1\. Pipeline Safety Advisory Bulletin - ADB-03-05 - October 8, 2003

> • Review Bulletin with operator, if operator is not familiar with.
>
> • Reference also Baker Stress Corrosion Cracking Study at:
> http://primis.phmsa.dot.gov/iim/pdfs/SCC_Report-Final_Report_with_Database.pdf

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2\. Has the pipeline system ever experienced SCC (in service, out of
service, leak, non-leak)?

• Type of SCC (high pH or low/near neutral pH)?

> • What are the known risk indicators that may have contributed to the
> SCC?

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3\. Does the operator have a written program in place to evaluate the
pipeline system for the presence of SCC? If no, have operator explain.
If operator has not considered SCC as a possible safety risk, go to #10.

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4\. Has/does the operator evaluate the pipeline system for the presence
of SCC risk indicators?

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5\. Has the operator identified pipeline segments that are susceptible
to SCC?

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6\. If conditions for SCC are present, are written inspection,
examination and evaluation procedures in place?

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7\. Does the operator have written remediation measures in place for
addressing SCC when discovered?

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8\. What preventive measures has the operator taken to prevent
recurrence of SCC?

• Modeling?

> • Crack growth rate?
>
> • Comparing pipe/environ./cp data vs. established factors?
>
> • Other?

• Hydrotest program?

• Intelligent pigging program?

> • Pipe re-coating?
>
> • Operational changes?
>
> • Inspection program?
>
> • Other?

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9\. Does the operator incorporate the risk assessment of SCC into a
comprehensive risk management program?

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**Continue below for those operators who have not considered SCC as a
possible safety risk.**

10\. Does the operator know of pipeline and right of way conditions that
would match the risk indicators for either classical or non-classical
SCC? See typical risk indicators below.

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**High pH (Classical) SCC Potential Risk Indicators**

• Known SCC history (failure, non-failure, in service, and during
testing)

> • Pipeline and Coating Characteristics
>
> • Steel grades X-52, X-60, X-65, X-70, and possibly X-42
>
> • Age \>= 10 years
>
> • Operating stress \> 60% smys
>
> • Pipe temperature \>100 deg. F (typically \< 20 miles d/s of
> compression)
>
> • Damaged pipe coating
>
> • Soil Characteristics
>
> • Soil pH range: 8.5 to 11
>
> • Alkaline carbonate/bicarbonate solution in the soil
>
> • Elevated soil temperature contributing to elevated pipe temperature
>
> • Polarized cathodic potential range: -600 to -750 mV, Cu/CuSO4

**Low or Near-Neutral pH (non-Classical) SCC Potential Risk Indicators**

• Known SCC history (failure, non-failure, in service, and during
testing)

> • Pipeline and Coating Characteristics
>
> • Steel grades X-52, X-60, X-65, X-70, and possibly X-42
>
> • Age \>= 10 years
>
> • Frequently associated with metallurgical features, such as
> mechanical damage, longitudinal seams, etc.
>
> • Protective coatings that may be susceptible to dis-bondment
>
> • Any coating **other than** correctly applied fusion bonded epoxy,
> field applied epoxies, or coal tar urethane . . .
>
> • Coal tar
>
> • Asphalt enamels
>
> **•** Tapes
>
> • Others
>
> • Soil Characteristics
>
> • Soil pH range: 4 to 8
>
> • Dissolved CO2 and carbonate chemicals present in soil
>
> • Organic decay
>
> • Soil leaching (in rice fields, for example)
>
> • "Normal" cathodic protection readings (dis-bonded coating shields
> the pipe from cp current)