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

Corrosion is typically tracked by establishing Condition Monitoring Locations (CMLs) on each piping circuit and repeatedly measuring wall thickness at the same locations with ultrasonic thickness (UT) readings.

The basic workflow is:

1. Capture baseline thickness at each CML/TML.
2. Repeat UT measurements at the same physical locations.
3. Calculate the short-term and long-term corrosion rates from successive readings.
4. Compare current thickness with the required/minimum allowable thickness.
5. Extrapolate the corrosion trend to estimate remaining life / retirement date.
6. Use the result to determine the next inspection interval and prioritize high-risk circuits. This is essentially the methodology described in API 570.

What system does this?

If you're asking for a software system that integrates UT thickness data and predicts pipe end-of-life, there are several options:

• AsInt IDMS / CML Management — specifically manages CML thickness readings, calculates short- and long-term corrosion rates, remaining life and retirement dates, and trends the data.
• GE Vernova Asset Integrity / Asset Performance Management — provides thickness monitoring, corrosion-rate analysis, required thickness calculations, next-inspection planning and retirement-date analysis.
• Cenosco S-IDAP — processes wall-thickness data, detects anomalous readings, calculates corrosion rate and remaining life for each CML/measurement point, and highlights locations with high corrosion rates or low remaining life.
• webPIMS — cloud-based ultrasonic corrosion/erosion monitoring that stores and trends metal-loss data and corrosion rates, with alarms for thickness and corrosion-rate limits.

If you mean “what is the standard system/concept?”, the answer is a Corrosion/Mechanical Integrity Management System (CIMS/MIMS) built around CML/TML data. The engineering calculation is essentially:

Remaining life = (current thickness − required thickness) ÷ corrosion rate.

So the system doesn't merely store UT readings—it creates a thickness-vs-time trend, calculates corrosion velocity, and forecasts when the pipe will reach its allowable/retirement thickness.

Tracking corrosion and predicting pipe end-of-life involves establishing systematic inspection routines, defining specific monitoring points, and processing thickness data through dedicated engineering software.

How We Track Corrosion

Corrosion tracking relies on a mix of non-destructive testing (NDT) and continuous monitoring strategies:

• Condition Monitoring Locations (CMLs): Specific, repeatable spots on a piping system where thickness measurements are routinely taken to ensure data consistency over time.
• Ultrasonic Testing (UT): Manual or automated ultrasonic gauges send high-frequency sound waves into the pipe wall to measure remaining thickness accurately, even with coatings present.
• Corrosion Coupons & Probes: Invasive or non-invasive electrochemical sensors (like ER/LPR probes) paired with UT provide real-time environmental corrosiveness data alongside physical wall measurements.
• Corrosion Rate Calculations: Software compares current UT readings against baseline (original nominal thickness) or previous inspection cycles to calculate both short-term and long-term corrosion rates.

Systems That Integrate UT Readings to Predict Pipe End-of-Life

Pipe end-of-life (remaining service life) is calculated using industry standards like API 579 / ASME FFS-1 (Fitness-for-Service) or API 510/570 for pressure vessels and piping. This is automated via Asset Integrity Management (AIM) or Asset Performance Management (APM) software platforms.

Popular enterprise systems that ingest UT thickness data, run corrosion-rate algorithms, and predict exact end-of-life/retirement dates include:

Are you looking to set up tracking for a specific industry/plant environment (like oil & gas, water utilities, or chemical processing), or do you need help understanding the math formula (𝑇𝑎𝑐𝑡𝑢𝑎𝑙−𝑇𝑚𝑖𝑛/C o r r o s i o n R a t e) used for these predictions?

Corrosion is typically tracked through an asset integrity management (AIM) or corrosion management system that combines inspection history, ultrasonic thickness (UT) measurements, engineering calculations, and risk-based inspection (RBI) methods. The goal is to turn repeated wall-thickness measurements into a corrosion rate, remaining wall thickness, and estimated end-of-life (EOL) date.

A typical workflow looks like this:

1. Collect thickness data

• Inspectors take ultrasonic thickness readings at predefined Thickness Measurement Locations (TMLs) or Condition Monitoring Locations (CMLs).
• Readings are stored with asset ID, location, date, and inspection method. Some systems can ingest automated UT sensor data.

