{"operation":"document","citation":"0900006480e91c2d","title":"U.S. DOT/PHMSA - Signed Special Permit","source_type":"rulemaking","agency":"Pipeline and Hazardous Materials Safety Administration","status":"current","official":true,"published_on":null,"effective_on":null,"summary":"U.S. DEPARTMENT OF TRANSPORTATION 1 PIPELINE AND HAZARDOUS MATERIALS SAFETY ADMINISTRATION (PHMSA) SPECIAL PERMIT Docket Number: PHMSA - 2008-0330 Requested By: Columbia Gulf Transmission Company' Date Requested: November 13, 2008 Code Section(s): 49 CFR $ 192.611 Grant of Special Permit: By this order, subject to the terms and conditions set forth below the Pipeline and... 2 • Special Permit Segment 2: 36-inch Mainline 300 - 1600 feet, Sta. 3025+55 to Sta. 3041+55 Special permit inspection areas - means the area that extends 220 yards on each side of the centerline along the entire length of the 30-inch Mainline 200 and 36-inch Mainline 300 pipelines defined as follows: • Special Permit...","machine_formats":{"json":"https://regulus.evalyn.ai/document/regulations-gov-attachment-0900006480e91c2d.json","markdown":"https://regulus.evalyn.ai/document/regulations-gov-attachment-0900006480e91c2d.md"},"app_url":"https://regulus.evalyn.ai/document/regulations-gov-attachment-0900006480e91c2d","source_url":"https://downloads.regulations.gov/PHMSA-2008-0330-0004/attachment_1.pdf","body":"<<<PAGE 1>>>\n\nU.S. DEPARTMENT OF TRANSPORTATION\n1\nPIPELINE AND HAZARDOUS MATERIALS SAFETY ADMINISTRATION (PHMSA)\nSPECIAL PERMIT\nDocket Number:\nPHMSA - 2008-0330\nRequested By:\nColumbia Gulf Transmission Company'\nDate Requested:\nNovember 13, 2008\nCode Section(s):\n49 CFR $ 192.611\nGrant of Special Permit:\nBy this order, subject to the terms and conditions set forth below the Pipeline and Hazardous\nMaterials Safety Administration (PHMSA) grants this special permit to Columbia Gulf Transmission\nCompany (Columbia Gulf) waiving compliance from 49 CFR § 192.611(a) for two natural gas\ntransmission pipeline segments in the Mt. Juliet area, Wilson County, Tennessee as described below.\nSpecial Permit Segments and Inspection Areas:\nWilliamson, Davidson, Wilson, Sumner and Trousdale Counties, Tennessee\nPHMSA waives compliance from 49 CFR § 192.611(a) for two natural gas transmission pipeline\nsegments on the 30-inch Mainline 200 and 36-inch Mainline 300 pipelines, where a change has\noccurred from a Class 1 location to a Class 3- location in the Mt. Juliet area, Wilson County, TN.\nThe Federal pipeline safety regulations in 49 CFR § 192.611(a) require natural gas pipeline operators\nto confirm or revise the maximum allowable operating pressure (MAOP) of a pipeline segment after\na change in class location. This special permit allows Columbia Gulf to continue to operate each\nspecial permit segment at its current maximum allowable operating pressure (MAOP) of 1008\npounds per square inch gauge (psig) for the 30-inch Mainline 200 and 36-inch Mainline 300\npipelines.\nThis special permit applies to the special permit segments defined as follows using the Columbia\nGulf pipeline survey stationing (Sta.):\n• Special Permit Segment I: 30-inch Mainline 200 - 1600 feet, Sta. 3030+43 to Sta. 3046+43\n'Columbia Gulf Transmission Company (Columbia Gulf) is owned and operated by NiSource Gas Transmission and\nStorage (NGT&S).\nlocation in accordance with § 192.611 (a) hydrostatic test.\n2 The Class 3 location special permit segments were originally a Class 1 location that were upgraded to a Class 2\n\n<<<PAGE 2>>>\n\n2\n• Special Permit Segment 2: 36-inch Mainline 300 - 1600 feet, Sta. 3025+55 to Sta. 3041+55\nSpecial permit inspection areas - means the area that extends 220 yards on each side of the\ncenterline along the entire length of the 30-inch Mainline 200 and 36-inch Mainline 300 pipelines\ndefined as follows:\n• Special Permit Inspection Area 1: 30-inch Mainline 200 - Sta. 1710+43 to Sta. 4366+43 (50.30\nmiles)\nSpecial Permit Inspection Area 2: 36-inch Mainline 300 - Sta. 1705+55 to Sta. 4361+55 (50.30\nmiles)\nThe special permit inspection areas are located in Williamson, Davidson, Wilson, Sumner and\nTrousdale Counties, TN. The special permit inspection areas start downstream of the Hampshire\nCompressor Station and ends upstream of the Hartsville Compressor Station for a total mileage of\n50.30 miles.\nNote: The special permit inspection areas extend approximately 50.30 miles along each pipeline\n(Mainlines 200 and 300) with overlapping areas and includes the special permit segments.\nPHMSA grants this special permit based on the findings set forth in the \"Special Permit Analysis and\nFindings\" document, which can be read in its entirety in Docket No. PHMSA-2008-0330 in the\nFederal Docket Management System (FDMS) located on the internet at www.Regulations.gov.\nConditions:\nPHMSA grants this special permit subject to the following conditions:\n1) Columbia Gulf must continue to operate the special permit segments at or below their existing\nMAOP as follows: the 30-inch Mainline 200 and 36-inch Mainline 300 pipelines - MAOP 1008\npsig.