{"operation":"document","citation":"PHMSA Guidance, Corrosion Enforcement Guidance Part 195","title":"Corrosion Enforcement Guidance Part 195","source_type":"guidance","agency":"Pipeline and Hazardous Materials Safety Administration","status":"guidance","official":true,"published_on":"2016-06-22","effective_on":"2016-06-22","summary":"Corrosion Enforcement Guidance Part 195 Document Corrosion_Enforcement_Guidance_Part195_6_22_2016.pdf (1014.97 KB) The Federal pipeline safety regulations (49 CFR Parts 190-199) discussed in this guidance document contains legally binding requirements. This document is not a regulation and creates no new legal obligations. The regulation is controlling. The materials in this document are explanatory in nature and ref","machine_formats":{"json":"https://regulus.evalyn.ai/document/phmsa-guidance-corrosion-enforcement-guidance-part-195-66b04819.json","markdown":"https://regulus.evalyn.ai/document/phmsa-guidance-corrosion-enforcement-guidance-part-195-66b04819.md"},"app_url":"https://regulus.evalyn.ai/document/phmsa-guidance-corrosion-enforcement-guidance-part-195-66b04819","source_url":"https://www.phmsa.dot.gov/pipeline/enforcement/corrosion-enforcement-guidance-part-195","body":"Corrosion Enforcement Guidance Part 195\n\nDocument\n\n Corrosion_Enforcement_Guidance_Part195_6_22_2016.pdf (1014.97 KB)\n\n        The Federal pipeline safety regulations (49 CFR Parts 190-199) discussed in this guidance document contains legally binding requirements. This document is not a regulation and creates no new legal obligations. The regulation is controlling. The materials in this document are explanatory in nature and reflect PHMSA’s current application of the regulations in effect at the time of the issuance of the guidance. In preparing an enforcement action alleging a probable violation, an allegation must always be based on the failure to take a required action (or taking a prohibited action) that is set forth directly in the language of the regulation. An allegation should never be drafted in a manner that says the operator “violated the guidance.”\n\n          Issued Date: Wednesday, June 22, 2016\n\n<<<PAGE 1>>>\n\nPart 195 Corrosion Enforcement Guidance\nIntroduction\nThe materials contained in this document consist of guidance, techniques, procedures and other information for\ninternal use by the PHMSA pipeline safety enforcement staff. This guidance document describes the practices\nused by PHMSA pipeline safety investigators and other enforcement personnel in undertaking their\ncompliance, inspection, and enforcement activities. This document is U.S. Government property and is to be\nused in conjunction with official duties.\nThe Federal pipeline safety regulations (49 CFR Parts 190-199) discussed in this guidance document contains\nlegally binding requirements. This document is not a regulation and creates no new legal obligations. The\nregulation is controlling. The materials in this document are explanatory in nature and reflect PHMSA’s\ncurrent application of the regulations in effect at the time of the issuance of the guidance. In preparing an\nenforcement action alleging a probable violation, an allegation must always be based on the failure to take a\nrequired action (or taking a prohibited action) that is set forth directly in the language of the regulation. An\nallegation should never be drafted in a manner that says the operator “violated the guidance.”\nNothing in this guidance document is intended to diminish or otherwise affect the authority of PHMSA to\ncarry out its statutory, regulatory or other official functions or to commit PHMSA to taking any action that is\nsubject to its discretion. Nothing in this document is intended to and does not create any legal or equitable\nright or benefit, substantive or procedural, enforceable at law by any person or organization against PHMSA,\nits personnel, State agencies or officers carrying out programs authorized under Federal law.\nDecisions about specific investigations and enforcement cases are made according to the specific facts and\ncircumstances at hand. Investigations and compliance determinations often require careful legal and\ntechnical analysis of complicated issues. Although this guidance document serves as a reference for the staff\nresponsible for investigations and enforcement, no set of procedures or policies can replace the need for\nactive and ongoing consultation with supervisors, colleagues, and the Office of Chief Counsel in\nenforcement matters.\nComments and suggestions for future changes and additions to this guidance document are invited and\nshould be forwarded to your supervisor.\nThe materials in this guidance document may be modified or revoked without prior notice by PHMSA\nmanagement.\n1\n\n<<<PAGE 2>>>\n\nPart 195 Corrosion Enforcement Guidance\nTable of Contents\nPress <Ctrl><Home> keys to return to TOC\nGlossary……………………………………………………………………………………………………….4\n§195.551 What do the regulations in this subpart cover? ..................................................................... 