2. Calculate corrosion rate

• The system compares current and historical thickness readings: - Corrosion rate = thickness loss ÷ time interval
• It can calculate short-term and long-term trends to account for changing corrosion behavior.

3. Predict remaining life

• The software compares the measured thickness against the required minimum thickness (t-min).
• Remaining life is estimated from: - Current thickness
• Corrosion rate
• Allowable minimum thickness
• Operating conditions
• The result is a projected retirement/EOL date or inspection due date.

4. Feed risk models

• Many platforms integrate with RBI methodologies such as API 580/API 581 to prioritize inspection and maintenance based on probability and consequence of failure.

Examples of systems that do this include:

• GE Vernova gevernova.com — integrates thickness monitoring, corrosion analysis, remaining-life calculations, and RBI workflows.
• AVEVA aveva.com — combines corrosion, RBI, inspection planning, and integrity operating windows.
• PCMS — provides corrosion modules that track wall thickness, corrosion rates, inspection dates, and retirement dates.

For a refinery, chemical plant, or pipeline operator, the system you are probably looking for is generally called an Asset Integrity Management (AIM) platform with Thickness Monitoring (TM), Corrosion Management, and Remaining Life Assessment (RLA) capabilities.

If you mean a specific environment (oil & gas pipeline, refinery piping, power plant boiler tubing, etc.), the best-fit systems and calculations can differ.

We track corrosion using non-destructive ultrasonic thickness (UT) testing paired with specialized Corrosion Monitoring Software (CMMS) and Inspection Data Management Systems (IDMS) that calculate corrosion rates and predict remaining pipe life.

How We Track Corrosion

1. Establish TMLs: Technicians designate specific Thickness Monitoring Locations (TMLs) or corrosion monitoring points on high-risk areas like bends, welds, and supports.
2. Ultrasonic Measurement: A transducer sends high-frequency sound waves into the pipe wall, measuring the echo return time to determine remaining metal thickness down to thousandths of an inch without cutting the pipe.
3. Data Logging: Readings are recorded sequentially over time during scheduled plant turnarounds or via permanently mounted ultrasonic sensors.

Systems That Integrate UT Readings for End-of-Life Prediction

Asset integrity and Inspection Data Management Systems (IDMS) ingest UT readings, compare them against baseline nominal thickness, and automatically compute corrosion rates (𝐶𝑅=𝑡𝑖𝑛𝑖𝑡𝑖𝑎𝑙−𝑡𝑎𝑐𝑡𝑢𝑎𝑙Δ𝑡𝑖𝑚𝑒) and remaining useful life (𝑅𝑈𝐿=𝑡𝑎𝑐𝑡𝑢𝑎𝑙−𝑡𝑚𝑖𝑛𝐶𝑅).

If you'd like, tell me:

• What industry or environment are the pipes in (oil and gas, water treatment, chemical processing)?
• Are you looking for portable handheld gauge software or an enterprise asset integrity platform?

I can provide a more tailored software recommendation.

If you mean industrial piping corrosion management, the system you’re describing is generally an Asset Integrity Management (AIM) / Mechanical Integrity system with Thickness Monitoring (TM).

The workflow is:

1. Collect UT thickness readings at fixed Condition Monitoring Locations (CMLs) / Thickness Measurement Locations.
2. Store the complete history for each point—asset, location, date, thickness, inspection method, etc.
3. Calculate short-term and long-term corrosion rates from successive readings.
4. Compare projected thickness against the engineering minimum/retirement thickness (Tmin).
5. Calculate remaining life / end-of-life date and flag locations approaching the limit.
6. Feed that information into RBI and inspection scheduling, so high-risk or rapidly thinning circuits get attention first.

Systems that do this

• GE Vernova APM Mechanical Integrity — a mature enterprise AIM platform. Its Thickness Monitoring capability stores thickness readings, performs corrosion analysis, calculates minimum safe thickness, and supports next-inspection and retirement-date decisions.
• AVEVA/AMETHYSTE orKsoft — integrates CML management, inspection management, corrosion, RBI, and integrity operating windows in one platform.
• AsInt CMLs — specifically focused on CML management, UT thickness history, corrosion rates, remaining life, half-life and retirement date.
• Strim — a newer asset-integrity platform that centralizes UT/CML data and trends corrosion rates to project remaining life.
• iFactory — focuses particularly on piping/API 570 workflows, including UT ingestion, corrosion-rate calculation, remaining life and inspection scheduling.

