, hydrophones, accelerometers, etc. Production control systems, user devices, and network elements may be computer systems similar to the computer system (502) described in FIG. 5 and the accompanying description.

[0036] In some embodiments, the detection system (10) may include a structure monitoring system (115) that includes hardware and/or software for collecting data in real-time from various gas wells, gas plants, sensors coupled to hardware equipment and structures such as flowlines, user devices, and other systems in the gas production system (100). For example, the structure monitoring system (115) may be one or more plant servers with functionality for obtaining data throughout the gas production system (100), such as gas flowline data (130). For example, gas flowline data (130) may include operating upstream and downstream sensor data for various structures such as flowlines (e.g., electrical continuity of flowlines, pressure data, temperature measurements, and gas flow rates), protection system updates, and maintenance operation status reports from various production information (PI) systems, such as production control systems located throughout the gas production system (100). Gas flowline data (130) may also include gas chemical composition data, such as condensate-gas ratio (CGR) data, and water sampling data (e.g., levels of Chloride and Strontium concentrations). Likewise, gas flowline data (130) may also include material and design specifications for various flowline components that form gas flowlines, such as pipe component geometry and pipe component compositions.

[0037] The structure monitoring system (115) may also collect various gas production parameters regarding gas plant operations, gas well operations, and remote header information regarding the gathering system (103) coupled to the gas wells. The structure monitoring system (115) may be operatively connected to the first structure (117) and the first cathodic protection system (120) either by, but not limited to, cable, wire and/or wirelessly. The structure monitoring system (115) may be configured to monitor a first current flow from the first cathodic protection system (120) through the first structure (117) to the ground connection. The structure monitoring system (115) is configured to obtain a source reading regarding the first current flow (195) of the first cathodic protection system (120).

[0038] The structure monitoring system (115) may include hardware/software to monitor the first current flow from the first cathodic protection system (120) and to obtain the source reading. In some embodiments, the structure monitoring system (115) may include an ammeter configured to obtain the source reading. The structure monitoring system (115) may also include a first processor configured to transmit the source reading to the structure management system (110). In some embodiments, the first cathodic protection system (120) may be a cathodic protection system. In some embodiments, the cathodic protection system may include a sacrificial anode cathodic protection system or an impressed current cathodic protection system.

[0039] In some embodiments, the structure monitoring system (115) includes functionality for determining and/or implementing one or more maintenance operations based on severity assessment data (132), protection system data (134), and/or maintenance data (140). A maintenance operation (160) may include replacing a particular structure such as a flowline component that is part of a gas production system (100) based on the flowline component failing to satisfy a predetermined criterion (e.g., pipe thickness falling below an integrity threshold). Likewise, the maintenance operation (160) may also include adjusting gas production operations to manage corrosion levels in the corresponding flowline component such as adjusting output of the source or installing resistance bond.

[0040] In some embodiments, the structure management system (110) may automatically prioritize various maintenance procedures among different flowline components instantaneously based on desired gas production targets, future plant operations, and/or the corrosion states of various gas flowlines. In some embodiments, the structure management system (110) may set various threshold (e.g., source threshold, operation duration threshold, difference threshold, area threshold) for determining cathodic protection interference. The various thresholds may be manually input by a user using a user device or may be determined using machine learning algorithms. In some embodiments, the structure monitoring system (115) may be operably connected to an alarm (125). The alarm (125) may include optical, auditory, and wireless signal capabilities.

[0041] In some embodiments, a user device (150) may communicate with the structure management system (110) to present severity assessment reports to a particular user. Based on the severity assessment reports, the user device (150) may also manage various commands for performing one or more maintenance operations based on one or more user selections. The user device (150) may be a personal computer, a handheld computer device such as a smartphone or personal digital assistant, or a human machine interface (HMI). For example, a user may interact with a user interface (e.g., graphical user interface presented on a display device) (151) to inquire regarding corrosion states and integrity levels in one or more structures of the gas production system (100). Through user selections or automation, the structure monitoring system (115) may identify flowline components that fail integrity criteria and implement maintenance operations accordingly. As such, the structure monitoring system (115) may provide agility and flexibility in determining the corrosion states of various gas flowlines as well as implement remediation operations to prevent or alleviate future corrosion to various gas flowlines. The user device (150) may be configured to receive wireless signals such as any alarm signals transmitted from the alarm (125).

