Frequently-Asked Questions (FAQ)

FAQ Topical Categories

• General (12)
• Rule Basics (2)
• Rule Applicability (5)
• Time Periods (4)
• Integrity Management Programs (9)
• HCA Identification (36)
• Threat/Risk Analysis (7)
• Identification of Threats (1)
• Data Integration (4)
• Risk Analysis and Prioritization (6)
• Specific Threats (3)
• Assessment (15)
• Baseline Assessment Plan (BAP) (3)
• Assessment Methods (28)
• Continual Assessment and Evaluation (11)
• Remediation (16)
• Preventive and Mitigative Measures (5)
• Performance Measures (5)
• Record Keeping (3)
• Management of Change (MOC) (1)
• Regulatory and External Interaction (2)
• Communication Plan (1)
• Notification (7)
• Inspection (3)
• Enforcement (3)
• State Agencies and Intrastate Pipelines (2)
• Exceptional Performance Deviations (2)

• General [Top] [Bottom]
  • FAQ-159. What constitutes an "incident" of the kind for which operators implementing performance-based programs must evaluate for implications to their pipelines and IM programs (192.913(b)(1)(v)? [03/09/2005]
  • FAQ-6. Does the rule apply to more than line pipe? [11/03/2004]
  • FAQ-4. Is integrity management simply inspection of pipe condition? [08/17/2004]
  • FAQ-11. Who will be held accountable for implementing Integrity Management requirements in a case where an operator transfers pipeline assets to another company but retains responsibility, by contract, for maintenance and integrity management activities until some later date? [06/29/2004]
  • FAQ-161. Can prior assessments be relied upon to meet the requirement that operators begin assessment activities by June 17, 2004? [05/26/2004]
  • FAQ-1. What are the Pipeline and Hazardous Materials Safety Administration's objectives for the Integrity Management rule? [05/19/2004]
  • FAQ-2. Who must comply with the rule? [05/19/2004]
  • FAQ-3. Does the rule apply to operators of transmission pipelines for gases other than natural gas? [05/19/2004]
  • FAQ-9. Does the rule apply to gathering and other low-stress lines? [05/19/2004]
  • FAQ-10. If a pipeline subject to 192 Subpart O is sold, does the new operator "inherit" integrity management plans and deadlines from the original operator? [05/18/2004]
  • FAQ-155. In several places, the rule requires that operators follow Appendices in ASME/ANSI B31.8S. The title of both Appendices A and B in the standard indicate they are non-mandatory. Must the requirements in these Appendices be followed verbatim? [05/05/2004]
  • FAQ-12. If a pipeline transports both gas and liquids (e.g., some off shore lines), does the hazardous liquid integrity management rule or the gas integrity management rule apply? [02/20/2004]
• Rule Basics [Top] [Bottom]
  • FAQ-244. What is the OPS position with regard to implementation of "should" statements in industry standards that are invoked by the rule? [01/11/2006]
  • FAQ-167. How should the operator address "must" and "shall" statements in the standard? In some cases, the standard provides for an alternative action if the "must" and "shall" statements are not implemented. [06/29/2004]
• Rule Applicability [Top] [Bottom]
  • FAQ-150. What requirements must an operator meet if there are no high consequence areas on any of its transmission pipelines. [06/20/2005]
  • FAQ-84. The Integrity Management Program portion of the rule [192.907] applies to all portions of a pipeline system that are in HCAs, including compressor stations, metering stations, and other equipment. What must an operator do to comply with the rule for these facilities? [03/04/2005]
  • FAQ-190. How do LDC operators and/or regulators define "distribution center"? (necessary to determine amount of transmission line.) [06/29/2004]
  • FAQ-188. Are jurisdictional gathering lines covered? [06/09/2004]
  • FAQ-7. Do the requirements of the rule apply to "idle" pipe? [02/20/2004]
• Time Periods [Top] [Bottom]
  • FAQ-237. When must the baseline assessment be completed for piping installed after the effective date of the rule? [12/12/2006]
  • FAQ-124. The rule includes many requirements that do not have specified time periods for completion. Examples include gathering and integrating data and information on the entire pipeline, updating risk assessments when the results of assesments are available and identifying HCAs for new pipe. How soon must these actions be completed? [03/09/2005]
  • FAQ-196. Is there any time limit between step 2 and step 3 in the ECDA process (indirect exam and direct exam)? [01/14/2005]
  • FAQ-179. How long does an operator that has had no HCAs, and therefore no integrity management program, have to develop an integrity management program after it discovers a new HCA? [08/19/2004]
• Integrity Management Programs [Top] [Bottom]
