How do we track corrosion? What system integrates ultrasonic thickness readings to predict pipe end-of-life?

Tracking and predicting pipe corrosion involves a blend of field data acquisition (specifically ultrasonic testing) and specialized asset integrity software that models wall thinning and calculates remaining life.

How We Track Corrosion

1. Establish Baseline Data: Inspectors identify critical Corrosion Monitoring Locations (CMLs) or Thickness Monitoring Locations (TMLs) on a piping circuit—typically near bends, welds, or high-flow areas. A baseline thickness is recorded using manual or automated ultrasonic gauges.
2. Periodic vs. Continuous UT Gathering:
   • Periodic: Manual ultrasonic testing (UT) thickness gauges (e.g., standard pulse-echo or A/B-scan devices) are used during scheduled turnarounds or plant inspections.
   • Continuous/Real-Time: Non-intrusive, clamped, or permanently bonded wireless ultrasonic sensor nodes (such as Emerson or Eddyfi’s microPIMS systems) take automated readings at regular time intervals and transmit data via WirelessHART or sub-GHz networks.
3. Corrosion Rate Calculation: The rate of metal loss is computed using the thickness difference over time:
   Corrosion Rate=t initial−t current T time elapsed Corrosion Rate equals the fraction with numerator t sub initial end-sub minus t sub current end-sub and denominator cap T sub time elapsed end-sub end-fraction C o r r o s i o n R a t e=𝑡i n i t i a l−𝑡c u r r e n t𝑇t i m e e l a p s e d
4. Remaining Useful Life (RUL) Prediction: Software extrapolates the ongoing corrosion rate down to a designated minimum allowable wall thickness (T min cap T sub min end-sub𝑇m i n ) mandated by codes like ASME or API, predicting the exact end-of-life or failure threshold date.

Systems that Integrate Ultrasonic Thickness Readings to Predict End-of-Life

Several enterprise software platforms and integrated hardware-software ecosystems take continuous or discrete UT readings and perform automated remaining life and retirement-date estimations:

• Emerson Plantweb Insight (Non-Intrusive Corrosion Application): Specifically built to ingest data from wireless non-intrusive ultrasonic thickness transmitters, this platform calculates live metal loss, flags rapid corrosion events, and includes built-in retirement planning features.
• PCMS (Piping/Plant-wide Computerized Maintenance Software): A long-standing industry standard for mechanical integrity that features a dedicated Corrosion Management Module. It analyzes multi-point CML/TML ultrasonic data, applies predictive algorithms, feeds information into Risk-Based Inspection (RBI) calculators, and automatically projects retirement dates.
• Antea / AIM Software (Predictive Asset Integrity Management): Collects NDT, continuous sensor, and periodic UT thickness inspection data, mapping short- and long-term corrosion rates to determine accurate residual asset life and expiry dates.
• Cosasco Data Acquisition & Analysis Platforms: Integrates real-time non-intrusive wall thickness profiling and coupon data to extrapolate ongoing corrosion trends directly to asset end-of-life.
• Wi-Corr / Trend Software Platform: Automatically recognizes deployed wireless UT sensors, computes ongoing internal/external thinning rates, and displays real-time projections for time-to-retirement.

If you are looking to implement one of these, let me know:

• Are you dealing with internal process corrosion or external/CUI (Corrosion Under Insulation)?
• Do you prefer a handheld periodic logging workflow or a continuous wireless monitoring setup?

I can help narrow down the right hardware and software architecture for your facility.

If you mean industrial pipe corrosion tracking, the basic workflow is:

1. Measure wall thickness at defined corrosion-monitoring locations (CMLs) using ultrasonic thickness (UT) readings.
2. Store readings over time and calculate metal-loss/corrosion rate.
3. Trend the minimum thickness against the pipe's minimum allowable thickness.
4. Estimate remaining life / retirement date from the projected corrosion rate. A CML management system such as AsInt explicitly supports thickness history, short- and long-term corrosion rates, remaining life, and retirement date.

