October 18, 2012 08:00 - 05:00

In spite of all the hype about Near Neutral pH and High pH (Classical) SCC, there are no borders that separate these threats as some people have speculated. A classical or high pHdSCC failure first occurred in the mid 1960's on a high pressure gas transmission pipeline that was located in Natchitoches, Louisiana. An explosion with fatalities resulted from a natural gas release during this failure. Conversely near neutral (Transgranular) SCC occurred in the mid 1980's in Canada. This type of corrosion exhibits transgranular morphology and has been known to have corrosion associated with it on the pipe surface. Whereas high pH SCC tends to have tighter cracks it typically does not have corrosion associated with it.
Yes, there are notable differences between the two types of SCC. And, yes the preponderance of transgranular happens to occur on the north side of the USA/Canadian border. Conversely, the majority of high pH SCC has occurred on the US side of the border. Neither type requires a passport to visit either side of this arbitrary border. Since the mid 1960's,research and hundreds of papers have been written on this difficult threat and how to manage it.

Does SCC Constitute a High Level SCC Threat to Your Pipeline System?
Then, you need to attend this one half day seminar to understand and recognize the issues that cause these threats.
Some of the factors that initiate SCC are:operating stress, operating temperature, electrolyte, age of pipeline, and coating type.

Pipelines susceptible to high pH SCC:
- Operating stress exceeds 60% of specified minimum yield strength (SMYS)
- Operating temperature exceeds 100 °F
- Segment is less than 20 miles downstream from a compressor station
- Age of the pipeline is greater than 10 years
- Coating type is other than fusion-bonded epoxy (FBE)
Pipelines susceptible to neutral or low pH SCC:
- Dilute near neutral pH electrolyte
- Ground or lower temperatures
- Coatings types that shield

½ day seminar – offered
July 25th 8 A.M. – 12 P.M.
Or
July 25th 1 P.M. – 5 P.M.

Outline:
History of SCC
Environmentally Assisted Crack (ECA)
Classical high pH
Transgranular low pH

Stresses

Field Assessment

Recommended Practices

SCC Management
Investigative Digs
Hydro
ILI
DA

Methods for Calculating SCC

Review, Evaluate and Document

Joe Pikas
EXPERIENCE (45 Years in the Control of Pipeline and Facility Corrosion)
Technical Toolboxes - 2012 to Present
HDR|Schiff – Senior Corrosion Consultant 2011 – 2012
Mistras IMPro Technologies – Vice President of Pipeline Integrity 2008 - 2010
Matcor – Vice President of Houston Operations 2002 – 2008
Williams Gas Pipelines (Transco) – Pipeline, Corrosion Control, Risk, Integrity, GIS, Pigging
1966-2002

AWARDS

NACE Distinguished Service Award for 2009.
Received industry award in 2002 with the Utmost Respect and Gratitude from AGA, GTI, INGAA, NACE, OPS, and PRCI International.
Received Long Neck Award from Big Inch Marine in the research and development for pre-fabricated isolating flanges.
Received Brandon Award for Outstanding Service from the Coating Society of the Houston Area

Seminar will be given at two separate times on October 18, 2012

8 a.m.-12:00 p.m.
or
1 p.m. - 5:00 p.m.

$ 199.00 (USD)