[0042] In some embodiments, various assessments of one or more structures such as flowline components is generated by the structure management system (110) upon obtaining a request (e.g., request for severity assessment report (142) and/or ranking report (136)) from the user device (150) and using various predetermined criteria (e.g., integrity criteria, severity probabilities, and/or ranking criteria) and input data (e.g., gas flowline data (130), severity assessment data (132), and/or protection system data (134)). The request may be a network message transmitted between the user device (150) and the structure monitoring system (115) that identifies a particular flowline component, gas production system (100), or portion of a gas production system (100) for a corrosion analysis.

[0043] In some embodiments, the user device (150) is configured to obtain a user selection within the user interface (151) regarding the alarm (125) and the maintenance operation (160) of the structure. In some embodiments, the structure monitoring system (115) includes functionality for transmitting commands to one or more production control systems to implement a particular maintenance operation. For example, the structure monitoring system (115) may transmit a network message over a machine-to-machine protocol to the production control system (107) in the gas plant (105). A command may be transmitted periodically, based on a user input, or automatically based on changes in gas flowline data (130).

[0044] In some embodiments, the structure management system (110) is configured to obtain a severity probability. The severity probability may be obtained by multiplying a surface area by a constant, (e.g., K1, K2, K2 for a high, medium, and low probability, respectively). The severity probability may be related to the probability of structural failure due to corrosion. In some embodiments, the structure management system (110) may be configured to transmit the severity probabilities in the severity assessment report (142) to the user device (150). In some embodiments, the structure management system (110) may be configured to initiate the alarm (125) if the severity probability is greater than various thresholds (e.g., an area threshold, and/or integrity threshold). In some embodiments, maintenance may be performed on the structure, for example, to prevent structural failure of the structure.

[0045] Returning to FIG. 1, the structure management system (110) may include hardware and/or software with functionality for generating and/or updating one or more machine-learning models to determine predicted severity assessment (e.g., by classifying a flowline component as passing or failing one or more integrity criteria). Examples of machine-learning models may include random forest models and artificial neural networks, such as convolutional neural networks, deep neural networks, and recurrent neural networks. Machine-learning models may also include support vector machines, decision trees, inductive learning models, deductive learning models, supervised learning models, unsupervised learning models, reinforcement learning models, etc. In a deep neural network, for example, a layer of neurons may be trained on a predetermined list of features based on the previous network layer's output. Thus, as data progresses through the deep neural network, more complex features may be identified within the data by neurons in later layers. Likewise, a U-net model or other type of convolutional neural network model may include various convolutional layers, pooling layers, fully connected layers, and/or normalization layers to produce a particular type of output. Thus, convolution and pooling functions may be the activation functions within a convolutional neural network. In some embodiments, two or more different types of machine-learning models are integrated into a single machine-learning architecture (e.g., a machine-learning model may include K-nearest neighbor (k-NN) models and neural networks). In some embodiments, a reservoir simulator may generate augmented data or synthetic data to produce a large amount of interpreted data for training a particular model.

[0046] While FIG. 1 shows various configurations of components, other configurations may be used without departing from the scope of the disclosure. For example, various components in FIG. 1 may be combined to create a single component. As another example, the functionality performed by a single component may be performed by two or more components.

[0047] FIG. 2 illustrates a structure (e.g., the first structure (117)) located beneath the surface in accordance with one or more embodiments. In some embodiments, the structure is located in a subsurface environment that may include a layer of soil (soil) beneath the surface. The soil may have a plurality of soil horizons (250, 251) with varying characteristics such as, but is not limited to, soil composition and water saturation. In some embodiments, the soil horizons may include an electrolyte layer (251) having oxygen gas, water, and electrolytes, for example, dissolved salts such as sodium, potassium, and the like.