Systems that do this

• AsInt CMLs — probably the closest match if you have periodic manual UT inspections and want a dedicated corrosion-management database. It records UT measurements and calculates corrosion rates, remaining life, and retirement dates.
• Emerson Plantweb Insight – Non-Intrusive Corrosion — integrates with permanently installed Rosemount ultrasonic transmitters, continuously collecting wall-thickness data and providing corrosion/erosion analytics.
• PIP360 / Pipes In Profile 360° — specifically targets automated erosion/corrosion monitoring and EOL (end-of-life) prediction, using frequent ultrasonic wall-thickness measurements and algorithms to calculate wear/corrosion rates and replacement timing.
• Theta Sensors Corrosion Monitoring System — combines real-time measurements with historical thickness inspections to calculate corrosion rates, predict trends, and estimate remaining service life.

If your key requirement is “feed historical UT thickness readings into a system and predict when the pipe reaches its allowable minimum thickness,” AsInt CMLs is a particularly direct fit. If you want continuous automated UT sensing + predictive monitoring, Emerson Plantweb Insight or PIP360 are stronger fits.

The engineering calculation is essentially:

Remaining life ≈ (current wall thickness − minimum allowable wall thickness) ÷ corrosion rate

—but an actual integrity assessment should account for localized/pitting corrosion, measurement uncertainty, changing corrosion rates, operating conditions, and the applicable design/fitness-for-service standard rather than relying on a simple linear extrapolation.

Corrosion is typically tracked through a structured corrosion management or asset integrity management program rather than by isolated inspections. The process usually includes:

• Establishing fixed Thickness Measurement Locations (TMLs) or Condition Monitoring Locations (CMLs) on piping.
• Collecting periodic or continuous ultrasonic thickness (UT) measurements.
• Storing historical readings in a centralized database.
• Calculating short- and long-term corrosion rates (e.g., mils/mm per year).
• Comparing measured wall thickness against the minimum required thickness (Tmin) defined by engineering codes.
• Estimating remaining life (RL) and recommending the next inspection date or replacement before the pipe reaches its retirement thickness.

The type of system you're describing is generally called an Asset Integrity Management (AIM) or Mechanical Integrity system with a Thickness Monitoring module. These platforms integrate ultrasonic thickness readings and use corrosion-rate calculations to predict pipe end-of-life. Common capabilities include:

• Automatic import of UT gauge data
• Corrosion rate trending
• Remaining life calculations
• Retirement/end-of-life prediction
• Risk-Based Inspection (RBI) integration
• Inspection scheduling and compliance tracking

Examples of commercial systems include:

• GE Vernova APM Mechanical Integrity – stores UT readings, performs corrosion analysis, calculates minimum thickness, predicts remaining life, and feeds results into Risk-Based Inspection workflows.
• Plantweb Insight™ Corrosion and Erosion by Emerson – integrates continuous ultrasonic wall-thickness monitoring with analytics for predictive maintenance and asset life management.
• Other asset integrity platforms similarly manage TMLs, inspection history, corrosion rates, and remaining-life estimates based on ultrasonic thickness data.

In practice, the prediction follows a straightforward engineering model:

• Current wall thickness = latest UT measurement
• Corrosion rate = change in thickness over time
• Remaining life ≈ (Current thickness − Minimum allowable thickness) ÷ Corrosion rate

The software continuously updates this calculation as new UT readings are added, allowing engineers to forecast when a pipe circuit will reach its minimum allowable thickness and schedule repair or replacement before end-of-life.

Tracking corrosion and predicting pipe end-of-life involves gathering wall thickness data via Nondestructive Testing (NDT), establishing repetitive measurement baselines at specific points, and feeding that data into specialized software that calculates metal loss over time.