\n2) Columbia Gulf must incorporate each of the special permit segments and special permit\ninspection areas into its written integrity management program (IMP) as a \"covered segment\" in\na \"high consequence area (HCA)\" per § 192.903, except for the reporting requirements contained\n3 \"Each condition that requires Columbia Gulf to perform an action with respect to the Special Permit Inspection Area\nshall also require Columbia Gulf to perform that action on all Special Permit Segments within such Areas.\"\n\n<<<PAGE 3>>>\n\nin § 192.945. Columbia Gulf need not include the special permit segments described in this\nspecial permit in its IMP baseline assessment plan unless those segments are in HCAs, in\naccordance with § 192.905.\n3) Columbia Gulf must perform a close interval survey (CIS) of the Mainline 200 & 300 pipelines\nalong the entire length of all special permit segments and special permit inspection areas and\nremediate any areas of inadequate cathodic protection no later than one year after the grant of this\nspecial permit. A CIS and remediation need not be performed if Columbia Gulf has performed a\nCIS and remediation on the Mainlines 200 & 300 pipelines along the entire length of all special\npermit inspection areas less than two years prior to the grant of this special permit. If factors\nbeyond Columbia Gulf's control prevent the completion of the CIS and remediation within one\nyear, a CIS and remediation must be completed as soon as practicable and a letter justifying the\ndelay and providing the anticipated date of completion must be submitted to the Director,\nPHMSA Southern Region*\nno later than one year after the grant of this special permit.\n4) Columbia Gulf must perform periodic CIS of the special permit segments and special permit\ninspection areas at least once every 5 calendar years at reassessment intervals not exceeding 63\nmonths. CGTC must also integrate CIS data with in-line inspection (ILI) data, and data on any\nother threats, in accordance with 49 CFR §§ 192.937 (a) and (b), and 192.917.\n5) Within one year of the grant of this special permit Columbia Gulf must perform a Direct Current\nVoltage Gradient (DCVG) survey or an Alternating Current Voltage Gradient (ACVG) survey of\neach special permit segment to determine the pipeline coating conditions and must then\nremediate any integrity issues in the special permit segments. A DCVG or ACG survey and\nremediation need not be performed on the special permit segments if Columbia Gulf has\nperformed a DCVG or ACVG and remediation in accordance with this special permit condition\non the Mainline 200 & 300 pipelines along the entire length of all special permit inspection areas\nless than two years prior to the grant of this special permit. Columbia Gulf must remediate any\ndamaged coating indications found during these assessments that are classified as moderate (i.e.\n35% IR and above for DCVG or 50 dBuV and above for ACVG) or severe based on NACE\n4 \"In the case of any Special Permit condition that requires Columbia Gulf to provide documentation to the PHMSA\nRegion, Columbia Gulf must also send a copy of such documentation to the appropriate state authorities, in states that\nhave interstate agent agreements with PHMSA.\"\n\n<<<PAGE 4>>>\n\nInternational Recommended Practice 0502-2002, \"Pipeline External Corrosion Direct\n4\nAssessment Methodology, \" (NACE RP 0502-20025). A minimum of two coating survey\nassessment classifications must be excavated, classified and/or remediated per each survey crew\nper each time the survey is performed. If factors beyond Columbia Gulf's control prevent the\ncompletion of the DCVG or ACVG survey and remediation within one year, a DCVG or ACVG\nsurvey and remediation must be performed as soon as practicable and a letter justifying the delay\nand providing the anticipated date of completion must be submitted to the Director, PHMSA\nSouthern Region no later than one year after the grant of this special permit.\n6) Columbia Gulf must evaluate the Mainline 200 & 300 pipelines for stress corrosion cracking\n(SCC) as follows:\na) Columbia Gulf must perform a stress corrosion cracking direct assessment (SCCDA) or other\nappropriate assessment method for SCC [such as pressure test or ILI with a crack detection\ntool] of the Mainline 200 & 300 pipelines along the entire length of the special permit\ninspection areas, according to the requirements of § 192.929 and/or NACE SP 0204-2008\nand remediate any SCC found, no later than one year after of the grant of this special permit.\nThe SCCA or other approved method must address both high pH SCC and near neutral pH\nSCC. A SCCA need not be performed if Columbia Gulf has performed a SCCA of the\nMainline 200 & 300 pipelines along the entire length of the special permit inspection areas\nless than two years prior to the grant of this special permit. If factors beyond Columbia\nGulf's control prevent the completion of the SCCA survey and remediation within one year,\na SCCA and remediation must be performed as soon as practicable and a letter justifying the\ndelay and providing the anticipated date of completion must be submitted to the Director,\nPHMSA Southern Region no later than one year after the grant of this special permit.