INSUS learns how H₂S, CO₂, chloride, pH, temperature, flow and inhibitor dosing have related to measured corrosion on your own pipeline, and predicts internal corrosion rate between ILI and coupon campaigns. Integrity engineers keep the programme.
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Corrosion rate predicted between ILI and coupon campaigns.
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Uses H₂S, CO₂, chloride, pH, flow and inhibitor data you already keep.
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Advisory only. Never replaces inspection or regulatory programmes.
The problem
Internal corrosion is a major integrity threat for natural gas pipelines, yet it is typically managed through periodic ILI runs and coupon monitoring, both point-in-time and location-specific. Between campaigns, H₂S, CO₂, chloride, pH, temperature, flow and inhibitor dosing keep interacting in ways simple models track poorly. Inspection scope and integrity spend then tend to follow uniform schedules rather than the conditions each segment has actually experienced.
The shift
Inline inspection, coupon monitoring and the regulated integrity programme all stay in place. What changes is that the time between campaigns is covered by a corrosion-rate prediction built on the pipeline's own process and inspection history.
Today
With INSUS
How it works
This fits OptiStudio as integrity decision support above process SCADA and the integrity management system. Access is read-only. It never replaces inspection, coupons or regulatory programmes.
Connect
Connect read-only to process SCADA and historian for temperature and flow, gas composition for H₂S and CO₂, water chemistry for chloride and pH, chemical treatment records for inhibitor dosing, and the integrity management system for ILI and coupon history.
Understand
The model learns how H₂S, CO₂, chloride, temperature, pH, flow rate and inhibitor dosing have related to the corrosion rates confirmed by inspection and coupon data across this pipeline's own operating history.
Predict
Predict internal corrosion rate from the process chemistry variables as data updates, using a model calibrated to this pipeline's own inspection and coupon history rather than a generic corrosion table.
Advise
Flag monitored segments with elevated predicted corrosion rate to help prioritise ILI scope and integrity spend, and show the predicted effect of current inhibitor dosing. The integrity team reviews every recommendation before it informs any plan.
Verify
Compare predictions with ILI and coupon results as they arrive. Accuracy is tracked, flagged segments are checked against subsequent findings, and the model is refined against the pipeline's own history.
Getting started
For midstream gas pipelines where internal corrosion is managed between ILI and coupon campaigns. Delivered through OptiStudio as integrity decision support. Expert Services can help with data assessment and validation. Advisory and read-only. Never replaces inspection.
Related for midstream
Pipeline corrosion rate prediction sits beside compressor network optimisation and EU methane compliance on the same transmission system.
Internal corrosion is driven continuously by process chemistry, but confirmed only at ILI and coupon intervals. This use case predicts corrosion rate between campaigns to help prioritise inspection for integrity engineer review.
Historical H₂S, CO₂, chloride, temperature, pH, flow rate and inhibitor dosing data, together with corresponding inline inspection and coupon results. No new sensors: it uses chemistry variables a midstream operator already monitors.
No. It helps prioritise inspection scope. It does not replace ILI, coupon monitoring, the integrity management system or any regulatory-mandated integrity programme.
No. It predicts internal corrosion rate and advises prioritisation. Access is read-only. Closed-loop control is not part of this use case.
Through OptiStudio as integrity decision support. Expert Services can support data assessment, integration and validation with your integrity team.
Peer-reviewed work has shown that internal corrosion rate can be predicted from process chemistry on gas pipelines. Those accuracy figures belong to the studied pipelines, not to every asset, and not to us. Value is measured against your own inspection-confirmed history.
It needs process chemistry and inspection or coupon data already being collected. Accuracy is specific to each pipeline's chemistry and corrosion mechanism. Local factors such as where water collects are not captured by process chemistry alone.
Midstream · Pipeline integrity
A back-test on one segment and the inspections you already ran will show how well process chemistry already predicts the corrosion rate your programme later confirmed.