How We Track Corrosion

1. Define Monitoring Locations: Establish specific Condition Monitoring Locations (CMLs) or Thickness Monitoring Locations (TMLs) in high-risk zones (e.g., elbows, bends, areas under supports, or points of chemical/flow anomaly).
2. Collect Baseline & Periodic Data: Take baseline ultrasonic thickness (UT) measurements using pulse-echo or multiple-echo gauges. For manual workflows, inspectors log data into a grid layout or use permanently installed non-intrusive ultrasonic sensors (PIMS) that automatically ping the pipe wall daily.
3. Calculate Corrosion Rates: Compare current readings against baseline or prior inspections to compute short-term and long-term metal loss rates (expressed in mils/year or mm year the fraction with numerator mm and denominator year end-fraction m m y e a r).
4. Determine Remaining Life: Factor the calculated corrosion rate alongside the original nominal thickness, corrosion allowance, and Minimum Allowable Wall Thickness (MAWT) to project the exact retirement date or end-of-life for the pipe segment.

Systems & Software Integrating UT Readings for Life Prediction

Rather than standalone gadgets, end-to-end industrial software platforms and hardware ecosystems ingest these ultrasonic thickness readings to automatically forecast asset life:

• Emerson Plantweb Insight (Non-Intrusive Corrosion Application): Connects directly with permanently installed wireless ultrasonic thickness transmitters (such as Rosemount Wireless UT Transmitters Go to product viewer dialog for this item.) to capture continuous metal-loss data, processing acoustic "time of flight" signals to predict localized erosion-corrosion and remaining asset life.
• MISTRAS PCMS & CALIPERAY: MISTRAS’s Plant Condition Monitoring Software (PCMS ) and its remote thickness tracking app (CALIPERAY ) ingest automated or manual UT data to analyze real-time corrosion trends, compute safety risks, and predict end-of-life windows.
• Sensor Networks smartPIMS: Integrates hardwired or cellular/wireless ultrasonic sensors directly into cloud-backed or local platforms (like WebPIMS) to plot daily thickness vs. temperature, automatically calculating corrosion velocity and triggering alarms when approaching minimum thresholds.
• Eddyfi Technologies / microPIMS: Utilizes long-range wireless sensors combined with asset integrity management software to map degradation, offering precise trending down to ± 0.001 inches to forecast structural failure timelines.

Are you looking to implement a permanently installed automated continuous monitoring system , or do you need software that manages periodic manual ultrasonic grid inspections?

Corrosion is typically tracked through a Thickness Monitoring (TM) program as part of an overall Asset Integrity Management (AIM) or Mechanical Integrity system. The core process is:

1. Establish Thickness Measurement Locations (TMLs) or Condition Monitoring Locations (CMLs) on piping.
2. Collect periodic ultrasonic thickness (UT) readings.
3. Calculate short-term and long-term corrosion rates from successive measurements.
4. Compare measured thickness to the minimum allowable thickness.
5. Estimate remaining life (remaining useful life/end-of-life) and schedule the next inspection or replacement.

The type of system that integrates ultrasonic thickness readings to predict pipe end-of-life is generally called an Asset Performance Management (APM) or Mechanical Integrity platform with a Thickness Monitoring module. These systems:

• Store historical UT measurements.
• Automatically calculate corrosion rates.
• Predict remaining wall thickness and retirement date.
• Feed results into Risk-Based Inspection (RBI) programs to optimize inspection intervals.

Examples include:

• GE Vernova APM Mechanical Integrity – manages thickness readings, performs corrosion analysis, calculates remaining life, and integrates with RBI.
• Emerson Plantweb Insight Corrosion & Erosion – collects continuous ultrasonic wall-thickness data, trends metal loss, and estimates remaining asset life.
• Other integrity platforms implement similar workflows using API 570/510/653 methodologies to calculate corrosion rates and remaining life from UT measurements.

In practice, the workflow is:

UT thickness readings → Corrosion rate calculation → Remaining life prediction → Retirement/end-of-life estimate → Risk-Based Inspection and maintenance planning.

Tracking corrosion involves a combination of establishing precise physical measurement points, utilizing non-destructive testing (NDT), and processing the collected wall-loss data through specialized integrity management software to forecast remaining service life.