\nColumbia Gulf may eliminate this Condition 6 (a), provided Columbia Gulf provides an\nengineering assessment showing that the pipeline does not meet any of the criteria for both\nnear neutral and high pH SCC per the applicable edition of the American Society of\nMechanical Engineers Standard B31.8S, \"Managing System Integrity of Gas Pipelines\"\n(ASME B31.8S) Appendix A3, or NACE SP 0204-2008, \"Stress Corrosion Cracking (SCC)\nDirect Assessment Methodology\",\n\", Section 1.2.1.1 and 1.2.2].\n5 \"When PHMSA adopts a revised edition of a referenced NACE or ASME standard into 49 CFR Part 192, the referenced\nrequirements of those revised standards are automatically incorporated into these special permit conditions.\"\n\n<<<PAGE 5>>>\n\nb) When the Columbia Gulf Mainline 200 or 300 pipelines are exposed for any reason in the\nspecial permit segments and special permit inspection areas and the coating has been\nidentified as poor during the pipeline examination, then Columbia Gulf must directly examine\nthe pipe for SCC using an accepted industry detection practice such as dry or wet magnetic\nparticle tests. Poor coating is a coating that has become damaged and is losing adhesion to\nthe pipe which is shown by falling off the pipe, is porous, has pin holes, and/or shields the\ncathodic protection. Visual inspection is not sufficient to determine if the coating is damaged\nand a holiday detection test at the correct voltage must be performed. Columbia Gulf must\nkeep coating records of all excavation locations in the special permit segments and special\npermit inspection areas to demonstrate the coating condition.\n7) Columbia Gulf must submit the DCVG or ACVG, CIS and SCCDA [or other PHMSA approved\nmethods of determining SCC] findings including remediation actions in a written report to the\nDirector, PHMSA Southern Region, no later than one year after the grant of this special permit.\n8) Columbia Gulf must amend applicable sections of its operations and maintenance (O&M)\nmanual(s) to incorporate the inspection and reassessment intervals by in-line inspection (ILI)\nincluding both metal loss and geometry tools of the Mainline 200 & 300 pipelines along the entire\nlength of the special permit segments and special permit inspection areas at a frequency\nconsistent with 49 CFR Part 192, Subpart O. [Deformation tools may be substituted for geometry\ntools, in accordance with Condition 20 (c). J Condition 20(c) requires Columbia Gulf to run\ndeformation tools on the pipelines.\n9) Columbia Gulf must amend applicable sections of its O&M manual(s) to require CIS inspection\nand reassessment intervals of the Mainlines 200 & 300 special permit segments and special\npermit inspection areas at a frequency consistent with 49 CFR Part 192, Subpart O, but at least\nonce every five (5) calendar years at reassessment intervals not exceeding 63 months.\n10) Columbia Gulf must perform an ILI assessment along the entire length of the special permit\nsegments and special permit inspection areas using high resolution MFL and deformation in-line\ninspection tools within 6 months of issuance of this permit and must remediate discovered\nconditions in accordance with Condition 20 of this permit. Subsequent ILI assessments of the\nMainline 200 & 300 pipelines along the entire length of the special permit inspection areas must\n\n<<<PAGE 6>>>\n\nconform to the required maximum reassessment intervals specified in § 192.93, but at least once\n6\nevery 5 calendar years at reassessment intervals not exceeding 63 months.\n11) Columbia Gulf must schedule ILI reassessment dates for the Mainline 200 & 300 pipelines along\nthe entire length of the special permit segments and special permit inspection areas according to\n$ 192.939 by adding the required time interval to the previous assessment date, but reassessments\nmust be at least once every 5 calendar years at intervals not exceeding 63 months.\n12) Columbia Gulf must incorporate the applicable best practices of the Common Ground Alliance\n(CGA) into its damage prevention program within the special permit segments and special permit\ninspection areas.\n13) Columbia Gulf must give a minimum of 14 days notice to the Director, PHMSA Southern\nRegion to enable him/her to observe the excavations relating to Conditions 5, 6 (b), 19, 20, 21,\n22, 23 and 24 in the special permit segments and special permit inspection areas. Immediate\nresponse conditions do not require a 14-day notice, but the PHMSA Region Director must be\nnotified by Columbia Gulf no later than two business days after the immediate condition is\ndiscovered.\n14) Columbia Gulf shall not use this special permit as a basis for deferring any of it's assessments for\nHCAs under 49 CFR Part 192, Subpart O.\n15) Within three months following the grant of this special permit and annually thereafter,\nColumbia Gulf must report the following to the Director, PHMSA Southern Region:\na) In the first annual report, Columbia Gulf must describe the economic benefits of the special\npermit including both the costs avoided from not replacing the pipe and the added costs of the\ninspection program. Subsequent annual reports should address any changes to these\neconomic benefits.\nb) In the first annual report, fully describe whether the public benefits from energy availability.