  • FAQ-238. What documentation must I include in my IM program to describe a "process" required by the rule? [04/18/2007]
  • FAQ-239. How much detail must I include when the rule requires that I "justify" an action or decision? [08/02/2006]
  • FAQ-202. DA vendors offer processes that include proprietary analysis techniques (similar to how ILI vendors use algorithms to classify anomalies). If my IMP written plan has to document my process for CIS/DCVG/etc. acceptance limits, how can I use vendors that wouldn’t give away their intellectual property? [12/06/2004]
  • FAQ-140. What level of detail does OPS expect to see in initial IM frameworks for each of the required program elements? [06/09/2004]
  • FAQ-72. When must the Baseline Assessment Plan and Framework be completed? [05/20/2004]
  • FAQ-73. Will OPS prepare templates for Baseline Assessment Plans or Integrity Management Program Frameworks that operators can use? [05/20/2004]
  • FAQ-76. What is an Integrity Management Program? [05/20/2004]
  • FAQ-74. What is the difference between an acceptable Integrity Management Framework and a fully developed Integrity Management Program? [05/18/2004]
  • FAQ-85. Can pipeline integrity management programs required by Subpart O be part of broader corporate safety or integrity management systems (e.g., as described in API Publication 9100A, Model Environmental, Health and Safety (EHS) Management System)? [05/10/2004]
• HCA Identification [Top] [Bottom]
  • FAQ-174. The centerline of a pipeline may not be accurately determined via GIS or other method. The locations of structures (e.g., from aerial photography) may also involve inaccuracies. What provisions must be taken to address for inaccuracies in these measurements, in order to accurately determine the relative location of structures with respect to the pipeline? [10/02/2006]
  • FAQ-22. Why is it important that operators know the specific characteristics of high consequence areas their pipelines traverse? [08/14/2006]
  • FAQ-233. Does growth of an existing HCA, which introduces new length of pipeline segment into the HCA, constitute a "newly-identified HCA?" [03/14/2005]
  • FAQ-172. May an operator designate an entire segment as HCA (i.e., covered by the rule)? [01/14/2005]
  • FAQ-171. If Method 2 is being used to identify HCAs, can multiple adjacent HCAs be merged to create a single segment? [12/06/2004]
  • FAQ-200. Our company constructed a line many years ago with an MAOP of 1000 psi. Recently we extended the line and, expecting market growth, put in pipe with an MAOP of 1201 psi. But the only supply to the new segment is the old line. Can we look for HCAs in both segments using MAOP=1000 psi? If we do so, are we obligated to go through a derate/uprate procedure? [12/06/2004]
  • FAQ-208. Is the derivation of the PIR equation publicly available? [12/06/2004]
  • FAQ-211. What is the time period for the 20 persons in an area? 20 people for 10 min/day, 20 people for 2 hours/day, 20 people for 8 hours/day? [12/06/2004]
  • FAQ-145. Are parking lots considered to be outside areas occupied by people in the definition of an identified site (specifically, commercial or industrial parking lots and church parking lots)? If a PIR crosses the back portion of a parking lot where it is unlikely that people will congregate, should this area be considered an identified site? If so, is there any guidance on how many people per parking space should be used to compute the total of 20? [11/19/2004]
  • FAQ-144. What is the preferred method for calculating the Potential Impact Radius (PIR) of a leak of a non-flammable gas within the context of Pipeline Integrity Management? The regulation refers to ASME B31.8S-2001 Section 3.2 for calculation of PIR for gases other than natural gas. However, this document only deals with flammable gases. ASME B31.8S-2001 allows alternate models to be used for calculating impact radius, but provides no guidance as to preferred methods of modeling non-flammable or corrosive gases. [10/25/2004]
  • FAQ-182. If a facility or site has 20 or more people visit throughout the day but never 20 or more at one time, does this meet the identified site criteria? [08/19/2004]
  • FAQ-183. If an operator initially selects method 1 to identify HCAs and later changes to method 2 for the same portion of its system, does this constitute a change in IMP that needs to be communicated to OPS/state? [08/19/2004]
  • FAQ-192. If an operator has a short line and wants to declare it as an HCA, and assess it respectively, does the operator have to count houses, buildings, and identified sites? [08/19/2004]
  • FAQ-176. Is a single home housing a disabled person considered an identified site? [08/18/2004]