There are also continuous UT systems rather than software-only approaches. For example, MISTRAS CALIPERAY permanently mounts UT sensors on difficult-to-access piping and sends thickness data to its web application or integrated database systems.

If you're asking what system I'd choose for a plant: I'd distinguish between GE APM / AVEVA-class enterprise AIM for a large existing integrity program, versus a lighter CML/UT-focused platform if the main requirement is simply “import UT readings → calculate corrosion rate → predict pipe end-of-life → schedule inspection.”

The key technical term to ask vendors for is “CML/TML-based thickness monitoring with corrosion-rate trending and remaining-life/retirement-date prediction, integrated with API 570/RBI.”

Here are top web results for exploring this topic:

scanndt.com·https://scanndt.com/ut-corrosion-monitoring/**Corrosion** Monitoring via Ultrasonic Thickness Gauging | ScanTech When you want to track how much metal is being lost to corrosion over time, ultrasonic thickness gauging (UTG) offers one of the most reliable and non-invasive approaches available in NDT. By comparin Emerson.com·https://www.emerson.com**Ultrasonic Thickness** (UT) Corrosion & Erosion Monitoring Monitor pipe wall thickness non-intrusively. Wireless ultrasonic sensors to track corrosion and erosion rates. Sonatest·https://sonatest.com**Ultrasonic Corrosion** Mapping of Pipelines - Sonatest UT and PAUT, with Sonatest technology, offer reliable pipeline inspection solutions. Smart scan plans drive innovation, ensuring the safety and longevity of critical infrastructure. Fig. 1 - Pipeline YouTube·https://www.youtube.com How to do a Grid Corrosion Inspection using the Elcometer MTG8 ...It is vital to do regular non-destructive testing using an ultrasonic thickness gauge, to inspect for corrosion throughout the service life of an asset; such as a pipeline, a pressure vessel, or a sto Dakota Ultrasonics·https://dakotandt.com**Ultrasonic Thickness** Gauging of Heavily Corroded Pipes Pipe integrity and corrosion monitoring is critical across many industries. These inspections are typically performed using ultrasonic thickness gauges, but severely corroded pipes can pose significan Evident Scientific·https://ims.evidentscientific.com Guide to Corrosion Thickness Gauges and Measurement - Evident Guide to Corrosion Thickness Gauges and Corrosion Measurement. Corrosion survey. Just about anything made of common structural metals is subject to corrosion. An important challenge in many industries Inspectioneering·https://inspectioneering.com**Ultrasonic Corrosion** Monitoring – It's Time for a Paradigm Shift Corrosion monitoring using ultrasonic sensors is a well-known method to determine remaining material thickness and, therefore, the on-going integrity of pipelines, pipes, vessels, and tanks. By using Processing Magazine·https://www.processingmagazine.com**Ultrasonic corrosion** gauging with dual element transducers For corrosion applications, dual element transducers measure the remaining wall thickness of pipes, boiler tubes, storage tanks and pressure vessels, among others. Greg Bauer. March 20, 2020. 10 min r ClampOn·https://www.clampon.com**Corrosion** Monitoring - ClampOn In the early 2000s ClampOn developed the CEM Corrosion-Erosion Monitor, a non-intrusive instrument for monitoring the wall thickness of pipes throughout a decades-long service life, corrosion monitori Cygnus Instruments·https://cygnus-instruments.com A Smarter Way to Gauge Corrosion - Cygnus Instruments More importantly, the Cygnus-pioneered Multiple Echo technology can measure just the thickness of the substrate material under test and ignore any protective coatings. This effectively eliminates the

If you mean industrial/process piping, corrosion is typically tracked through a Mechanical Integrity / Asset Integrity Management (AIM) system using Condition Monitoring Locations (CMLs) and recurring ultrasonic thickness (UT) measurements.

The basic workflow is:

1. Establish CMLs/TMLs on the pipe circuit and repeatedly measure the same locations.

2. Store each UT reading with its date and location, creating a thickness history.

3. Calculate the short-term and long-term corrosion rates from successive readings.

4. Determine the pipe's minimum required thickness (t_required or t_min).

5. Calculate remaining life approximately as:

   Remaining life = (current measured thickness − required thickness) ÷ corrosion rate

   That's the methodology specified in API 570.