[0048] The electrolyte layer may include an upper boundary (252). The electrolyte layer may facilitate corrosion due to the presence of oxygen gas, water, and electrolytes. A structure includes an outer surface. The outer surface of the structure may develop one or more cathodic areas and one or more anodic areas due to electric potentials between areas of the structure due to interaction with the electrolyte layer. Anodic areas may be susceptible to corrosion due to the susceptibility of the anodic areas to be oxidized. Cathodic areas may be less susceptible to corrosion relative to the anodic areas. The structure management system (110) may be configured to obtain a surface area of the outer surface. In some embodiments, the surface area may be determined from calculating the surface area, at least in part, from dimensions of the structure. In some embodiments, the surface area may be determined from inputs from a user using the user device (150).

[0049] FIG. 2 further illustrates a cathodic protection system (e.g., the first cathodic protection system (120)). In some embodiments, the cathodic protection system may include functionality to provide cathodic protection to one or more structures. The cathodic protection system may include a source (200) and an anode (230). The source (200) is operably connected to the structure and the anode (230). The source (200) is configured to provide an electrical current flow (e.g., the first current flow) to the structure and the anode (230). The cathodic protection system may comprise a second processor configured to control the electric current flow from the source (200). The source (200) may be a direct current (DC) source, or an alternating current (AC) source.

[0050] In some embodiments, the cathodic protection system may include a transformer and/or an AC to DC converter if the source (200) is an AC source. The transformer is configured to step-down from a relatively high voltage into a relatively low voltage suitable for cathodic protection (e.g., 24 volts). In some embodiments, the cathodic protection system may include a transformer rectifier unit to step-down the voltage and convert an AC source to DC. The anode (230) may be constructed from any suitable material for conducting an electrical current, for example, a metal or metal alloy. In some embodiments, the anode (230) may be constructed from an inert metal (e.g., titanium). The inert metal may be configured to resist decay in the electrolyte layer.

[0051] In some embodiments, the negative terminal of the source (200) is operably connected to the structure, and the positive terminal is operable connected to the anode (230). Electric current may flow through the electrolyte layer by flow of electrons from the anode (230) to the structure. The structure may shift in a more negative electric potential direction. Anodic areas of the outer surface may be transformed into cathodic areas and may become less susceptible to corrosion. The source (200) determines current strength and amount of cathodic protection. The cathodic protection system may also include a ground connection. The ground connection may be constructed of any material suitable for carrying the electric current flow such as metal. The ground connection may be of any design suitable for grounding an electric circuit. The ground connection may be ground to the earth for completing the current flow path of the cathodic protection system.

[0052] The cathodic protection system may include hardware/software for determining protection system data (e.g., soil electric potential data, electric potential data, anode voltage output, and/or anode-to-structure flow) (134). The cathodic protection system may include voltmeters for determining, but not limited to, soil electric potential data, anode voltage output and/or anode-to-pipe flow. The cathodic protection system may include ohmmeters for determining structure continuity.

[0053] The cathodic protection system may include a protection control system to maintain an electric current suitable for providing cathodic protection to a structure. The protection control system may include hardware and/or software for collecting protection system data (e.g., electric current strength data, and/or electric potential data) (134) in real-time from various structures, sensors coupled to hardware equipment and structures such as flowlines, user devices, and other systems (e.g., production control systems, and/or well systems) for maintaining cathodic protection of one or more structures within the gas production system (100). In some embodiments, the cathodic protection system may be coupled to the gas plant (105) and the gathering system (103).

[0054] In accordance with one or more embodiments, the detection system (10) may comprise a second structure (317), such as a flowline, and a second cathodic protection system (320) as shown in FIG. 3. The second structure (317) may be arbitrarily positioned relative to the first structure (117). The second cathodic protection system (320), having a second source (300) and second anode (330), is operatively connected to the second structure (317). The second cathodic protection system (320) is configured to control a second electrical current flow (395) through the second structure (317). The second structure (317) may emit stray currents (350) as illustrated in FIG. 3. Stray currents (350) may be any electrical current flow that is not following the intended current flow path, for example, current flow from the second structure (317) to the first structure (117). The stray currents (350) from the second structure (317) may interfere with the first cathodic protection system (120) causing cathodic protection interference of the first structure (117). The cathodic protection interference may decrease effectiveness of the cathodic protection of the first structure (117).