\nThis should address the benefits of avoided disruptions as a consequence of pipe replacement\nAnnual reports must be received by PHMSA by the last day of the month in which the Special Permit is dated. For\neach year beginning in 2011.\nexample, the annual report for a Special Permit dated January, 2010, must be received by PHMSA no later than January\n\n<<<PAGE 7>>>\n\nand the benefits of maintaining system capacity. Subsequent reports must indicate any\nchanges to this initial assessment.\nc) The number of new residences, other structures intended for human occupancy and public\ngathering areas built within the special permit segments and special permit inspection areas.\nd) Any new integrity threats identified during the previous year and the results of any ILl or\ndirect assessments performed during the previous year in the special permit segments and\nspecial permit inspection areas.\ne) Any reportable incident, any leak normally indicated on the DOT Annual Report and all\nrepairs on the pipeline that occurred during the previous year in the special permit segments\nand special permit inspection areas.\nf) Any on-going damage prevention initiatives affecting the special permit segments and special\npermit inspection areas and a discussion of the success of the initiatives.\ng) Any mergers, acquisitions, transfer of assets, or other events affecting the regulatory\nresponsibility of the company operating the pipeline.\n16) At least one cathodic protection (CP) pipe-to-soil test station must be located within each HCA\nwith a maximum spacing between test stations of one-half mile within an HCA. In cases where\nobstructions or restricted areas prevent test station placement, the test station must be placed in\nthe closest practical location. This requirement applies to any HCA within the special permit\nsegments and special permit inspection areas.\n17) If any annual CP test station readings on the Mainline 200 & 300 within the special permit\nsegments and special permit inspection areas fall below 49 CFR Part 192, Subpart I\nrequirements, remediation must occur within six months and include a CIS on each side of the\naffected test station to the next test station and perform any identified corrosion system\nmodifications to ensure acceptable corrosion control. If factors beyond Columbia Gulf's control\nprevent the completion of remediation within six months, remediation must be completed as soon\nas practicable and a letter justifying the delay and providing the anticipated date of completion\nmust be submitted to the Director, PHMSA Southern Region, no later than the end of the six\nmonths completion date.\n18) Interference Currents Control: Columbia Gulf must address induced AC from parallel electric\ntransmission lines and other interference issues in the special permit segments and special permit\n\n<<<PAGE 8>>>\n\ninspection areas that may affect the pipeline. An induced AC program and remediation to\n8\nprotect the pipeline from corrosion caused by stray currents must be in place within one year of\nthe date of this special permit.\n19) Field Coating: The coatings used on the pipeline and girth weld joints in the special permit\nsegments and special permit inspection areas must be non-shielding to CP. In the event that the\ncoating type is unknown or is known to shield CP for girth weld joints then Columbia Gulf must\ntake special care to:\na) Analyze ILl logs in the areas of girth welds for potential corrosion indications.\nb) Any ILI corrosion indications above 30% wall loss at girth welds where the coating type is\nunknown or is known to shield CP, girth weld joints must be exposed and evaluated each\ntime the ILI is run or until the girth weld coating is replaced\nc) A minimum of two girth weld joints at locations most likely to have shielding and corrosion\nshall be exposed and evaluated each time ILl is run. If corrosion is found, the next most\nlikely joint is to be exposed and evaluated until no corrosion is found.\n20) Anomaly Evaluation and Repair:\na) General: Columbia Gulf must account for ILI tool tolerance and corrosion growth rates in\nscheduled response times and repairs and document and justify the values used. Columbia\nGulf must demonstrate ILI Tool tolerance accuracy for each ILI Tool run by usage of\ncalibration excavations (minimum of 5 excavations for each ILI Tool run) and unity plots that\ndemonstrate ILI Tool accuracy for depth within +/-10% accuracy for 80% of the time. The\nunity plots must show: a) actual anomaly depth versus predicted depth and b) actual failure\npressure/MAOP versus predicted failure pressure/MAOP. Discovery date must be within 60\ndays of an ILI Tool run for each type ILI Tool (geometry, deformation or high resolution\nMFL).\nb) Dents: Columbia Gulf must repair dents to the Mainline 200 & 300 pipelines in the special\npermit inspection areas in accordance with § 192.933 repair criteria. Special permit\nsegments and special permit inspection areas must have a geometry tool inspection as part\nof the initial ILI and all dent repairs made in accordance with § 192.933 repair criteria. The\ngeometry tool can be from past ILI inspections. The timing for these dent repairs should\nfollow Columbia Gulf's O&M Manual but must not be longer than 1 year after discovery.