Asset Integrity Management

Pipeline & Storage Tank Integrity Management

API 1160 / API 653 / PHMSA-compliant integrity programmes — driven by ILI, direct assessment, and damage-mechanism science

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Technical overview

Pipeline & Storage
Tank Integrity Management

Pipeline Integrity Management Programmes (PIMP) and Tank Integrity Management Programmes (TIMP) translate API 1160 (liquid pipelines), API 1163 (ILI qualification), API 570 (in-service piping), API 653 (above-ground storage tanks), and PHMSA 49 CFR Parts 192 (gas) / 195 (liquid) into asset-specific inspection, monitoring, repair, and re-rating programmes. PHMSA's mega-rule (Gas Transmission Pipeline Safety, Phase 1 effective July 2020, Phase 2 effective May 2023, Phase 3 in 2025) significantly expanded HCA (High Consequence Area), MCA (Moderate Consequence Area), and assessment-method requirements following the San Bruno 2010 (8 fatalities), Marshall Michigan 2010 (Enbridge dilbit spill), and Aliso Canyon 2015 events. Modern PIMP execution combines ILI-tool selection (MFL, UT, EMAT, calliper, geometry — typically run on 5–7 year intervals depending on threat profile), direct assessment for un-piggable segments (ECDA for external corrosion, ICDA for internal, SCCDA for stress-corrosion cracking), API 653 out-of-service / in-service tank inspection with bottom-plate MFL and shell UT scanning, and increasingly fibre-optic distributed sensing (DAS / DTS) for leak and ground-movement detection.

Pipeline & Storage Tank Integrity Management — Overview
Engineering process

Pipeline & Storage Tank Integrity Management workflow

Pipeline Threat Assessment

Catalogue threats per ASME B31.8S / API 1160 — external corrosion, internal corrosion, SCC, manufacturing defects, construction / fabrication, equipment, third-party damage, incorrect operations, weather / outside force; build pipeline threat register.

ILI Programme Design

Design inline inspection programme — MFL (corrosion / pitting), UT (wall loss), EMAT (SCC), Caliper (geometry), IMU (strain); specify ILI tool capability (sizing accuracy, POD, POI); align with API 1163 ILI Systems Qualification.

Defect Assessment & MAOP Verification

Assess ILI-detected defects per ASME B31G / ModifiedB31G / RSTRENG; calculate failure pressure and predicted burst; verify MAOP per Subpart H (PHMSA 49 CFR 192/195); integrate with hydrostatic test programme.

Cathodic Protection & Corrosion Programme

Design CP system per NACE SP 0169 — sacrificial anode or impressed current; specify CP monitoring (CIPS, DCVG, ACVG); design internal corrosion programme — chemical inhibition, pigging, biocide treatment; align with NACE / API standards.

Pipeline ECDA & ICDA Programme

Design External Corrosion Direct Assessment (ECDA) per NACE SP 0502 with indirect inspection, direct examination, post-assessment; design Internal Corrosion Direct Assessment (ICDA) per NACE SP 0206; align with high-consequence area (HCA) coverage.

IMP Programme Documentation & Audit

Author Integrity Management Programme per ASME B31.8S / API 1160 / PHMSA 49 CFR 192/195 Subpart O; prepare for PHMSA inspection / FERC audit; maintain inspection records, calculation files, and MOC integration.

Pipeline & Storage Tank Integrity Management — Scope
Scope of work

Every deliverable — from basis to handover

Complete Pipeline & Storage Tank Integrity Management scope — every calculation, drawing, specification, and construction support activity.

Threat identification per API 1160 — external corrosion, internal corrosion, SCC, manufacturing defect, third-party damage, weather/outside force
HCA / MCA / Class Location designation per PHMSA Mega-Rule for assessment-method gating
ILI tool selection — MFL (metal-loss), UT-WT (precise wall thickness), EMAT (SCC), geometry (dent), calliper (ovality)
ILI qualification per API 1163 — POD, POI, sizing tolerance, run validation
Direct assessment — ECDA (external corrosion), ICDA (internal), SCCDA (stress-corrosion cracking) for un-piggable
API 653 tank inspection — bottom MFL, shell UT scanning, roof / floating-roof inspection
Anomaly assessment per API 579 FFS Level 1/2/3 with pressure-reduction (PR) and repair-prioritisation logic
Fibre-optic distributed sensing (DAS / DTS) for leak detection and ground-movement monitoring
Cathodic protection programme per NACE SP0169 with annual CP survey
Integrity Management Plan (IMP) with re-baseline trigger matrix and 5-year re-assessment cycle
Engineering outcomes

Outcomes of Pipeline & Storage Tank Integrity Management

Pipeline Failure & Leak Prevention
  • Lowers release frequency and consequence
  • Identifies high-risk segments for inspection
  • Reinforces leak detection capability
  • Supports HCA-driven prioritisation
ASME B31.8S / API 1160 / PHMSA Defence
  • Tracks to API 1160, 653, 570
  • Documents PHMSA 49 CFR 195 compliance
  • Supports OISD-STD-141 (India)
  • Withstands regulator and AHJ audit
ILI Programme & MAOP Assurance
  • Optimises inspection scope and frequency
  • Improves anomaly response
  • Tightens corrosion control programmes
  • Supports right-of-way management
Dig & Repair Cost Targeting
  • Defers full replacement through targeted repair
  • Reduces release cleanup and litigation cost
  • Optimises inspection capex
  • Eases premium pressure on transmission risk
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