Piping Material Specification and related activities

A: A. Raising level masks increased inlet turbulence and raises re-entrainment risk at the weir. B. Velocity increase compounds shear at the inlet device and worsens carryover despite unchanged diameter. C. Full rejection ignores that roughness affects ΔP more than phase separation and delays operations without risk ranking. D. Formal MOC with momentum check contains the risk by proving inlet device limits aren't exceeded and logging the deviation.

A: A. Counting CA inflates allowable stress margin and hides future thinning under normal operation. B. Flange class limits don't remove the need to size pipe wall independently for pressure. C. Internal corrosion is a primary driver for CA in hydrocarbon service. D. Deducting CA forces the pressure design to stand on required thickness alone so loss over life doesn't erode containment.

A: A. Insulation follows heat loss and personnel protection, not material class. B. Identical size doesn't mean identical metallurgy or pressure class. C. Valve datasheets don't govern upstream line class selection. D. Misaligned spec breaks can put a lower-rated body in higher severity service, which is an audit red flag.

A: A. Sulfidation needs much higher metal temperature than this service sees. B. CS doesn't crack from chlorides without tensile stress and much higher temperature. C. CO2 corrosion dominates only when H2S is absent or very low. D. Iron sulfide films form in wet sour service and dictate corrosion behavior at these conditions.