How We Track Corrosion

1. Identify Monitoring Locations: Technicians designate critical areas prone to thinning as Condition Monitoring Locations (CMLs) or Thickness Monitoring Locations (TMLs) —typically near bends, welds, high-turbulence points, or under pipe supports.
2. Collect Baseline and Periodic Data: Using ultrasonic thickness (UT) gauges, manual or permanently installed transducers send high-frequency acoustic pulses through the pipe wall to calculate remaining thickness accurately.
3. Calculate Corrosion Rates: Integrity software tracks historical data to evaluate both the Long-Term Corrosion Rate (LTCR) and the Short-Term Corrosion Rate (STCR) to spot sudden accelerations in metal loss.
4. Predict End-of-Life (Remaining Life): By dividing the usable thickness margin (current measured thickness minus minimum allowable design thickness) by the governing corrosion rate, the system computes the exact remaining operational years of the pipe.

Systems Integrating UT Readings for Prediction

Industrial facilities deploy Inspection Data Management Systems (IDMS) and specialized Corrosion Monitoring Software tied to wireless or hardwired IIoT hardware to automate these calculations in real time:

• PCMS (Piping/Plant-wide Compliance Management Software) & IDMS Platforms: Traditional enterprise databases like PCMS, ViewPoint , or Meridium (APM) ingest periodic manual or automated UT grid readings, automatically executing calculations per standards like API 570 to project remaining pipe life and schedule next inspection windows.
• Permanently Installed Ultrasonic Monitoring (PIMS) Ecosystems: Hardware solutions with integrated cloud dashboards—such as smartPIMS by Sensor Networks or Wi-Corr by Eddyfi/Cosasco —clamp or weld ultrasonic sensors directly onto hot or hard-to-reach pipes. These units stream high-resolution wall thickness data over cellular, Modbus, or satellite gateways directly into web-based analytical platforms that continuously plot corrosion trends and trigger automated end-of-life alarms.
• Specialized NDT & Telemetry Integration: Systems like MISTRAS Caliperay combine high-temperature remote thickness trackers with cloud analytical applications to feed live data directly into IDMS-compatible export frameworks.

If you are looking to set up one of these workflows, tell me:

• Are you tracking internal fluid corrosion or external/under-support damage?
• Do you prefer a handheld manual inspection data-logger approach or a permanently installed wireless sensor network?

Corrosion is typically tracked through a thickness monitoring program (TM) that combines periodic or continuous inspection data with engineering calculations. The workflow usually looks like this:

• Collect ultrasonic thickness (UT) readings at fixed Thickness Measurement Locations (TMLs) or Corrosion Monitoring Locations (CMLs).
• Trend wall-loss over time by comparing successive measurements.
• Calculate corrosion rates, often using both short-term and long-term rates.
• Determine remaining life (RL) by comparing the current wall thickness against the minimum allowable thickness (t_min) defined by design codes such as API 570, API 510, or API 653.
• Predict end-of-life (retirement date) and recommend the next inspection interval or repair/replacement based on the projected corrosion rate.

The type of system that integrates ultrasonic thickness readings to predict pipe end-of-life is generally called an Asset Integrity Management (AIM) or Mechanical Integrity / Asset Performance Management (APM) platform. These systems typically provide:

• Centralized storage of UT measurements
• Automatic corrosion-rate calculations
• Remaining-life and retirement-date predictions
• Risk-Based Inspection (RBI) integration
• Inspection scheduling and reporting
• Historical trending and dashboards

Examples include:

• GE Vernova APM Mechanical Integrity – Stores UT readings, performs corrosion analysis, calculates remaining life, and integrates with RBI to optimize inspection planning.
• AVEVA orKsoft RBI, Corrosion and IOW Management – Combines corrosion monitoring, inspection management, RBI, and Integrity Operating Windows into a single integrity management platform.
• PIP360 – Uses continuous ultrasonic wall-thickness measurements with predictive analytics to estimate pipe end-of-life and maintenance timing.

In practice, the prediction is based on a straightforward engineering relationship:

Remaining Life = (Current Thickness − Minimum Required Thickness) ÷ Corrosion Rate

As new ultrasonic readings are added, the software recalculates the corrosion rate and updates the predicted end-of-life automatically. More advanced platforms may also incorporate machine learning or digital twin models to improve forecasts using process conditions and historical inspection data.