  • FAQ-20. When must newly-identified HCAs be included in the program? [08/17/2004]
  • FAQ-162. If only a small portion of a building where more than 20 people gather is within the impact radius, why does the segment need to be considered a covered segment? [08/17/2004]
  • FAQ-163. Why does the length of an HCA segment vary depending on how close to the pipeline an identified site is located? If an identified site is close to the pipeline the HCA length is longer than if an identified site is further away. Shouldn’t the HCA be the same? [08/17/2004]
  • FAQ-164. Why should the high consequence area extend from the beginning of the first circle to the end of the last circle containing an identified site? For identified sites close to the pipeline, this creates HCAs that appear unreasonably long. [08/17/2004]
  • FAQ-170. Must an operator continue to contact public safety officials in order to locate identified sites even if they don’t respond? [08/17/2004]
  • FAQ-191. If a pipeline is determined to fall within an HCA due to its class location, does the operator also have to identify identified sites. [06/29/2004]
  • FAQ-195. How were the Fire Marshals notified of providing assistance in locating identified sites? Is there written communication (i.e., documentation) that operators can reference? A Federal Register notice describing this effort would be useful. [06/28/2004]
  • FAQ-117. How often must an operator update its building density survey and list of identified sites to determine if new HCAs have been created? [06/09/2004]
  • FAQ-146. Does a commercial or industrial building count as one building, or multiple buildings? For example a shipping and receiving warehouse. Would a two story office building with five offices count as five buildings or one? [06/09/2004]
  • FAQ-149. Must an operator treat all of its class 3 and 4 areas as high consequence areas? [06/09/2004]
  • FAQ-14. When must covered pipeline segments subject to the rule be identified? [05/19/2004]
  • FAQ-16. How will an operator determine if a pipeline is in an HCA? [05/19/2004]
  • FAQ-17. What is an identified site? [05/19/2004]
  • FAQ-151. Must off-shore platforms be treated as high consequence areas? [05/18/2004]
  • FAQ-15. Many operators have pre-defined segments on their pipeline (e.g., the length of pipe between two compressor stations or between consecutive isolation valves is considered a segment). When OPS refers to segments in HCAs in the rule, in what context is the term segment used? [05/17/2004]
  • FAQ-18. Are there practical limits on an operator’s search for identified sites? [05/17/2004]
  • FAQ-19. What are OPS expectations for operators to determine new or changed HCAs? [05/17/2004]
  • FAQ-21. Must non-pipe elements of a pipeline system in HCAs (e.g., compressor stations) be identified by 12/17/04? [05/17/2004]
  • FAQ-120. Who is an appropriate safety authority for locating identified sites? [05/17/2004]
  • FAQ-119. Can I use normal operating pressure in my potential impact circle calculations if that pressure is significantly below MAOP? [05/11/2004]
  • FAQ-121. Must facilities occupied by an operator's employees be considered in identifying HCAs? [05/11/2004]
  • FAQ-143. When determining "identified sites", does one have to consider standing traffic on roads/expressways under the "outside area or open structure" portion of the definition? If so, is there any guidance on how many people per vehicle should be used to compute the total of 20? [02/20/2004]
• Threat/Risk Analysis [Top] [Bottom]
  • FAQ-234. How often must my risk analysis be updated? [04/29/2005]
  • FAQ-168. Does OPS expect operators to progress through the four risk analysis methods, from least complicated to most complicated as the operator moves to a performance based program? [08/17/2004]
  • FAQ-83. Will operators be expected to consider external conditions such as earthquake fault lines or mining subsidence in their integrity management program? [06/09/2004]
  • FAQ-102. Can operators include potential business consequences (e.g., curtailments, plant shutdown) in their risk determinations? [05/17/2004]
  • FAQ-45. Can the operator use risk assessment data to defend longer intervals between integrity assessments? [05/11/2004]
  • FAQ-91. How do operators assess and control risk caused by third-parties over which they have no direct control? [04/20/2004]
  • FAQ-142. When should risk analysis be performed? [04/08/2004]
• Identification of Threats [Top] [Bottom]
  • FAQ-231. What 5-year period must I consider to establish a reference pressure for stability of manufacturing and construction defects? [03/09/2005]
• Data Integration [Top] [Bottom]
  • FAQ-240. What must I do for "data integration"? [08/02/2006]
