2. 1 Philip Sher Connecticut Department of Public Utility Control Gas Pipeline Safety Unit RepresentingNAPSR National Association of Pipeline Safety Representatives November 4, 2003 Direct Assessment

3. 2 NAPSR  NAPSR = National Association of Pipeline Safety Representatives  non-profit organization  state pipeline safety directors, managers, inspectors and technical personnel  to support, encourage, develop and enhance pipeline safety regulation  Founded on December 2, 1982

4. 3 Integrity Management Program Pipeline IMP = “a plan or system” “to handle or direct with a degree of skill” the “soundness” of a pipeline system

5. 4 We Need Integrity Management Bellingham, WA Carlsbad, NM Edison, NJ

6. 5 We Will Have Integrity Management

7. 6 Steps in Risk Management

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11. 10 ANSI Gas Piping Technology Committee & ANSI B31.8S Integrity Management Process.

12. 11 High Consequence Area – The Real World

13. 12 Integrity Assessment Methods 1. Smart pig 2. Pressure test 3. Direct assessment 4. Other (new technology )

14. 13 Smart Pigs  1 st smart pigs – mid 1960’s, primarily for the detection of wall thinning. Now other types of defects - cracks, coating disbondment, dents and gouges - are detectable  Smart pig digs have served to calibrate and validate smart pig results

15. 14 Smart Pigs  Smart pigs need  launchers & receivers  long radius bends  full opening valves  constant pipe diameter  Smart pigs may require interruption  25-30% of transmission pipelines are piggable

16. 15 Pressure Testing  Require taking pipeline out of service  Water removal can be difficult  Water can promote internal corrosion  Pressure testing can grow subcritical flaws into critical flaws  Pressure test provides limited information and limited evaluation of future performance

17. 16 Direct Assessment  ECDA =External Corrosion Direct Assessment  ICDA =Internal Corrosion Direct Assessment  SCCDA=Stress Corrosion Cracking Direct Assessment

18. 17 ECDA 4 Step Process  Step 1 - Pre Assessment  Step 2 - Indirect Examination  Step 3 - Direct Examination  Step 4 - Post Assessment

19. 18 Direct Assessment  Absolute need for DA  MUST be perfected  Must define parameters where it works  Must define parameters to evaluate it in use  Must develop body of knowledge and talent to utilize DA

20. 19 Tools of ECDA  Cathodic Protection Readings (CP)

21. 20 Tools of ECDA  Close Interval Survey (CIS)

22. 21 Tools of ECDA  Direct Current Voltage Gradient (DCVG)

23. 22 Tools of ECDA  C-Scan (The C-Scan mode or pulse-echo provides a planar view image at a specific depth. Illustrations of delaminations and void formation can be generated.)

24. 23 Tools of ECDA  Current Mapper

25. 24 Direct Assessment  Some DA tools are old and there is considerable experience  Some DA tools are new with little experience  The DA process is new incorporating old and new tools, old and new techniques, and significant new data integration and documentation

26. 25 Direct Assessment  Just as smart pig needed calibration and verification, DA will also need to be proven for the many conditions that may exist. that may exist.  DA must be repeatable  DA must have a high level of confidence  Operator must demonstrate compliance  Regulator must confirm compliance

27. 26 Reassessment Period  Original proposed reassessment period  Final reassessment period?

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29. 28 Ultimate Goal

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