For a new or existing pipeline segment to be eligible for operation at the alternative maximum allowable operating pressure calculated under Sec. 192.620, a segment must meet the following additional construction requirements. Records must be maintained, for the useful life of the pipeline, demonstrating compliance with these requirements: ------------------------------------------------------------------------
To address this construction The pipeline segment must meet this
(a) Quality assurance............. (1) The construction of the pipeline
(1) The construction of the pipeline
segment must be done under a
quality assurance plan addressing
pipe inspection, hauling and
stringing, field bending, welding,
non-destructive examination of
girth welds, applying and testing
field applied coating, lowering of
the pipeline into the ditch,
padding and backfilling, and
hydrostatic testing.
(2) The quality assurance plan for
applying and testing field applied
coating to girth welds must be:
(i) Equivalent to that required
under Sec. 192.112(f)(3) for pipe;
and
(ii) Performed by an individual with
the knowledge, skills, and ability
to assure effective coating
(1) All girth welds on a new
pipeline segment must be non-
destructively examined in
accordance with Sec. 192.243(b)
(1) Notwithstanding any lesser depth
of cover otherwise allowed in Sec.
192.327, there must be at least 36
inches (914 millimeters) of cover
or equivalent means to protect the
pipeline from outside force damage.
(2) In areas where deep tilling or
other activities could threaten the
pipeline, the top of the pipeline
must be installed at least one foot
below the deepest expected
(1) The pipeline segment must not
have experienced failures
indicative of systemic material
defects during strength testing,
including initial hydrostatic
testing. A root cause analysis,
including metallurgical examination
of the failed pipe, must be
performed for any failure
experienced to verify that it is
not indicative of a systemic
concern. The results of this root
cause analysis must be reported to
each PHMSA pipeline safety regional
office where the pipe is in service
at least 60 days prior to operating
at the alternative MAOP. An
operator must also notify a State
pipeline safety authority when the
pipeline is located in a State
where PHMSA has an interstate agent
agreement, or an intrastate
pipeline is regulated by that
(1) For a new pipeline segment, the
construction must address the
impacts of induced alternating
current from parallel electric
transmission lines and other known
sources of potential interference
with corrosion control.------------------------------------------------------------------------ [72 FR 62176, Oct. 17, 2008]