  • FAQ-205. Does an operator have to provide the original source documents for the covered segment of the pipeline? (Source document means actual pressure test chart for MAOP, mill test report on pipe, etc.) In the absence of original source material, will DOT accept inventory map data for pipeline information, MAOP database information, etc.? [12/06/2004]
  • FAQ-222. Must I consider information from portions of my pipeline not in HCAs when developing my integrity management program? [09/16/2004]
  • FAQ-81. What kinds of information must be integrated in performing a continual evaluation of pipeline integrity? [05/17/2004]
• Risk Analysis and Prioritization [Top] [Bottom]
  • FAQ-28. What must an operator consider in prioritizing pipe segments for assessment and re-assessment? [08/17/2004]
  • FAQ-166. What qualification standards apply to Subject Matter Experts (SME) where that approach is used for risk assessment? [08/17/2004]
  • FAQ-169. Where the rule specifies certain segments with specific threats as "high risk segments," do these segments need to be in the top 50%? [08/17/2004]
  • FAQ-110. When the operator has identified a "new" HCA that results in the designation of additional covered segments, not previously identified as covered segments, subpart 192.905(c) requires the operator to incorporate these segments into the baseline assessment plan within one year. Subpart 192.921(f) requires the operator to complete the baseline assessment on these newly identified covered segments within ten (10) years from the date the new area is identified. Is the operator required to re-prioritize the baseline assessment plan segments per 192.921(b) each time a new segment is added even though the rule specifies a ten (10) year assessment schedule for these additional segments? [05/17/2004]
  • FAQ-78. Does OPS expect operators to apply different risk ranking systems for lines in HCAs? [04/08/2004]
  • FAQ-125. Can risk ranking be done by piggable sections, since that is the way my assessments will be conducted? [04/08/2004]
• Specific Threats [Top] [Bottom]
  • FAQ-220. Are assessments required for manufacturing and construction defects, including seam defects, if the pipeline has not been pressure tested in accordance with Subpart J? [01/04/2005]
  • FAQ-221. Relative to the requirement in 192.917(e)(3)(i), how much pressure increase (above the maximum experienced in the preceding five years of operation) will trigger the requirement to treat the segment as high risk for purposes of integrity assessments. [01/04/2005]
  • FAQ-219. Are integrity assessments required for manufacturing and construction defects, including seam defects, if the pipeline has been pressure tested in accordance with Subpart J? [09/16/2004]
• Assessment [Top] [Bottom]
  • FAQ-46. What are acceptable integrity assessment methods? [10/20/2004]
  • FAQ-49. What type of pressure test can be used to assess pipeline integrity? [10/20/2004]
  • FAQ-177. Can operators aggregate ECDA regions after the process is started and they determine that some regions have common features? [08/19/2004]
  • FAQ-175. What is the definition of complementary technologies for selection of ECDA indirect inspection tools? [08/18/2004]
  • FAQ-48. What kind of tool can an operator use to conduct integrity assessments by internal inspection? [08/17/2004]
  • FAQ-33. The rule requires that 50% of the covered segments be assessed by December 17, 2007. For purposes of determining the 50% criterion, does an operator use the total mileage that has been and will be assessed, or just the mileage that has been determined to be in an HCA? (For example, most operators who use internal inspection will pig a greater distance than just the portion of the pipeline that can affect an HCA.) [05/20/2004]
  • FAQ-57. How soon must the results of pipeline integrity assessment be evaluated? [05/20/2004]
  • FAQ-26. When must baseline assessments be completed? [05/19/2004]
  • FAQ-34. For purposes of establishing the deadlines for completing baseline assessments, what is the date on which an assessment is considered complete? [05/18/2004]
  • FAQ-152. Must an assessment completed prior to the effective date of the rule have considered all applicable threats in order to be treated as a baseline assessment? [05/18/2004]
  • FAQ-53. For operators having line pipe in states that have a pressure testing requirement, will satisfying the state requirement also suffice for satisfying the integrity assessment requirement of the integrity management rule? [05/17/2004]
  • FAQ-29. Can operators count prior assessments of low-risk segments used as baselines against the requirement to complete 50% of their covered mileage by December 17, 2007? [04/27/2004]