\nc) Deformation Tool: Columbia Gulf must run a deformation tool through all special permit\n\n<<<PAGE 9>>>\n\n9\nsegments and special permit inspection areas within 6 months of the grant of this special\npermit and remediate all expanded pipe in accordance with PHMSA's \"Interim Guidelines\nfor Confirming Pipe Strength in Pipe Susceptible to Low Yield Strength\", dated\nSeptember 10, 2009, within 12 months of grant date of this special permit.\nd) Investigation and Repair Criteria: Investigation, evaluation, and repair criteria apply to all\nanomalies located on the Mainline 200 & 300 pipelines within the special permit segments\nand special permit inspection area when they have been excavated, investigated, and\nremediated in accordance with §$ 192.485 and 192.933 incorporating appropriate class\nlocation design factors in the anomaly repair criteria, including HAs as follows:\n• Special permit segments - Repair any anomaly within a special permit segment that\nmeets either: (1) a failure pressure ratio? (FPR) less than or equal to 1.39 for original\nClass 1 location pipe in a Class 3 location operating up to 72% of the specified\nminimum yield strength (SMYS); (2) an anomaly depth greater than or equal to 40%\nof pipe wall thickness.\n• Special permit inspection area - Repair any anomaly within a special permit\ninspection area that meets either: (1) an FPR less than design factor - for Class 1\nlocation - FPR equal to or less than 1.39; for Class 2 location - FPR equal to or less\nthan 1.67; and for Class 3 location - FPR equal to or less than 2.0; (2) an anomaly\ndepth equal to or greater than 60% wall thickness loss.\n- Repair anomalies in original Class 1 location pipe that are now in a Class 2\nlocation in accordance with §§ 192.5 and 192.611 that meets either: (1) is equal to\nor less than the Class 1 location FPR of 1.39; (2) an anomaly depth equal to or\ngreater than 50% wall thickness loss for anomaly repairs.\n- Repair anomalies in original Class 2 location pipe that is now in a Class 3 location\nin accordance with § 192.611 that meets either: (1) is equal to or less than the\nClass 2 location FPR of 1.67; (2) an anomaly depth equal to or greater than 50%\nwall thickness loss for anomaly repairs.\ne) Response Time for ILI Results: The following guidelines provide the required timing for\nexcavation, investigation, and remediation of anomalies based on ILI data results in\naccordance with §§ 192.485 and 192.933, and must incorporate appropriate class location\ndesign factors in the anomaly repair criteria for special permit segments and special permit\n\" Failure pressure ratio (FPR) is based upon the class location where the special permit segment or special permit\ninspection area pipe is located in accordance with § 192.5 and is the reciprocal of the class location design factor in\n§ 192.111(a).\n\n<<<PAGE 10>>>\n\ninspection area including all HCAs. Reassessment by ILI will reset the timing for\n10\nanomalies not already investigated and/or repaired. CGTC must evaluate ILI data by using\neither the ASME Standard B31G, \"Manual for Determining the Remaining Strength of\nCorroded Pipelines\" (ASME B31G), the modified B31G (0.85dL) or R-STRENG for\ncalculating the predicted FPR to determine anomaly responses.\n• Special permit segments:\n- Immediate response: Any anomaly within a special permit segment operating up\nto 72% SMYS that meets either: (1) an FPR equal to or less than 1.1; (2) an\nanomaly depth equal to or greater than 80% wall thickness loss.\n- One-year response: Any anomaly within a special permit segment with original\nClass 1 location pipe in a Class 3 location operating up to 72% SMYS that meets\neither: (1) an FPR equal to or less than 1.39; (2) an anomaly depth equal to or\ngreater than 40% wall thickness loss.\n- Monitored response: Any anomaly within a special permit segment with original\nClass 1 location pipe in a Class 3 location operating up to 72% SMYS that meets\nboth: (1) an FPR greater than 1.39; (2) an anomaly depth less than 40% wall\nthickness loss. The schedule for the response must take tool tolerance and\ncorrosion growth rates into account.\n• Special permit inspection areas:\n- Immediate response: Any anomaly within a special permit inspection area\noperating up to 72% SMYS that meets either: (1) an FPR equal to or less than 1.1;\n(2) an anomaly depth equal to or greater than 80% wall thickness loss.\n- One-year response: Any anomaly within a special permit inspection area that\nmeets either: (1) an FPR less than design factor - for Class 1 location- FPR equal\nto or less than 1.39; Class 2 location - FPR equal to or less than 1.67; and for\nClass 3 location - FPR equal to or less than 2.0; (2) an anomaly depth equal to or\ngreater than 60% wall thickness loss.\nAny anomaly for Class location changes from original Class 1 to 2 location or\noriginal Class 2 to 3 location in accordance with §§ 192.5 and 192.611 that meets\neither: (1) an anomaly FPR equal to or less than the FPR of the original Class\nlocation ; (2) an anomaly depth equal to or greater than 50% wall thickness loss.