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APPROVED 10/13/2014 OC Board of Adjustment – 8/27/2014 Page 14 of 64 Rob Priester: One of the biggest issues we have and other gas companies have is outside damage or 1 third party damage. The width of the right of way and having a cleared and maintained right of way helps 2 us to protect against third party damage. 3 Matt Rhoads: And what about the separation between the existing pipelines? I believe they are 4 separated by about 10 feet. Does that help you protect the line as well? 5 Rob Priester: That is our proposed and again, that is above what the minimum standard would be. Both 6 minimum requirements from the code but yes that allows us to safely construct a secondary pipeline 7 adjacent to a new one. 8 Matt Rhoads: And will the project as proposed maintain the public health and safety? 9 Rob Priester: Yes. 10 Matt Rhoads: And as proposed will it adequately protect from explosion, rupture, collapse, fire or other 11 meniscus to public health? 12 Rob Priester: Safety is our top priority. We design all pipelines and operate all pipelines as safely and 13 efficiently as possible. Part 192 dictates as many of the regulations that dictate how we operate and how 14 we maintain our pipelines and we meet or exceed anything and everything that is in the code. 15 Matt Rhoads: So is that a yes. 16 Rob Priester: Yes. 17 Matt Rhoads: That is all I have for Mr. Priester unless the Board has questions. 18 Larry Wright: Board have questions for Mr. Priester? 19 David Blankfard: How often is the pig run done on the line? 20 Rob Priester: Integrity related questions, those are typically …. 21 Matt Rhoads: If you are okay with it, Andrew Moore may be better suited to answer those integrity 22 questions. 23 Andrew Moore: I am Andrew Moore and I have been sworn. The MI inspections are part of our Pipeline 24 Integrity Management program and we are required to perform some type of physical assessment of our 25 pipelines every seven years depending on the operating stress of the pipeline that sort of establishes the 26 frequency in which we have to do certain types of assessments so for a pipeline operating at a low to 27 moderate stress level, we would be required to perform an inline inspection maybe every 15 or 20 years. 28 For a pipeline operating at a higher stress level, it would be every 10 years, some type of inspection has 29 to be performed at least every seven as part of the Integrity Management Plan and also realize that the 30 Integrity Management Program is something that started in 2004 and these are supplemental 31 maintenance and inspection requirements that are above and beyond all the other inspection 32 maintenance requirements that the code has imposed since 1970 I guess. There is all sorts of annual 33 type maintenance that is performed and these are in addition to that. 34 David Blankfard: What is the pressure that this line will be running at? 35 Andrew Moore: It will be running at 800 psi. 36 David Blankfard: And what is the one that the 10 inch is running at? 37 Andrew Moore: 800. They will operate both at 800 psi. 38