[0055] In accordance with one or more embodiments, the first cathodic protection system (120) may be configured to determine electric potential data (138) such as, but not limited to, potential differences, soil potentials, and/or structure potentials. A potential difference may include an electrical continuity potential difference, and/or soil-structure potential difference. The electrical continuity potential difference may be determined by subtracting a second electrical potential of an electrically bonded line; for example, the second structure (317), from a first electric potential of the first structure (117).

[0056] FIG. 4 depicts a flowchart in accordance with one or more embodiments describing a method for detection of cathodic protection (hereafter detection method) (400). In some embodiments, the detection method (400) may use current flow to predict cathodic protection interference between different structures. Although the steps in flowchart using the detection method (400) are shown in sequential order, it will be apparent to one of ordinary skill in the art that some steps may be conducted in parallel, in a different order than shown, or may be omitted without departing form the scope of the invention.

[0057] In step (402), the detection method (400) may include obtaining a source reading. The source reading may be obtained by the structure monitoring system (115). The structure monitoring system (115) may include a device configured to measure electric current such as an ammeter. In some embodiments, the ammeter may be coupled in series with the source (200) and the structure.

[0058] In step (403), the detection method (400) may include determining if the source reading is less than a source threshold in accordance with one or more embodiments. The source threshold may be a numerical constant or a range (e.g., 0-0.5 Ampere). The source threshold may be entered by a user using the user interface (151) of the structure management system (110) and/or the user device (150). The structure management system (110) is configured to determine if the source reading is less than the source threshold. If the source reading is greater than the source threshold, then it may be determined that no interference is occurring, and normal production operations may continue. In some embodiments, the detection method (400) may include obtaining another source reading. If the source reading is determined to be less than the source threshold, then an operation duration value is obtained. In step (404), the detection method (400) may include obtaining an operation value. The structure management system (110) may be configured to obtain the operation value. The operation value may be a numerical constant.

[0059] In step (405), the detection method (400) may include determining if the operation duration value is greater than an operation duration threshold. The operation duration threshold may be a numerical constant. The operation duration threshold may be entered by a user using the user interface (151) of the structure management system (110) and/or the user device (150). The structure management system (110) is configured to determine if the operation value is greater than the operation duration threshold. If the operation duration value is less than the operation duration threshold, then it may be determined that no interference is occurring, and normal production operations may continue.

[0060] In some embodiments, the detection method (400) may include obtaining another source reading. If the operation duration value is greater than the operation duration threshold (e.g., 5 days), then a potential difference may be obtained. In step (406), the detection method (400) may include obtaining a potential difference. The potential difference may include an electrical continuity potential difference between the first structure and the second structure. The electrical continuity potential difference may be determined by subtracting the electrical potential of an electrically bonded line (e.g., the second structure (317)) from the electric potential of the first structure (117). The structure management system (110) may be configured to obtain the potential difference. In some embodiments, the potential difference may be determined from inputs (e.g., 100 mV) from a user using the user device (150).

[0061] In step (407), the detection method (400) may include determining if the potential difference is greater than or equal to a difference threshold. The structure management may be configured to determine if the potential difference is greater than or equal to the difference threshold. If the potential difference is less than the difference threshold, then it may be determined that no interference is occurring, and normal production operations may continue. In some embodiments, the detection method (400) may include obtaining another source reading. If the potential difference is greater than or equal to the difference threshold, then a surface area is obtained. In step (408), the detection method (400) may include obtaining a surface area. The structure management system (110) may be configured to obtain the surface area of the outer surface. In some embodiments, the surface area may be determined from calculating the surface area, at least in part, from dimensions of the structure. In some embodiments, the surface area may be determined from inputs (e.g., 250 m.sup.2) from a user using the user device (150).

