New York Codes, Rules and Regulations › Title 16 - DEPARTMENT OF PUBLIC SERVICE › Appendices › Appendix 14-E

Current through Register Vol. 46, No. 28, July 10, 2024
Guidance on Determining High Consequence Areas and on Carrying
				out Requirements in the Integrity Management Rule
I. Guidance on Determining a High Consequence Area
To determine which segments of an operator's transmission
				pipeline system are covered for purposes of the integrity management program
				requirements, an operator must identify the high consequence areas. An operator
				must use the methods defined in paragraphs (1) or (2) of subdivision (f) of
				section 255.903  of this Part to identify a
				high consequence area. An operator may apply one method to its entire pipeline
				system, or an operator may apply one method to individual portions of the
				pipeline system. (Refer to Figure 1 below for a diagram of a high consequence
				area.)
FIGURE 1
II. Guidance on Assessment Methods and Additional Preventive
				and Mitigative Measures for Transmission Pipelines
(a) Table 1 below gives guidance to help an operator implement
				requirements on additional preventive and mitigative measures for addressing
				time dependent and independent threats for a transmission pipeline operating
				below 30 percent SMYS not in a High Consequence Area (
i.e.,
outside of potential impact circle) but located within a Class 3 or Class 4
				Location.
(b) Table 2 below gives guidance to help an operator implement
				requirements on assessment methods for addressing time dependent and
				independent threats for a transmission pipeline in a high consequence
				area.
(c) Table 3 below gives guidance on preventive and mitigative
				measures addressing time dependent and independent threats for transmission
				pipelines that operate below 30 percent SMYS, in high consequence areas.
Table 1
Preventive and Mitigative Measures for Transmission
				Pipelines Operating Below 30% SMYS not in HCAs but in Class 3 and 4
				Locations
(Column 4)
Existing Part 255
							 Requirements
Additional (to 255
							 requirements)
(Column 1)
(Column 2)
(Column 3)
Preventive and
							 Mitigative
Threat
Primary
Secondary
Measures
Eternal Corrosion
455-(Gen. Post 1971) 457-(Gen. Pre-1971) 459-Examination)
						  461-(Ext. Coating) 463-(CP) 465-(Monitoring) 467-(Elect isolation) 469-(Test
						  Stations) 471-(Test Leads) 473-(Interference) 479-(Atmospheric)
						  481-(Atmospheric) 485-(remedial) 705-(Patrol) 706-(Leak Survey) 711-(Repair -
						  gen.) 717-(Repair - perm.)
603-(Gen Oper'n) 613-(Surveillance)
For Cathodically Protected Transmission Pipeline: *
						  Performs semi-annual leak surveys. For Unprotected Transmission Pipelines or
						  for Cathodically Protected Pipe where Electrical Surveys are Impractical: *
						  Perform quarterly leak surveys
Internal
475-(Gen IC) 477-(IC monitoring) 485-(Remedial)
						  705-(Patrol)
53(a)-(Materials) 603-(Gen Oper'n)
* Perform semi-annual leak surveys.
Corrosion
706-(Leak Survey) 711-(Repair- gen.)
						  717-(Repair-perm.)
613-(Surveillance)
3rd Party Damage
103-(Gen. Design) 111-(Design factor) 317-(Hazard prot)
						  327-(Cover) 614-(Dam. Prevent) 616-(Public Education) 705-(Patrol) 707-(Line
						  markers) 711-(Repair-gen.) 717-(Repair-Perm)
615-(Emerg. Plan)
* Participation in state one-call system * Use of
						  qualified operator employees and contractors to perform marking and locating of
						  buried structures and in direct supervision of excavation work, AND * Either
						  monitoring of excavations near operator's transmission pipelines, or bi-monthly
						  patrol of transmission pipelines in class 3 and 4 locations. Any indications of
						  unreported construction activity would require a follow up investigation to
						  determine if mechanical damage occurred.