  • FAQ-35. Must all of the highest risk segments be assessed by December 17, 2007, or will OPS allow operators some flexibility to deal with practical issues in scheduling assessments? [04/08/2004]
  • FAQ-55. A reduction in operating pressure can provide an equivalent level of safety as that provided by a Subpart J pressure test. Is a pressure reduction an acceptable integrity assessment method? [04/08/2004]
  • FAQ-25. Under what conditions should the Baseline Assessment Plan be modified? [02/20/2004]
• Baseline Assessment Plan (BAP) [Top] [Bottom]
  • FAQ-38. If an operator has multiple operating companies, does OPS require the operator to produce a single Baseline Assessment Plan for the entire company, or can an operator create multiple plans to align with its internal management practices? [09/07/2004]
  • FAQ-36. If an operator develops a single Baseline Assessment Plan that covers both intra- and interstate pipelines, does the need to complete assessments on 50% of the pipeline mileage in HCAs apply to both intra- and interstate line segments, or just interstate line segment mileage? Should the company’s Plan identify whether line segments are intra- or interstate? [06/29/2004]
  • FAQ-39. What specificity does OPS expect for schedules in baseline assessment plans? [05/17/2004]
• Assessment Methods [Top] [Bottom]
  • FAQ-133. Must I do a full assessment every 7 years if my pipeline is subject to threats other than external and internal corrosion. [09/27/2006]
  • FAQ-235. If Guided Wave UT is used as part of the ICDA process, is it considered "other technology" requiring notification to OPS/states? [08/30/2006]
  • FAQ-242. How can I demonstrate that I have applied more restrictive criteria the first time I used ECDA (required by 192.925(b)(1)-(3) and NACE-0502-2002)? [08/02/2006]
  • FAQ-243. What does PHMSA expect to see in a direct assessment feasibility study? [08/02/2006]
  • FAQ-232. What timeframes apply to "discovery" of conditions presenting a potential threat to the integrity of a pipeline when using Direct Assessment? [06/09/2005]
  • FAQ-218. If DA is not currently accepted as a primary assessment method for third party damage, and the threat of third party damage is present, does the rule require that DA always be accompanied by either a pressure test, or ILI, or another assessment method that is capable of assessing third party damage? [03/14/2005]
  • FAQ-223. What kind of data must I collect and evaluate to use stress corrosion cracking direct assessment (SCCDA)? [03/09/2005]
  • FAQ-158. Must historical operating conditions be considered, or only current operating conditions, when using ICDA? [12/06/2004]
  • FAQ-197. If you learn something in the post assessment step that may change the results in another ECDA, is there a time limit when you have to reassess that covered segment? [12/06/2004]
  • FAQ-198. If Guided Wave UT is used as part of the ECDA process, is it considered "other technology" requiring notification to OPS/states? [12/06/2004]
  • FAQ-203. For the first time using DA you were required to do an extra direct examination. Does this mean the "first time" on each covered segment, or the first time you do DA (ever)? [12/06/2004]
  • FAQ-204. Does close interval survey/overline survey qualify for "other technology"? [12/06/2004]
  • FAQ-213. At what point during ECDA does one move from severe, moderate, minor to immediate, scheduled, monitored? [12/06/2004]
  • FAQ-217. In Section 192.919(b), the rule states there must be an explanation of why assessment methods are chosen to assess the integrity of the line pipe. Does this mean the methods must be chosen and explained for all segments before the assessment begins, possibly by using some sort of decision tree, or does this mean that assessment methods can be explained after the assessment is complete? For example, an operator may plan on using an ILI tool for a segment but due to last minute budget restrictions must now hydrotest the segment. Will this last minute change cause a negative effect in an OPS audit even though the operator explains the reasons for the change and the reasons for the assessment method after the assessment is complete? [12/06/2004]
  • FAQ-126. Can Internal Corrosion Direct Assessment (ICDA) be used on a dry-gas system that was used previously to transport wet gas? [09/03/2004]
  • FAQ-187. Discussion at the Houston workshop implied an operator needs to justify use of DA. Since DA is an accepted assessment method in the rule, why does an operator need to justify it over ILI or hydrotesting? [08/19/2004]
  • FAQ-193. Currently, no standard exists for ICDA. How can we include ICDA in our plan when there is no accepted standard? [08/19/2004]