[0062] In step (410), the detection method (400) may include determining if the surface area is greater than an area threshold. The structure management system (110) may be configured to determine if the surface area is greater than the area threshold. If the surface area is less than the area threshold, then it may be determined that no interference is occurring, and normal production operations may continue. In some embodiments, the detection method (400) may include obtaining another source reading. If the surface area is greater than the area threshold, then a severity probability is obtained. In step (412), the detection method (400) may include obtaining a severity probability. The structure management system (110) may be configured to obtain the severity probability. In some embodiments, the severity probability may be obtained by multiplying constants (e.g., K1, K2, K2) with the surface area to obtain various severity probabilities (e.g., high, medium, and low severity probabilities). The severity probability may be used to determine the corrosion severity. The severity assessment report (142) may include the severity probability and/or may be transmitted to a user.

[0063] In accordance with one or more embodiments, the detection method (400) may include initiating the alarm (125) if the severity probability is greater than a severity threshold. The severity threshold may be obtained from inputs by a user using the user device (150). The alarm (125) may be initiated from inputs by a user using the user device (150). In some embodiments, the structure monitoring system (115) may be configured to initiate the alarm (125) if the structure management system (110) determines the severity probability is greater than the threshold. In some embodiments, the structure management system (110) may be configured to transmit an alarm signal to the structure monitoring system (115). In some embodiments, if the severity probability is a high severity indicating possible structural failure of the structure, the detection method (400) may include performing maintenance on the structure to prevent structural failure of the structure. In some embodiments, maintenance may include replacing, at least a portion, of the structure.

[0064] In accordance with one or more embodiments, the detection method (400) may include transmitting severity probability data in the severity assessment report (142) to the user device (150). The user device (150) may be coupled to the first cathodic protection system (120). The user device (150) may be configured to obtain a user selection within the user interface (151) regarding the alarm (125) and the maintenance operation (160) of the structure.

[0065] Embodiments may be implemented on a computer system (500). FIG. 5 is a block diagram of a computer system (500) used to provide computational functionalities associated with described algorithms, methods, functions, processes, flows, and procedures as described in the instant disclosure, according to an implementation. The illustrated computer (502) is intended to encompass any computing device such as a high-performance computing (HPC) device, a server, desktop computer, laptop/notebook computer, wireless data port, smart phone, personal data assistant (PDA), tablet computing device, one or more processors within these devices, or any other suitable processing device, including both physical or virtual instances (or both) of the computing device. Additionally, the computer (502) may include a computer that includes an input device, such as a keypad, keyboard, touch screen, or other device that can accept user information, and an output device that conveys information associated with the operation of the computer (502), including digital data, visual, or audio information (or a combination of information), or a GUI.

[0066] The computer (502) can serve in a role as a client, network component, a server, a database or other persistency, or any other component (or a combination of roles) of a computer system for performing the subject matter described in the instant disclosure. The illustrated computer (502) is communicably coupled with a network (530). In some implementations, one or more components of the computer (502) may be configured to operate within environments, including cloud-computing-based, local, global, or other environments (or a combination of environments).

[0067] At a high level, the computer (502) is an electronic computing device operable to receive, transmit, process, store, or manage data and information associated with the described subject matter. According to some implementations, the computer (502) may also include or be communicably coupled with an application server, e-mail server, web server, caching server, streaming data server, business intelligence (BI) server, or other server (or a combination of servers).

[0068] The computer (502) can receive requests over network (530) from a client application (for example, executing on another computer (502)) and responding to the received requests by processing the said requests in an appropriate software application. In addition, requests may also be sent to the computer (502) from internal users (for example, from a command console or by other appropriate access method), external or third-parties, other automated applications, as well as any other appropriate entities, individuals, systems, or computers.