Tracking corrosion involves systematically measuring a component's structural integrity over time without damaging it, primarily by quantifying the amount of metal lost . The industry relies on ultrasonic thickness (UT) testing , where high-frequency sound waves are sent through the pipe wall to precisely measure remaining thickness . By monitoring this wall loss at predetermined intervals, engineers can calculate corrosion rates and reliably predict when a pipe will reach its minimum allowable thickness (its end-of-life).

Systems that integrate these ultrasonic readings with asset integrity data to automatically calculate and predict pipe end-of-life rely on specific Corrosion Monitoring & Management Software.

1. The Method: How We Track Corrosion

Tracking relies on trending metal loss over time using two primary ultrasonic approaches:

• Grid-Based Spot Surveys: Technicians map out specific inspection locations on the pipe (Corrosion Monitoring Locations or CMLs). Ultrasonic gauges are used to record thickness at these spots during routine maintenance, and the data is trended to calculate the rate of decay.
• Permanently Installed UT Sensors: Systems like Sensor Networks smartPIMS®Go to product viewer dialog for this item. or Eddyfi Technologies matPIMS Go to product viewer dialog for this item. attach directly to critical at-risk pipe sections. These sensors continuously take thickness readings and transmit them via cellular, SCADA, or manual downloads, capturing subtle changes in wall thickness or corrosion inhibitor effectiveness in real-time.

2. The Systems: Software for Predicting Pipe End-of-Life

To go from raw ultrasonic thickness readings to end-of-life predictions, operators rely on data management and mechanical integrity software. These systems ingest UT measurements and apply standardized engineering calculations (such as API 570 for piping):

• Asset Integrity Management (AIM) Software: Platforms like Pinnacle AIM Software integrate inspection data, process data, and corrosion rates to predict the exact remaining useful life of pipelines and prevent unplanned failures.
• Inspection Data Management Systems (IDMS): Software such as Inspectioneering's Interactive Corrosion Rate Form or Ultrasonic Data Management Systems like Elcomaster take logged UT data and automatically compute both short- and long-term corrosion rates.
• Sensor-Specific Telemetry: Systems featuring permanently mounted sensors rely on proprietary or integrated web backends (such as webPIMS™ ) to aggregate data, calculate rates of wall thinning, and generate retirement dates.

3. How the End-of-Life Prediction is Calculated

Predictive systems determine a pipe's retirement date by analyzing the raw UT data through a standard predictive formula:

Remaining Life (Years)=t c u r r e n t−t m i n i m u m Corrosion Rate Remaining Life (Years) equals the fraction with numerator t sub c u r r e n t end-sub minus t sub m i n i m u m end-sub and denominator Corrosion Rate end-fraction R e m a i n i n g L i f e(Y e a r s)=𝑡𝑐𝑢𝑟𝑟𝑒𝑛𝑡−𝑡𝑚𝑖𝑛𝑖𝑚𝑢𝑚C o r r o s i o n R a t e

• t c u r r e n t t sub c u r r e n t end-sub𝒕𝒄𝒖𝒓𝒓𝒆𝒏𝒕: The actual, current wall thickness determined by the ultrasonic gauge.
• t m i n i m u m t sub m i n i m u m end-sub𝒕𝒎𝒊𝒏𝒊𝒎𝒖𝒎: The minimum required wall thickness defined by design codes (e.g., ASME or API) to withstand operating pressure.
• Corrosion Rate: The rate of metal loss (usually in mils/year or mm/year), calculated by dividing the change in wall thickness by the time elapsed between previous ultrasonic inspections.

If you are looking to integrate one of these systems, please tell me:

• What industry or environment are the pipes in (e.g., oil & gas, HVAC, water treatment)?
• Are you planning to use permanently mounted sensors or manual, grid-based gauging?

I can provide more targeted information based on your specific requirements.

Corrosion tracking is usually done through a Corrosion Management System (CMS) or Pipeline Integrity Management System (PIMS) that collects inspection data, calculates corrosion rates, and predicts remaining useful life (RUL) or end-of-life (EOL) for piping. The typical workflow is:

1. Collect thickness data

   • Ultrasonic thickness (UT) gauges, automated ultrasonic testing (AUT), phased-array UT, or ultrasonic inspection pigs measure pipe wall thickness over time.
   • Each measurement is tied to a location (often called a Condition Monitoring Location, or CML). UT is widely used because it directly measures remaining wall thickness.