  • FAQ-105. If an operator has no records indicating that a pipeline section contained water or other electrolytes, is the lack of records sufficient to demonstrate that ICDA is unnecessary downstream of that location until the next feed injection point? [06/09/2004]
  • FAQ-128. When using Stress Corrosion Cracking Direct Assessment (SCCDA), must I consider conditions on portions of my pipeline not in high consequence areas? [06/09/2004]
  • FAQ-129. Can I use an indirect assessment tool for ECDA that is not listed in Table 2 of NACE RP-0502-2002? [06/09/2004]
  • FAQ-141. A spike test can be very useful for assessing some threats, including seam issues. Can a spike test be used as an assessment method? [06/09/2004]
  • FAQ-131. Can I use confirmatory direct assessment (CDA) for stress corrosion cracking? [05/20/2004]
  • FAQ-104. ASME/ANSI B31.8S, Appendix B, section B1.3, Indirect Examinations, states that the secondary indirect examination method must evaluate at least 25% of each ECDA region. NACE Standard RP0502-2002, section 4.1.2 states that the indirect inspection step requires the use of at least two inspections over the entire length of each ECDA region. The requirements in the two standards appear to conflict. Which requirement should be implemented? [05/11/2004]
  • FAQ-107. Section 192.927(c)(5)(iii) states that the ICDA plan must include "provisions that analysis be carried out on the entire pipeline in which covered segments are present..." Please clarify what sections of the pipeline must the operator conduct this analysis. Also, please define the term "analysis." Is this intended to be ICDA pre-assessment or some other analysis? [05/11/2004]
  • FAQ-127. Must I notify OPS (or the appropriate State) if I plan to use ICDA to assess a system transporting gas with an electrolyte nominally present in the gas stream? [04/08/2004]
  • FAQ-130. Section 192.925(b)(3)(iii) requires notification procedures for any changes to my ECDA plan. Does this mean I have to notify OPS every time my plan changes? [04/08/2004]
  • FAQ-147. Does an operator have to do a direct assessment for internal corrosion (where pigging and hydrostatic testing are impractical) if the operator can demonstrate by historical records such as gas quality, internal inspections, etc. that they have never identified an internal corrosion problem and that conditions conducive to internal corrosion do not exist? [04/08/2004]
  • FAQ-109. Section 192.921(a)(2) requires that pressure tests performed to satisfy rule assessment requirements must be conducted in accordance with subpart J. ASME/ASNI B31.8S, section 6.3 states that the details for conducting pressure tests are in ASME B31.8. These two documents contain different requirements for conducting pressure tests. Which document should take precedence? [04/06/2004]
• Continual Assessment and Evaluation [Top] [Bottom]
  • FAQ-40. How often must periodic integrity assessments be performed on HCA pipeline segments after the baseline assessment is completed? [05/03/2006]
  • FAQ-42. Must operators conduct re-assessments before they have completed all baseline assessments? [05/03/2006]
  • FAQ-43. Can a re-assessment interval be extended beyond the maximum interval specified in 192.939? [05/03/2006]
  • FAQ-207. Table 3 of ASME/ANSI B31.8S indicates that reassessment intervals must be 5 years for some instances in which test pressure was higher than would be required by Subpart J. If I conduct my assessments in accordance with Subpart J, must I reassess more frequently than once every seven years? [05/03/2006]
  • FAQ-236. If I have hydrostatically tested my pipeline to a test pressure different than those listed in table 3 of ASME/ANSI B31.8S, how can I determine an extended reassessment interval? [01/04/2006]
  • FAQ-132. How do I determine a new reassessment schedule if I identify defects requiring remediation using ICDA during a CDA assessment? [12/06/2004]
  • FAQ-216. Assuming a system operating below 30% SMYS and reassessment every 20 years, how much of a system must be assessed via CDA at the 7 and 14 year intervals? How do we determine where we must use CDA? [12/06/2004]
  • FAQ-228. Can the conduct of a successful CDA assessment extend the interval until the next required assessment using ILI, pressure testing, DA, or other technology? [10/08/2004]
  • FAQ-178. If a line was operating at <30% SMYS and reassessment schedules had been established based on this stress level, what requirements would need to be adopted before the line stress is raised to >30% SMYS? [08/19/2004]
  • FAQ-185. Might OPS consider revising the rule, if experience indicates that longer reassessment intervals could be acceptable? [06/29/2004]