\n- Monitored response: Any anomaly within a special permit inspection area that\nmeets both: (1) an FPR less than design factor - for Class 1 location - FPR greater\n\n<<<PAGE 11>>>\n\nthan 1.39; Class 2 location - FPR greater than 1.67; and for Class 3 location -\nFPR greater than 2.0; (2) an anomaly depth less than 60% wall thickness loss.\nAny anomaly repairs for Class location changes from original Class 1 to 2 location\nor original Class 2 to 3 location in accordance with §§ 192.5 and 192.611 that\nmeets both: (1) an anomaly FPR greater than the FPR of the original Class\nlocation; (2) an anomaly depth less than 50% wall thickness loss. The schedule for\nthe response must take tool tolerance and corrosion growth rates into account.\n21) Columbia Gulf must comply with the following provisions:\na) Columbia Gulf must provide records to PHMSA to demonstrate that the girth welds on the\nMainline 200 & 300 pipelines were non-destructively tested at the time of construction in\naccordance with the Federal pipeline safety regulations at the time the pipelines were\nconstructed. If not, show that at least 10% of the girth welds in each special permit\nsegment were non-destructively tested after construction, but prior to the application for\nthis special permit provided at least two girth welds in each special permit segment were\nexcavated and inspected. If Columbia Gulf cannot provide girth weld records to PHMSA\nto demonstrate either of the above, Columbia Gulf must accomplish either: (i); (ii) and\n(ili), or (ii) and (iv) of the following:\n1) Certify to PHMSA in writing that there have been no in-service leaks or breaks\nin the girth welds on the Mainline 200 & 300 pipelines within the entire special\npermit inspection areas for the entire life of the pipelines.\nii) Evaluate the terrain along the special permit segments for threats to girth weld\nintegrity from soil or settlement stresses and remediate all such integrity threats.\nili) Excavate®\n, visually inspect and nondestructively test at least two girth welds on\nthe Mainlines 200 & 300 pipelines in each special permit segment in accordance\nwith the American Petroleum Institute Standard 1104, \"Welding of Pipelines and\nRelated Facilities\" (API 1104) as follows:\nA. Use the edition of API 1104 current at the time the pipelines were\nconstructed; or\nB. Use the edition of API 1104 recognized in the Federal pipeline safety\nregulations at the time the pipelines were constructed; or\n& Columbia Gulf must evaluate for SCC any time the Mainline 200 & 300 pipelines are uncovered in accordance with\nCondition 6 (b) of this special permit.\n\n<<<PAGE 12>>>\n\nC. Use the edition of API 1104 currently recognized in the Federal pipeline\n12\nsafety regulations.\niv) As an alternative to Condition 21 (a) (iii), Columbia Gulf may perform an\nHRMFL in-line inspection capable of identifying girth weld anomalies. If this\ntechnique is employed, Columbia Gulf must develop a technical basis for\nevaluating the serviceability of the girth welds based on HRMFL ILI data. The\ngirth weld ILI inspection plan including ILI findings, technical determination for\nidentifying weld anomalies and confirmation excavations must be submitted to\nDirector, PHMSA Southern Region for approval 14 days prior to confirmation\nexcavations.\nb) If any girth weld in any of the special permit segments does not comply with API 1104,\nColumbia Gulf must repair the girth weld immediately and then prepare an inspection and\nremediation plan for all remaining girth welds in the special permit segments based upon\nthe repair findings and the threat to the special permit segments. Columbia Gulf must\nsubmit the inspection and remediation plan for girth welds to the Director, PHMSA\nSouthern Region and remediate girth welds in the special permit segments in accordance\nwith the inspection and remediation plan within 60 days of finding girth welds that do not\nmeet this Condition 21 (c).\nc) All oxy-acetylene girth welds, mechanical couplings, and wrinkle bends in special permit\nsegments must be removed.\nd) Columbia Gulf must complete the girth weld testing, and the girth weld inspection and\nremediation plan, within six months after the grant of this special permit. If factors\nbeyond Columbia Gulf's control prevent the completion of these tasks within six months,\nthe tasks must be completed as soon as practicable and a letter justifying the delay and\nproviding the anticipated date of completion must be submitted to the Director, PHMSA\nSouthern Region no later than six months after the grant of this special permit.\n22) Columbia Gulf must identify all shorted casings (metallic or electrolytic) within the special\npermit segments and special permit inspection areas no later than six months after the grant of\nthis special permit and classify any shorted casings as either having a \"metallic short\" (the carrier\npipe and the casing are in metallic contact) or an \"electrolytic short\" (the casing is filled with an\nelectrolyte) using a commonly accepted method such as the Panhandle Eastern, Pearson, DCVG,\nACVG or AC Attenuation.\n\n<<<PAGE 13>>>\n\na) Metallic Shorts: Columbia Gulf must clear any metallic short on a casing in the special\n13\npermit segments and special permit inspection areas no later than six months after the\nshort is identified.