6. Project when the wall reaches the retirement/minimum allowable thickness and use that result to set the next inspection date or trigger an engineering/RBI review.

What system does this?

A good example is GE Vernova APM (Asset Performance Management) – Mechanical Integrity/Thickness Monitoring. It can collect thickness data from UT gauges/data loggers, calculate remaining life from the minimum safe thickness, and integrate those results with its Risk-Based Inspection (RBI) module.

Other systems with this capability include:

• AVEVA orKsoft — corrosion management + CML management + RBI + inspection management, with long-term asset-life management.
• SHIELD IDMS — specifically tracks CML corrosion rates, remaining life and retirement dates and incorporates API 510/570/653 rules.
• NEXUS SPE Expert System — CML trending, remaining-life calculations, tmin, corrosion models and automated inspection planning.

So if you're looking for the category of system, the term I'd use is Corrosion/Inspection Data Management System (IDMS) integrated with an Asset Integrity Management (AIM/APM) and RBI system.

The key distinction is that UT equipment collects the thickness data; the integrity-management system turns that history into corrosion rate, remaining life, projected end-of-life, and inspection decisions. API 570 explicitly calls for successive thickness measurements to be used for corrosion-rate, remaining-life and next-inspection calculations.

If you tell me whether this is for oil & gas, chemical processing, power, water, or another application, I can narrow this down to the best 3–5 commercial systems and show exactly how their UT → corrosion-rate → end-of-life workflow compares.

Tracking corrosion involves establishing an accurate baseline wall thickness at critical Condition Monitoring Locations (CMLs) —often called Thickness Monitoring Locations (TMLs) —and performing periodic or continuous non-destructive ultrasonic testing (UT) to quantify metal loss . Specialized software platforms like iFactory AI or enterprise inspection data management software (IDMS) like MISTRAS PCMS integrate these field ultrasonic readings to automatically calculate short-term and long-term corrosion rates in compliance with standards like API 570 , dynamically projecting remaining service life and auto-scheduling re-inspection intervals before retirement thickness is reached.

Core Methods for Tracking Corrosion

• Manual Ultrasonic Testing (UTG): Technicians use portable digital thickness gauges (such as [Elcometer MTG2 Go to product viewer dialog for this item. ](https://www.youtube.com/watch?v=0wcP6kZA-WA) or [Olympus 38DL Plus Go to product viewer dialog for this item. ](https://www.survtechsolutions.com/post/survtech-saved-client-millions-utilizing-ndt-pipe-thickness-testing) ) to record spot or grid-based measurements at designated CMLs during planned maintenance windows.
• Permanently Installed Ultrasonic Sensors: Non-intrusive wireless sensor nodes (such as Eddyfi microPIMS Go to product viewer dialog for this item. or Inductosense WAND Go to product viewer dialog for this item. ) are attached directly to high-risk pipe elbows or deadlegs to capture automated daily thickness echoes without interrupting operations.
• Advanced Screening & Robotic Crawlers: High-coverage tools like Guided Wave UT (GWUT) or remote-access magnetic/ultrasonic crawlers (such as Voliro UT Drones Go to product viewer dialog for this item.) map large, difficult-to-access pipe sections rapidly.

Software Systems Integrating UT Data for End-of-Life (EOL) Prediction

• iFactory AI: Ingests field UT data natively, automates API 570 corrosion rate formulas, flags CMLs nearing critical minimums, and triggers predictive maintenance workflows.
• MISTRAS PCMS / CALIPERAY: Industrial plant condition monitoring and web applications that ingest live or batch UT streams, trend wall loss over time, and forecast accurate risk profiles and retirement dates.
• PIP360: Specialized pipeline integrity and wear-tracking system that ingests daily ultrasonic profile data to forecast effective lifecycle limits and optimal rotation scheduling for aggressive slurry/erosion environments.

If you share the pipe operating environment (e.g., fluid type, temperature, and whether you need manual batch loading or continuous wireless sensors), I can help recommend the most suitable platform architecture for your facility.