  • FAQ-41. Does the requirement that an operator establish inspection intervals not to exceed a specified number of years mean calendar years (i.e., pipe assessed in 2004 must be re-assessed during 2011) or actual years? [06/09/2004]
• Remediation [Top] [Bottom]
  • FAQ-68. Must tool accuracy be considered when determining if an anomaly detected by in-line inspection meets repair criteria? [08/14/2006]
  • FAQ-215. ASME B31.8S states that Immediate conditions shall be examined within five days after determination of the condition. Is this 5 day requirement part of the Final Rule? [08/14/2006]
  • FAQ-241. May I exclude metal loss indications of >80% wall loss from immediate repair requirements per 933(d)(1), if B31G or RSTRENG predict a failure pressure of greater than 1.1 times MAOP? [08/02/2006]
  • FAQ-224. What actions must I take on non-covered segments if I find corrosion during an assessment of segments in HCA? [03/09/2005]
  • FAQ-229. Must I include a safety factor when calculating an acceptable reduced operating pressure [per 192.933(d)(1)] for the interim period until immediate conditions can be repaired? [03/09/2005]
  • FAQ-225. Must I fix anomalies found in non-covered segments? [01/04/2005]
  • FAQ-56. Do the anomaly repair schedule requirements in 192.933(d) apply to all previous internal inspection runs performed by the operator, or just the integrity assessments required by Subpart O (i.e., the baseline assessment and subsequent integrity assessments)? [06/09/2004]
  • FAQ-65. If an operator elects to use an assessment conducted prior to 2002 as its baseline assessment [per 192.921 (e)], how long does the operator have to review the results of the prior assessment and identify any anomalies that have not already been repaired or remediated that meet the criteria established in 192.933? [06/09/2004]
  • FAQ-62. When must monitored conditions be repaired? [05/20/2004]
  • FAQ-69. Is a 20 percent reduction in pressure an adequate interim measure for immediate repair conditions? [05/20/2004]
  • FAQ-66. If a covered segment is relatively short (e.g., only 2 miles in length), yet the operator internally inspects a longer portion around this segment (e.g., 50 miles from pig launcher to receiver), do the repair schedules in 192.933 apply to the covered segment or the entire distance over which the pig is run? [05/17/2004]
  • FAQ-67. The rule requires that an operator temporarily reduce pressure if an immediate repair condition is discovered (192.933(d)(1)). Can the temporary reduction in operating pressure be based upon previous maximum allowable operating pressures? [05/17/2004]
  • FAQ-70. Must anomalies identified during pig runs not considered "baseline" or "re-assessments" under the rule be repaired in accordance with the rule's repair criteria? [05/17/2004]
  • FAQ-134. How soon must I reduce pressure after identifying an immediate repair condition? [04/12/2004]
  • FAQ-58. What constitutes "discovery of a condition"? [04/08/2004]
  • FAQ-135. Must I consider segments not in HCAs when evaluating my pipeline after discovering corrosion in a covered segment? [04/08/2004]
• Preventive and Mitigative Measures [Top] [Bottom]
  • FAQ-90. When must operators implement additional preventive and mitigative measures? For example, how long after completing the baseline assessment for a segment can an operator take to conduct a risk analysis and determine whether additional preventive or mitigative actions are needed (including the need for ASVs/RCVs)? If an operator determines that additional actions are warranted, how long does it have to implement them? [03/13/2007]
  • FAQ-230. What is the maximum interval for "semi-annual" and "quarterly" leak surveys (192.935(d)(3))? [11/19/2004]
  • FAQ-180. How will OPS evaluate required "enhancements" for operators that are already operating at high level with respect to damage prevention measures? [08/19/2004]
  • FAQ-113. Section 192.935(b)(2) uses the term "determines ... is a threat to the integrity of a covered segment." What is intended by the word "threat" in this context, such that the subsequent actions (e.g., relocating the line) are required to be implemented? [04/20/2004]
  • FAQ-86. What criteria must an operator use in determining whether automatic shut-off valves or remote control valves are required to protect HCAs? [04/06/2004]
• Performance Measures [Top] [Bottom]
  • FAQ-137. Over what time period should performance measures be determined? How often should they be updated? [07/15/2005]
  • FAQ-209. As originally published, the rule required that all performance measures be submitted to OPS on a semi-annual basis. Current discussion indicates only the four overall measures of B31.8S, Section 9.4, must be submitted. Which is correct? [12/06/2004]