\nb) Electrolytic Shorts: Columbia Gulf must remove any electrolyte from the casing/pipe\nannular space on any casing in the special permit segments and special permit inspection\nareas that has an electrolytic short no later than six months after the short is identified.\nc) All Shorted Casings: Columbia Gulf must install external corrosion control test leads on\nboth the carrier pipe and the casing in accordance with § 192.471 to facilitate the future\nmonitoring for shorted conditions and may then choose to fill the casing/pipe annular\nspace with a high dielectric casing filler or other material which provides a corrosion\ninhibiting environment provided an assessment and all repairs were completed.\nIf Columbia Gulf identifies any shorted casings within the special permit segments and special\npermit inspection areas, they must monitor' all casings within the special permit segments and\nspecial permit inspection areas for shorts at least once each calendar quarter, but at intervals not\nto exceed 100 days, for four consecutive calendar quarters after the grant of this special permit.\nThe intent is to identify through monitoring the calendar quarters) when electrolytic casing shorts\nare most likely to be identified. Columbia Gulf must then monitor all casings for shorts within\nthe special permit segments and special permit inspection areas at least once each calendar year\nduring the calendar quarters) when electrolytic casing shorts are most likely to be identified.\nAny casing shorts found in the special permit segments and special permit inspection areas at\nany time must be classified and cleared as explained above.\n23) Pipe Seam Evaluations: Columbia Gulf must identify any pipeline in the special permit\nsegments and special permit inspection area that may be susceptible to pipe seam issues because\nof the vintage of the pipe, the manufacture of the pipe, or other issues. Once Columbia Gulf has\nidentified such issues, they must complete one or all of the following:\na) Columbia Gulf must perform an engineering analysis to determine if there are any pipe\nseam threats on the Mainline 200 & 300 pipelines located in the special permit segments\nand special permit inspection area. This analysis must include the documentation that the\nprocesses in 'M Charts' in \"Evaluating the Stability of Manufacturing and Construction\nDefects in Natural Gas Pipelines\" by Kiefner and Associates updated April 26, 2007,\n' Monitoring of casings in this situation means an acceptable test method in accordance with 49 CFR Part 192 to\ndetermine if the casing and carrier pipe have either a metallic or electrolytic short (connection or contact).\n\n<<<PAGE 14>>>\n\n14\nunder PHMSA Contract DTFAA-COSPO2120 and Figure 4.2, 'Framework for\nEvaluation with Path for the Segment Analyzed Highlighted' from TTO-5 \"Low\nFrequency ERW and Lap Welded Longitudinal Seam Evaluation\" by Michael Baker Jr.,\nand Kiefner and Associates, et. al. under PHMSA Contract DTRS56-02-D-70036 were\nutilized along with other relevant materials. If the engineering analysis shows that the\npipe seam issues on the Mainline 200 & 300 pipelines located in the special permit\nsegments and special permit inspection area are not a threat to the integrity of the\npipeline, Columbia Gulf does not have to complete Conditions 23 (b) through 23 (e). If\nthere is a seam integrity threat to the integrity of the pipeline, then one or more of\nConditions 23 (b) through 23 (e) must be completed;\nb) The special permit segment pipeline must be hydrostatically tested to a minimum pressure\nof 100 percent SMYS, per 49 CFR Part 192, Subpart J requirements for eight continuous\nhours, within one year of issuance of this special permit if no 49 CFR Part 192, Subpart J\ntest has been performed since 1971. The hydrostatic test must confirm no systemic issues\nwith the weld seam or pipe. A root cause analysis, including metallurgical examination of\nthe failed pipe, must be performed for any failure experienced to verify that it is not\nindicative of a systemic issue. The results of this root cause analysis must be reported to\neach PHMSA pipeline safety region office where the pipe is in service within 60 days of\nthe failure; or\nc) If the pipeline in the special permit inspection area has experienced a seam leak or failure\nin the last five years and no hydrostatic test meeting the conditions per 49 CFR Part 192,\nSubpart J was performed after the seam leak or failure, then a hydrostatic test must be\nperformed within one year after the grant of this special permit on the special permit\nsegment pipeline; and\nd) If the pipeline in the special permit segment has any LF ERW seam or EFW seam\nconditions as noted in (i), (ii), or (il) below, the special permit segment pipeline must be\nreplaced:\ni) constructed or manufactured prior to 1954 and has had any pipe seam leaks or ruptures\nin the special permit inspection area,\nii) has unknown manufacturing processes, or\niii) has known manufacturing or construction issues that are unresolved [such as\nconcentrated hard spots, hard heat-affected weld zones, selective seam corrosion, pipe\nmovement that has led to buckling, have had past leak and rupture issues, or any other\n\n<<<PAGE 15>>>\n\nother systemic issues].