Table 2
Assessment Requirements for Transmission Pipelines in
				HCAs (Re-assessment intervals are the maximum allowed)
Re-Assessment Requirements (see
							 Note 3)
At or Above 50%
							 SMYS
At or Above 30% SMYS up to 50%
							 SMYS
Below 30%
							 SMYS
Baseline Assessment Method (See
							 Note 3)
Max Re-Assessment
							 Interval
Assessment
							 Method
Max Re-Assessment
							 Interval
Assessment
							 Method
Max Re-Assessment
							 Interval
Assessment
							 Method
7
CDA
7
CDA
Pressure
10
Pressure
Preventive and
Testing
Test or ILI or DA
Ongoing
Mitigative (P&M)
Measures
Repeat inspection cycle every 10 years
15 (See Note 1)
Pressure Test or ILI or DA (See Note 1)
(See Table 3), (See Note 2)
Repeat inspection
20
Pressure Test or ILI or DA
cycle every 15 years
Repeat inspection cycle every 20 years
7
CDA
7
CDA
In-Line
10
ILI or DA
Preventive and
Inspection
or Pressure Test
Ongoing
Mitigative (P&M)
Measures
Repeat inspection cycle every 10 years
15 (See Note 1)
ILI or DA or Pressure Test (See Note 1)
(See Table 3), (See Note 2)
Repeat inspection
20
ILI or DA or Pressure Test
cycle every 15 years
Repeat inspection cycle every 20 years
7
CDA
7
CDA
Direct
10
DA or ILI or
Preventive and
Assessment
Pressure Test (see Note 1)
Ongoing
Mitigative (P&M)
Measures
Repeat inspection cycle every 10 years
15 (See Note 1)
DA or ILI or Pressure Test (See Note 1)
(See Table 3), (See Note 2)
Repeat inspection
20
DA or ILI or Pressure Test
cycle every 15 years
Repeat inspection cycle every 20 years
Operator may choose to utilize CDA at year 14, then utilize
				ILI, Pressure Test, or DA at year 15 as allowed under ASME B31.8S
Operator may choose to utilize CDA at year 7 and 14 in lieu of
				P&M
Operator may utilize "other technology that an operator
				demonstrates can provide an equivalent understanding of the condition of line
				pipe"
Table 3
Preventive and Mitigative Measures Addressing Time
				Dependent and Independent Threats for Transmission Pipelines that Operate Below
				30% SMYS, in HCAs
Existing 255
							 Requirements
Additional (to 255 requirements)
							 Preventive
Threat
Primary
Secondary
and Mitigative
							 Measures
External Corrosion
455-(Gen. Post 1971) 457-(Gen. Post 1971)
						  459-(Examination) 46 l-(Ext. Coating) 463-(CP) 465-(Monitoring) 467-(Elect.
						  Isolation) 469-(Test Stations) 471-(Test Leads) 473-(Interference)
						  479-(Atmospheric) 481-(Atmospheric) 485-(Remedial) 705-(Patrol) 706-(Leak
						  Survev) 711-(Repair- gen) 717-(Repair - perm.)
603-(Gen. Oper) 613-(Surveillance)
For Cathodically Protected Transmission Pipelines: *
						  Perform an electrical survey (i.e. indirect examination tool/method) at least
						  every 7 years. Results are to be utilized as part of an overall evaluation of
						  the CP system and corrosion threat for the covered segment. Evaluation shall
						  include consideration of leak repair and inspection records, corrosion
						  monitoring records. exposed pipe inspection records, and the pipeline
						  environment. For Unprotected Transmission Pipelines or Cathodicallv Protected
						  pipe where Electrical Surveys are Impracticable: * Conduct Quarterly leak
						  surveys AND * Every 11/2 years, determine areas of active corrosion by
						  evaluation of leak repair and inspection records. corrosion monitoring records,
						  exposed pipe inspection records, and the pipeline environment.
Internal Corrosion
475-(Gen 1C) 477-(IC Monitoring) 485-(Remedial)
						  705-(Patrol) 706-(Leak Survey) 711-(Repair- gen) 717-(Repair - perm.)
53(a)-(Materials) 603-(Gen. Oper) 613-(Surveil)
* Obtain and review gas analysis data each calendar year
						  for corrosive agents from transmission pipelines in HCAs * Periodic testing of
						  fluid removed from pipelines. Specifically, once each calendar year from each
						  storage field that may affect transmission pipelines in HCAs. AND * At least
						  every 7 years, integrate data obtained with applicable internal corrosion leak
						  records, incident reports, safety related condition reports, repair records,
						  patrol records, exposed pipe reports, and test records.
3rd Party Damage
103-(Gen. Design) 111-(Design Factor) 317-(HazardProt)
						  327-(Cover) 614-(Dam. Prevent) 616-(Public Educat) 705-(Patrol) 707-(Line
						  Markers) 711-(Repair-gen.) 717-(Repair-perm.)
615-(Emer. Plan)
* Participate in state one-call system. * Use of
						  qualified operator employees and contractors to perform marking and locating of
						  buried structures and in direct supervision of excavation work. AND * Either
						  monitoring of excavations near operator's transmission pipelines, or bi-monthly
						  patrol of transmission pipelines in HCAs or class 3 and 4 locations. Any
						  indications of unreported construction activity would require a follow up
						  investigation to determine if mechanical damage occurred.