(a) An operator must use API RP 80 (incorporated by reference, see Sec. 192.7), to determine if an onshore pipeline (or part of a connected series of pipelines) is an onshore gathering line. The determination is subject to the limitations listed below. After making this determination, an operator must determine if the onshore gathering line is a regulated onshore gathering line under paragraph (b) of this section.
(1) The beginning of gathering, under section 2.2(a)(1) of API RP 80, may not extend beyond the furthermost downstream point in a production operation as defined in section 2.3 of API RP 80. This furthermost downstream point does not include equipment that can be used in either production or transportation, such as separators or dehydrators, unless that equipment is involved in the processes of ``production and preparation for transportation or delivery of hydrocarbon gas'' within the meaning of ``production operation.''
(2) The endpoint of gathering, under section 2.2(a)(1)(A) of API RP 80, may not extend beyond the first downstream natural gas processing plant, unless the operator can demonstrate, using sound engineering principles, that gathering extends to a further downstream plant.
(3) If the endpoint of gathering, under section 2.2(a)(1)(C) of API RP 80, is determined by the commingling of gas from separate production fields, the fields may not be more than 50 miles from each other, unless the Administrator finds a longer separation distance is justified in a particular case (see 49 CFR Sec. 190.9).
(4) The endpoint of gathering, under section 2.2(a)(1)(D) of API RP 80, may not extend beyond the furthermost downstream compressor used to increase gathering line pressure for delivery to another pipeline.
(b) For purposes of Sec. 192.9, ``regulated onshore gathering line'' means:
(1) Each onshore gathering line (or segment of onshore gathering line) with a feature described in the second column that lies in an area described in the third column; and
(2) As applicable, additional lengths of line described in the fourth column to provide a safety buffer: ----------------------------------------------------------------------------------------------------------------
Type Feature Area Safety buffer----------------------------------------------------------------------------------------------------------------A.................................... --Metallic and the MAOP Class 2, 3, or 4 None.
produces a hoop stress location (see Sec.
of 20 percent or more 192.5).
of SMYS. If the stress
level is unknown, an
operator must
determine the stress
level according to the
applicable provisions
in subpart C of this
part.
--Non-metallic and the
MAOP is more than 125
psig (862 kPa).
B.................................... --Metallic and the MAOP Area 1. Class 3 or 4 If the gathering line
produces a hoop stress location. is in Area 2(b) or
of less than 20 Area 2. An area within 2(c), the additional
percent of SMYS. If a Class 2 location the lengths of line extend
the stress level is operator determines by upstream and
unknown, an operator using any of the downstream from the
must determine the following three area to a point where
stress level according methods:. the line is at least
to the applicable (a) A Class 2 location. 150 feet (45.7 m) from
provisions in subpart (b) An area extending the nearest dwelling
C of this part. 150 feet (45.7 m) on in the area. However,
--Non-metallic and the each side of the if a cluster of
MAOP is 125 psig (862 centerline of any dwellings in Area 2
kPa) or less. continuous 1 mile (1.6 (b) or 2(c) qualifies
km) of pipeline and a line as Type B, the
including more than 10 Type B classification
but fewer than 46 ends 150 feet (45.7 m)
dwellings. from the nearest
(c) An area extending dwelling in the
150 feet (45.7 m) on cluster.
each side of the
centerline of any
continous 1000 feet
(305 m) of pipeline
and including 5 or
more dwellings.---------------------------------------------------------------------------------------------------------------- [Amdt. 192-102, 71 FR 13302, Mar. 15, 2006]