\n15\ne) If the pipeline in the special permit segment has a reduced longitudinal joint seam factor,\nbelow 1.0, as defined in § 192.113 the special permit segment pipeline must be replaced.\nf) All pipe in special permit segments and special permit inspection areas must have all\nweld seam or girth weld repairs that have been made by the usage of fittings such as\nweldolets, threadolets, repair clamps and pipe sleeves removed and replaced with pipe in\naccordance with 49 CFR Part 192 requirements.\n24) Columbia Gulf must comply with the following requirements.\na) Columbia Gulf must mechanically and hydrostatically test pipe in each special permit\nsegment that does not meet Condition 25 (b) as follows:\ni) Test a minimum of 10% of pipe lengths/joints, or at least 2 pipe lengths/joints when\nthe percentage is less than 2 pipe lengths/joints, in accordance with §§ 192.109 and\n192.107(b).\nii) Special permit segments pipe must meet the requirements of § 192.107 (b).\niii) Special permit segments pipe must be tested for mechanical and chemical properties\n(properties) as required in § 192, Appendix B, Section III (B) and (C).\niv) Pipe that is tested for properties in accordance with Condition 24 (a) (i),(a) (ii) and\n(a)(iii), must meet the hydrostatic test requirements of 49 CFR Part 192, Appendix B,\nSection III (C)(2). Original Class 1 location pipe that is approved for Class 3\nlocations per this special permit must be tested to a minimum of 100% SMYS for 8\ncontinuous hours in accordance with 49 CFR Part 192, Subpart J.\nv) The requirements in Condition 24 (a) must be completed within one year of issuance\nof this special permit and must meet pipe properties requirements for the pipe\ndesigned class location factor in accordance with §§ 192.103. 192.105, 192.107,\n192.109, 192.111 and 192.113.\nb) Columbia Gulf must complete within six (6) months of the grant of this special permit a\ndepth of cover survey of the special permit segments. For any pipe in the special permit\nsegments that does not meet § 192.327(a), Columbia Gulf must implement additional\nsafety measures in areas with reduced depth of cover. Columbia Gulf must submit to the\nDirector, PHMSA Southern Region remedial measures to implement based upon the\nthreat, such as lowering the pipeline, increased pipeline patrols and/or additional line\nmarkers.\n\n<<<PAGE 16>>>\n\nc) Columbia Gulf must install and maintain line-of-sight markings on the pipeline in the\n16\nspecial permit segments and special permit inspection areas except in agricultural areas\nor large water crossings such as lakes where line-of-sight signage is not practical.\nd) Columbia Gulf must install pipeline warning tape above the pipe for the length of the\nexcavation in all integrity excavations in the special permit segments and special permit\ninspection areas.\n25) Columbia Gulf must maintain the following records for each special permit segment:\na) Documentation showing that each special permit segment has received a § 192.505,\nSubpart J, hydrostatic test for 8 continuous hours and at a minimum pressure of 1.25 X\nMAOP. If Columbia Gulf does not have hydrostatic test documentation, then the special\npermit segment must be hydrostatically tested to meet this requirement within one year of\nreceipt of this special permit.\nb) Documentation (mill test reports) showing that the pipe in each special permit segments\nmeets the wall thickness, yield strength, tensile strength and chemical composition of\neither the American Petroleum Institute Standard 5L, 5LX or 5LS, \"Specification for Line\nPipe\" (API 5L) referenced in 49 CFR Part 192 at the time of manufacturing or if pipe was\nmanufactured and placed in-service prior to the inception of 49 CFR Part 192 then the\npipe meets the API 5L standard in usage at that time. Any special permit segment that\ndoes not have mill test reports for the pipe can not be authorized per this special permit\nunless it is qualified in accordance with Condition 24 (a) above.\nc) Documentation of compliance with all conditions of this special permit must be kept for\nthe applicable life of this special permit for the referenced special permit segments and\nspecial permit inspection areas.\n26) PHMSA may extend the original special permit segments to include contiguous segments of the\nMainline 200 & 300 pipelines up to the limits of the special permit inspection areas pursuant to\nthe following conditions. Columbia Gulf must:\na) Provide notice to the Director, PHMSA Southern Region, and PHMSA Headquarters of\nan extension request of the Mainline 200 & 300 special permit segments based on actual\nclass location change, and include a schedule of inspections and of any anticipated\nremedial actions. All requests for special permit segment extensions must be submitted\nin the first nine (9) months of the § 192.611(d) timing limits. If PHMSA Headquarters or\n\n<<<PAGE 17>>>\n\nRegion Director makes a written objection before the effective date of the requested\n17\nspecial permit segments extension (90 days from receipt of the above notice), the\nrequested special permit extension does not b","truncated":true,"body_characters":48779}