Structural Integrity Assessment of Assets

We assist our customers to have safe and reliable operations, mitigate risks, enhance uptime, reduce downtime, and assist them for overall productivity increase of their asset utilization.

Increasingly, we are assisting our customers in implementation of IIoT, Cloud, AI/ML based digital twin development.

1. Pipeline Study

• Pipeline Geometry and Material: Diameter, wall thickness, grade, age, type, specified material properties (yield andtensile strength, toughness)&pipeline design code
• Pipeline operational characteristics: Operating pressure andtemperature, temperature and pressure cycles
• Type of product carried by the pipeline and pipeline environments (internal and external)
• Details of Corrosion protection
• History of the pipeline (from manufacturing and constructionthrough to operation)
• Past history of failures and repairment/ replacements done.
• Intended future operating conditions.

2. Considerations for stresses on the pipelines

• Loads acting on the length of the pipeline containing a defect.
• If these loads will change in future
• Considerations of circumstances that may result in overpressure (e.g. surged. Are
• Cyclic loads on the pipeline
• Failure stress

3. Review of Inspection Method used

• Type of inspection methods used – MFL/ UT and any other surveys.
• Minimum sizing threshold and what are the sizing tolerances and accuracies of the inspection methods.

4. Review of Defects identified during ILI (in-Line inspection)

• Cause for the identified defects (due to bacterial growth, corrosion, fluid constituents etc.)
• Dimensions of the defects reported (length, width, depth, acuity,profile)
• Types of defect (metal-loss, dent, gouge, girth weld defect,crack, laminations, blister)
• Potential for defect growth

5. Location Overview

• Location accuracies (depending upon agency, and pigging equipment); determine dig verification location;

6. Anomalies assessment Overview

• Level 1 assessment will be carried out for all the identified anomalies considering failure stress, acceptable safety factor and FCA
• If level 1 assessment shows unacceptable anomalies, these defects will be identified as inputs for dig verification and additional NDE
• The identified defect locations will be superimposed on the actual pipeline map for providing locations for dig verification
• Level 2 assessment will be carried out based on the dig verification and additional NDE’s

7. Identifying potential for SCC by considering the following

• The operating stress exceeds 60%of the SMYS
• The operating temperature hashistorically exceeded 38ºC
• Pipeline segment is less than or equalto 32 km downstream from acompressorstation
• Age and coating type
• Initial identification of candidate sites foradditional indirect surveys and subsequent directexaminations (if required)

8. Identifying consequences for the anomalies

• Consequences of failure for identified defects will be correlated with pipeline location class (population density) and risk-based inspection or time-based approach will be considered for mitigations.
• Expected failure mode (running fracture, leak, rupture)

9. Integrity Assessment

• Predict degradation mode and rate of degradation
• Predictive Models – Operational data
• Historical inspection data
• Future degradation rates
• Determine Remnant life
• Corrosion tolerance and degradation rate

10. Rating the pipeline for MAOP (maximum allowable operating pressure) based on

• Allowable design pressure of the weakest element considering the worst defect remaining in the pipeline
• Maximum safe pressure to which a pipeline should be subjected.
• Consideration of connected lines

11. Future inspection/ remedial actions &recommendations

• External corrosion
• Coating rehabilitation
• CP performance
• Internal corrosion
• Operational mitigation – inhibition, batching, dew point etc
• External welded sleeves
• Sectional replacement – interim temporary repair – clamps, welded sleeves etc