If you mean an industrial piping corrosion-management system, the basic approach is:

1. Measure wall thickness at fixed CMLs/TMLs using ultrasonic thickness (UT) inspections.
2. Trend the readings over time to calculate short- and long-term corrosion rates.
3. Compare projected thickness against the minimum allowable thickness (Tmin).
4. Calculate remaining life / retirement date from the corrosion trend.
5. Feed that result into Risk-Based Inspection (RBI) to prioritize inspections and determine when intervention is needed.

A useful rule-of-thumb calculation is:

Remaining life ≈ (current thickness − Tmin) ÷ corrosion rate

Systems that do this

• GE Vernova APM Mechanical Integrity — probably the closest match if you want an established enterprise system. It stores thickness readings, performs corrosion analysis, calculates remaining life, and integrates the results with RBI.
• AsInt CMLs — specifically tracks UT thickness measurements at condition-monitoring locations and calculates corrosion rates, remaining life, half-life and retirement date.
• AVEVA orKsoft — combines corrosion management, CML management, inspection management and API 581-based RBI for piping and other static equipment.
• TWI RiskWISE — an RBI/integrity platform that can translate inspection data into pipeline risk and remaining-life profiles.

If you're specifically looking for “UT gauge → automatic corrosion-rate calculation → predicted pipe end-of-life → inspection alert”, I'd shortlist GE APM Mechanical Integrity and AsInt CMLs first. The latter is particularly direct for CML/TML-based pipe-wall tracking.

One important distinction: “end-of-life” isn't simply the date the pipe reaches zero thickness. The system should calculate the engineering minimum allowable thickness based on design/material/pressure requirements, then project when the measured degradation reaches that limit.

Tracking pipe corrosion involves monitoring wall-thickness degradation over time to calculate actual metal loss rates and forecast remaining asset life.

How We Track Corrosion

1. Establish Baseline Data (CMLs/TMLs): Select specific Corrosion Monitoring Locations or Thickness Monitoring Locations in high-risk areas (e.g., pipe elbows, welds, areas under supports) and record initial precise baseline wall thicknesses.
2. Periodic or Continuous UT Measurement: Use Ultrasonic Testing (UT) via manual gauges during routine inspections or permanent/semi-permanent non-intrusive ultrasonic transducers attached directly to the pipe exterior.
3. Data Logging & Trending: Capture echo signals (A-scans, B-scans, or absolute thickness values) to track micro-level metal loss down to thousandths of an inch.
4. Corrosion Rate & End-of-Life Calculation: Compute the corrosion rate (𝐶𝑅=𝑇𝑖𝑛𝑖𝑡𝑖𝑎𝑙−𝑇𝑐𝑢𝑟𝑟𝑒𝑛𝑡𝑇𝑖𝑚𝑒) and project when the pipe wall will hit the Minimum Allowable Wall Thickness (MAWT) , determining the exact end-of-life.

Systems That Integrate UT Readings to Predict End-of-Life

Industrial facilities rely on specialized Inspection Data Management Software (IDMS) or Corrosion Management Software (CMS) platforms paired with hardware arrays to automate this prediction:

• Plant Condition Monitoring Software (PCMS): Industry-standard IDMS developed by MISTRAS Group , which accepts manual or automated UT data inputs to compute corrosion rates, track degradation trends, and signal retirement or inspection windows.
• Plantweb Insight Corrosion and Erosion Software: Emerson's dedicated software platform that seamlessly ingests data from wireless non-intrusive ultrasonic transmitters (such as Rosemount or specialized partner hardware) to deliver real-time wall loss calculations and retirement/replacement planning features.
• Antea Asset Integrity Management (AIM) Software: Integrates data from NDT, online sensors, and traditional thickness monitoring locations (CMLs) to run predictive analytics, mapping short- and long-term residual life and expiration dates for piping assets.
• SmartPIMS / Sensor Networks Web Backend: Cloud and on-premise software architecture that ingests multi-point ultrasonic sensor data via cellular or Modbus/SCADA connection to automatically trend thinning and forecast time-to-failure.

If you are working on a specific asset, let me know:

• The operating environment (temperature, fluid type, or if it has external insulation)
• Whether you need a manual inspection workflow or a permanent wireless monitoring setup

I can recommend the most practical hardware and software combination for your project.