  • FAQ-186. Assume that an operator runs an inline inspection tool through a 50-mile segment of pipeline, not all of which is HCA, and a new HCA is subsequently identified within the inspected pipeline. When submitting semi-annual performance measures, can the operator take credit for the previous inspection when reporting "number of miles inspected versus program requirements"? [08/19/2004]
  • FAQ-194. Will DOT develop an official reporting form for semi-annual reporting of the four overall measures? [06/23/2004]
  • FAQ-136. One of the four overall performance measures required by 192.945(a) is the number of leaks, failures, and incidents (classified by cause). What is the threshold an operator should use for reporting leaks, failures, and incidents? [05/18/2004]
• Record Keeping [Top] [Bottom]
  • FAQ-189. What certification or officer approval by the operator of the IMP is required by OPS? [08/19/2004]
  • FAQ-165. Is information in an electronic database considered satisfactory documentation? [06/29/2004]
  • FAQ-32. Should operators archive previous versions of their baseline assessment plans so OPS can track changes to these plans over time? [02/20/2004]
• Management of Change (MOC) [Top] [Bottom]
  • FAQ-201. Must an operator implement change log procedures on December 17, 2004, or can the lockdown date be later? [12/06/2004]
• Regulatory and External Interaction [Top] [Bottom]
  • FAQ-30. Will operators need to seek waivers from OPS in order to change assessment schedules after the initial Baseline Assessment Plan has been developed? [05/20/2004]
  • FAQ-31. Section 192.909(b) requires that operators notify OPS of program changes that may modify the schedule for carrying out the program elements. Must operators notify OPS every time they change their assessment schedules? [04/08/2004]
• Communication Plan [Top] [Bottom]
  • FAQ-184. What content/information is to be communicated with the public/public officials about integrity management plan and activities related to IMP? [08/19/2004]
• Notification [Top] [Bottom]
  • FAQ-245. If PHMSA completes a review of my notification for use of "other technology" and has no objections, must I still wait the remainder of the 180 days before I can implement the technology? [04/27/2006]
  • FAQ-99. What information must be in a notification? [09/03/2004]
  • FAQ-153. Must I notify OPS/state regulators if I plan to use a different model for ICDA than the one referenced in the rule? [09/03/2004]
  • FAQ-97. What types of notifications are required by the rule? [06/29/2004]
  • FAQ-181. Is a safety related condition notification required when an operator implements a pressure reduction for an immediate repair? What about other pressure reducing requirements in the IM rule, is a notification required per 191.23? [06/29/2004]
  • FAQ-111. What level of change satisfies the terms "significantly modify" or "substantially affect" as used under subpart 192.909(b) regarding notification requirements for changes to an operator’s integrity management plan? [06/09/2004]
  • FAQ-98. When must notifications be submitted? [05/20/2004]
• Inspection [Top] [Bottom]
  • FAQ-94. How can operators know what inspections will cover? [06/09/2004]
  • FAQ-95. Will integrity management inspection results on a company be publicly available? [05/17/2004]
  • FAQ-93. Will inspections of Integrity Management Programs be scheduled in advance? [04/08/2004]
• Enforcement [Top] [Bottom]
  • FAQ-114. Are Appendix E "must" statements required by rule, or are they merely guidance statements? [07/31/2007]
  • FAQ-96. How will OPS ensure consistency in applicatiion of integrity management requirements? [06/09/2004]
  • FAQ-160. Are requirements included in a company's integrity management program that go beyond those in the regulations enforceable by OPS? [05/18/2004]
• State Agencies and Intrastate Pipelines [Top] [Bottom]
  • FAQ-206. New York CRR 255 mandates any pipeline operating above 125 PSIG is classified as a "transmission line". Will operators be required to develop an IMP for NY transmission lines even though under 192 these lines would not be defined as transmission pipelines? [12/06/2004]
  • FAQ-210. If the gas transmission pipeline is under state jurisdiction, should performance measures, waivers, etc., be sent to the states’ commission rather than OPS? [12/06/2004]
• Exceptional Performance Deviations [Top] [Bottom]
  • FAQ-227. How is risk assessment and data integration conducted in performance-based programs expected to differ from that in a prescriptive approach? [09/16/2004]
  • FAQ-173. Can a CDA be credited as a second assessment if an operator desires to move to a performance-based program? [08/18/2004]