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Experience with Stress Corrosion Cracking (SCC)

Experience with Stress Corrosion Cracking (SCC). Scott Davis – Director of Pipeline Integrity and Facilities Engineering. Outline. KMP Liquids Pipelines July 30, 2003 Failure Repair and Start-up Sequence SCC Investigation Strategy SCC Investigation Status and Results.

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Experience with Stress Corrosion Cracking (SCC)

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  1. Experience with Stress Corrosion Cracking (SCC) Scott Davis – Director of Pipeline Integrity and Facilities Engineering

  2. Outline • KMP Liquids Pipelines • July 30, 2003 Failure • Repair and Start-up Sequence • SCC Investigation Strategy • SCC Investigation Status and Results

  3. KMEP Liquids Pipelines PACIFIC PACIFIC Mid Con CALNEV PACIFIC KMCO2 PLANTATION Products Pipelines Products Pipeline Terminals Transmix Facilities CO2 Pipelines Terminals CFPL

  4. 8” Tucson to Phoenix Release Location

  5. July 30, 2003 Failure • Approximately 13:09 line failure • SCADA alarm and Controller shutdown within 3 minutes • Operators dispatched and line isolated • Line excavated and exposed

  6. Repair and Start-up Sequence • Visual examination, suspected seam weld failure • Entire joint replaced by August 1, 2003 • Line re-started at 50% of MOP (~34% SMYS)

  7. Pressure Test Protocol • Metallurgist identified SCC on August 8, 2003 • Line shut down for further testing • Pressure test in 2 sections • “Spike” test of 1 hour at 139% of MOP • 8 hours at 125% of MOP • Testing commenced on August 20, 2003 • One test successful

  8. Pressure Test Failure • 2nd test unsuccessful • Failedin 1st minute at 139% MOP • 40’ from original failure • Intermittent SCC cluster length 6” • SCC ranged from 50-86% wt

  9. Return to Operation • Bypassed 8” pipe near failure on August 24 • Replaced 5400 feet of pipe in the immediate vicinity • Successful pressure test of section 2 • Line restarted on September 12, 2003 • Currently operating at 50% MOP • Increasing pressure dependant on results of SCC investigation

  10. High pH SCC • Still requires • Environment that is conducive to SCC • Susceptible pipeline material • Tensile stress in the pipeline steel • Differences: • No surface corrosion products • CP is adequately protecting the steel • Higher published stress threshold

  11. SCC InvestigationStrategy • Gather and investigate pipeline data • Develop algorithm to predict SCC likelihood • Complete case study on removed 5400’ • Predict terrain conditions conducive to SCC • Conduct field geotechnical, CIS, and PCM • Select locations for excavations • Conduct field excavations • Reintegrate excavation findings

  12. SCC InvestigationStatus and Results • MPI conducted on 5400’ of removed 8” • SCC found in pressure test failure joint • SCC found in 1 joint approx. 1800’ upstream • Field surveys have been completed • Finalizing excavation locations • Anticipated completion prior to year end

  13. Contact Information Scott P. Davis Director – Pipeline Integrity and Facility Engineering Kinder Morgan Energy Partners 1100 Town & Country Drive Orange, California 92868 E-mail: daviss@kindermorgan.com

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