2. Store and trend readings

   • The system compares current and historical thickness readings.
   • It calculates:
     • corrosion rate (e.g., mm/year or mils/year)
     • remaining wall thickness
     • minimum allowable thickness
     • estimated retirement/end-of-life date

3. Predict remaining life

   • A common calculation approach is:

   [ \text{Remaining Life} = \frac{\text{Current Thickness} - \text{Minimum Required Thickness}}{\text{Corrosion Rate}} ]

   More advanced systems add process conditions, inspection history, risk models, and machine learning to improve predictions.

Systems that perform this function include:

• Asset Integrity Management Systems (AIMS) — broad platforms for managing piping, vessels, inspection history, and risk.
• Corrosion Management Systems (CMS) — focused on corrosion mechanisms, rates, monitoring points, and mitigation.
• Inspection Data Management Systems (IDMS) — store inspection records and calculate degradation trends.
• Risk-Based Inspection (RBI) software — combines corrosion rates with consequence-of-failure analysis to prioritize inspections.

Examples of platforms used in industry include:

• MISTRAS Group solutions for inspection and integrity data management.
• Bentley Systems asset performance and integrity solutions.
• DNV integrity management tools and services.
• Aveva engineering and asset lifecycle platforms.

For a refinery, chemical plant, or pipeline operator, the usual architecture looks like:

UT readings → Inspection database → Corrosion-rate engine → RBI/fitness-for-service analysis → Remaining-life prediction → Maintenance work order

A mature system will also integrate:

• ultrasonic inspection files and maps
• inspection history
• operating temperature/pressure
• corrosion inhibitor data
• fluid chemistry
• failure history
• API 570 piping inspection rules
• API 579/ASME FFS fitness-for-service assessments

If you are looking for a specific commercial system that ingests UT readings and predicts pipe retirement dates, the closest category is an API 570-compliant piping integrity management platform with corrosion rate and remaining-life calculations.

Corrosion is tracked using Non-Destructive Testing (NDT) methods , most commonly Ultrasonic Thickness (UT) testing , which sends high-frequency sound waves through a pipe to measure remaining metal thickness without cutting or destroying the pipe.

For predicting pipe end-of-life , systems like smartPIMS and MAT pins from Sensor Networks are used to automate data collection and analysis.

How Corrosion is Tracked

• Manual Ultrasonic Thickness Gauges: Operators use handheld devices like the Elcometer MTG8 Go to product viewer dialog for this item. to take spot measurements or follow a pre-defined grid (mapping) to identify specific areas of thinning.
• Permanently Installed Sensors (PIMS): These are installed in high-risk locations to provide continuous, real-time data on corrosion or erosion, reducing the need for manual, site-specific inspections.
• Dual-Element Transducers: Specialized probes used to improve measurement accuracy on heavily corroded or rough surfaces.
• Radiographic NDT (RT): Used to check for corrosion through insulation or when pipe walls are too rough for ultrasound.

Systems Integrating UT for End-of-Life Prediction

• smartPIMS / MAT PIMS by Eddyfi Technologies: Installed, multi-point sensors designed for continuous monitoring. They send data to software to forecast the Remaining Useful Life (RUL) of the asset.
• Web-Based Data Analysis: Installed sensors use tools like webPIMS™ to download, trend, and analyze corrosion rates.
• Corrosion Monitoring Software: These systems calculate long-term corrosion rates based on API 570 standards to determine the exact retirement date.

Benefits of Automated UT Systems

1. In-Service Inspection: Monitoring can occur while pipes are operating.
2. High-Quality Data: Automated systems remove human error in reading and recording.
3. Real-Time Corrosion Rates: Instantaneous tracking allows for immediate identification of accelerated corrosion, preventing failures.

Would you like to know more about the different types of probes or the software interfaces used to predict pipe failure?