New York Codes, Rules and Regulations › Title 16 - DEPARTMENT OF PUBLIC SERVICE › Chapter III - GAS UTILITIES › Subchapter C - Safety › Part 255 - Transmission And Distribution Of Gas › Transmission Pipeline Integrity Management › Section 255.927 - Internal corrosion direct assessment (icda)

Current through Register Vol. 46, No. 28, July 10, 2024
(a) Definition. Internal corrosion direct
					 assessment (ICDA) is a process an operator uses to identify areas along the
					 pipeline where fluid or other electrolyte introduced during normal operation or
					 by an upset condition may reside, and then focuses direct examination on the
					 locations in covered segments where internal corrosion is most likely to exist.
					 The process identifies the potential for internal corrosion caused by
					 microorganisms, or fluid with C02, 02, hydrogen sulfide or other contaminants
					 present in the gas.
(b) General
					 requirements. An operator using direct assessment as an assessment method to
					 address internal corrosion in a covered pipeline segment must follow the
					 requirements in this section and in ASME/ANSI B31.8S (as described in section
					 10.3 
					 of this Title), section
					 6.4 and
					 Appendix B2. The ICDA process described in this section applies only for a
					 segment of pipe transporting nominally dry natural gas, and not for a segment
					 with electrolyte nominally present in the gas stream. If an operator uses ICDA
					 to assess a covered segment operating with electrolyte present in the gas
					 stream, the operator must develop a plan that demonstrates how it will conduct
					 ICDA in the segment to effectively address internal corrosion, and must provide
					 notification in accordance with section
					 255.921(a)(4)
					 or
					 255.937(c)(4) 
					 of this Part.
(c) The ICDA plan. An
					 operator must develop and follow an ICDA plan that provides for preassessment,
					 identification of ICDA regions and excavation locations, detailed examination
					 of pipe at excavation locations, and post-assessment evaluation and monitoring.
(1) Preassessment. In the preassessment
					 stage, an operator must gather and integrate data and information needed to
					 evaluate the feasibility of ICDA for the covered segment, and to support use of
					 a model to identify the locations along the pipe segment where electrolyte may
					 accumulate, to identify ICDA regions, and to identify areas within the covered
					 segment where liquids may potentially be entrained. This data and information
					 includes, but is not limited to:
(i) all data
					 elements listed in Appendix A2 of ASME/ANSI B31.8S;
(ii) information needed to support use of a
					 model that an operator must use to identify areas along the pipeline where
					 internal corrosion is most likely to occur. (See subdivision [a] of this
					 section.) This information, includes, but is not limited to, location of all
					 gas input and withdrawal points on the line; location of all low points on
					 covered segments such as sags, drips, inclines, valves, manifolds, dead-legs,
					 and traps; the elevation profile of the pipeline in sufficient detail that
					 angles of inclination can be calculated for all pipe segments; and the diameter
					 of the pipeline, and the range of expected gas velocities in the
					 pipeline;
(iii) operating
					 experience data that would indicate historic upsets in gas conditions,
					 locations where these upsets have occurred, and potential damage resulting from
					 these upset conditions; and
(iv)
					 information on covered segments where cleaning pigs may not have been used or
					 where cleaning pigs may deposit electrolytes.