[0069] Each of the components of the computer (502) can communicate using a system bus (503). In some implementations, any, or all of the components of the computer (502), both hardware or software (or a combination of hardware and software), may interface with each other or the interface (504) (or a combination of both) over the system bus (503) using an application programming interface (API) (512) or a service layer (513) (or a combination of the API (512) and service layer (513). The API (512) may include specifications for routines, data structures, and object classes. The API (512) may be either computer-language independent or dependent and refer to a complete interface, a single function, or even a set of APIs. The service layer (513) provides software services to the computer (502) or other components (whether or not illustrated) that are communicably coupled to the computer (502). The functionality of the computer (502) may be accessible for all service consumers using this service layer. Software services, such as those provided by the service layer (513), provide reusable, defined business functionalities through a defined interface. For example, the interface may be software written in JAVA, C++, or other suitable language providing data in extensible markup language (XML) format or other suitable format. While illustrated as an integrated component of the computer (502), alternative implementations may illustrate the API (512) or the service layer (513) as stand-alone components in relation to other components of the computer (502) or other components (whether or not illustrated) that are communicably coupled to the computer (502). Moreover, any or all parts of the API (512) or the service layer (513) may be implemented as child or sub-modules of another software module, enterprise application, or hardware module without departing from the scope of this disclosure.

[0070] The computer (502) includes an interface (504). Although illustrated as a single interface (504) in FIG. 5, two or more interfaces (504) may be used according to particular needs, desires, or particular implementations of the computer (502). The interface (504) is used by the computer (502) for communicating with other systems in a distributed environment that are connected to the network (530). Generally, the interface (504 includes logic encoded in software or hardware (or a combination of software and hardware) and operable to communicate with the network (530). More specifically, the interface (504) may include software supporting one or more communication protocols associated with communications such that the network (530) or interface's hardware is operable to communicate physical signals within and outside of the illustrated computer (502).

[0071] The computer (502) includes at least one computer processor (505). Although illustrated as a single computer processor (505) in FIG. 5, two or more processors may be used according to particular needs, desires, or particular implementations of the computer (502). Generally, the computer processor (505) executes instructions and manipulates data to perform the operations of the computer (502) and any algorithms, methods, functions, processes, flows, and procedures as described in the instant disclosure.

[0072] The computer (502) also includes a memory (506) that holds data for the computer (502) or other components (or a combination of both) that can be connected to the network (530). For example, memory (506) can be a database storing data consistent with this disclosure. Although illustrated as a single memory (506) in FIG. 5, two or more memories may be used according to particular needs, desires, or particular implementations of the computer (502) and the described functionality. While memory (506) is illustrated as an integral component of the computer (502), in alternative implementations, memory (506) can be external to the computer (502).

[0073] The application (507) is an algorithmic software engine providing functionality according to particular needs, desires, or particular implementations of the computer (502), particularly with respect to functionality described in this disclosure. For example, application (507) can serve as one or more components, modules, applications, etc. Further, although illustrated as a single application (507), the application (507) may be implemented as multiple applications (507) on the computer (502). In addition, although illustrated as integral to the computer (502), in alternative implementations, the application (507) can be external to the computer (502).

[0074] There may be any number of computers (502) associated with, or external to, a computer system containing computer (502), each computer (502) communicating over network (530). Further, the term client, user, and other appropriate terminology may be used interchangeably as appropriate without departing from the scope of this disclosure. Moreover, this disclosure contemplates that many users may use one computer (502), or that one user may use multiple computers (502).

[0075] In some embodiments, the computer (502) is implemented as part of a cloud computing system. For example, a cloud computing system may include one or more remote servers along with various other cloud components, such as cloud storage units and edge servers. In particular, a cloud computing system may perform one or more computing operations without direct active management by a user device or local computer system. As such, a cloud computing system may have different functions distributed over multiple locations from a central server, which may be performed using one or more Internet connections. More specifically, cloud computing system may operate according to one or more service models, such as infrastructure as a service (IaaS), platform as a service (PaaS), software as a service (SaaS), mobile backend as a service (MBaaS), serverless computing, artificial intelligence (AI) as a service (AIaaS), and/or function as a service (FaaS).

[0076] Although only a few example embodiments have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the example embodiments without materially departing from this invention. Accordingly, all such modifications are intended to be included within the scope of this disclosure as defined in the following claims.