5\n§195.553 What special definitions apply to this subpart? ..................................................................... 7\n§195.555 What are the qualifications for supervisors? ......................................................................... 8\n§195.557 Which pipelines must have coating for external corrosion control? Section 195.557(a)..10\n§195.557 Which pipelines must have coating for external corrosion control? Section 195.557(b)..11\n§195.559 What coating materials may I use for external corrosion control? Section 195.559(a) ...... 13\n§195.559 What coating materials may I use for external corrosion control? Section 195.559(b) ...... 15\n§195.559 What coating materials may I use for external corrosion control? Section 195.559(c) ....... 17\n§195.559 What coating materials may I use for external corrosion control? Section 195.559(d) ...... 19\n§195.559 What coating materials may I use for external corrosion control? Section 195.559(e) ...... 21\n§195.559 What coating materials may I use for external corrosion control? Section 195.559(f) ....... 23\n§195.561 When must I inspect pipe coating used for external corrosion control? Section 195.561(a) .......... 25\n§195.561 When must I inspect pipel coating for external corrosion control? Section 195.561(b) ................. 27\n§195.563 Which pipelines must have cathodic protection? Section 195.563(a) ................................ 29\n§195.563 Which pipelines must have cathodic protection? Section 195.563(b) ................................ 31\n§195.563 Which pipelines must have cathodic protection? Section 195.563(c) ................................. 33\n§195.563 Which pipelines must have cathodic protection? Section 195.563(d) ................................ 35\n§195.563 Which pipelines must have cathodic protection? Section 195.563(d) ................................ 37\n§195.565 How do I install cathodic protection on breakout tanks? ..................................................... 38\n§195.567 Which pipelines must have test leads and what must I do to install and maintain the leads? Section\n195.567(a) .......................................................................................................................................................... 40\n§195.567 Which pipelines must have test leads and what must I do to install and maintain the leads? Section\n195.567(b) .......................................................................................................................................................... 42\n§195.567 Which pipelines must have test leads and what must I do to install and maintain the leads? Section\n195.567(c) .......................................................................................................................................................... 45\n§195.569 Do I have to examine exposed potions of buried pipelines?............................................... 47\n§195.571 What criteria must I use to determine the adequacy of cathodic protection? ..................... 49\n§195.573 What must I do to monitor external corrosion control? Section 195.573(a) ........................ 54\n§195.573 What must I do to monitor external corrosion control? Section 195.573(b) ........................ 57\n§195.573 What must I do to monitor external corrosion control? Section 195.573(c) ........................ 59\n§195.573 What must I do to monitor external corrosion control? Section 195.573(d) ........................ 61\n§195.573 What must I do to monitor external corrosion control? Section 195.573(e) ........................ 63\n§195.575 Which facilities must I electrically isolate and what inspections, tests,and safeguards are\nrequired? Section 195.575(a) .............................................................................................................. 66\n§195.575 Which facilities must I electrically isolate and what inspections, tests and safeguards are\nrequired? Section 195.575(b) .............................................................................................................. 68\n§195.575 Which facilities must I electrically isolate and what inspections, tests and safeguards are\nrequired? Section 195.575(c)............................................................................................................... 70\n§195.575 Which facilities must I electrically isolate and what inspections, tests and safeguards are\nrequired? Section 195.575(d) .............................................................................................................. 72\n2\n\n<<<PAGE 3>>>\n\n§195.575 Which facilities must I electrically isolate and what inspections, tests and safeguards are\nrequired? Section 195.575(e) .............................................................................................................. 73\n§195.577 What must I do to alleviate interference currents? Section 195.577(a) ............................. 75\n§195.577 What must I do to alleviate interference currents? Section 195.577(b) ............................. 77\n§195.579 What must I do to mititage internal corrosion? Section 195.579(a) .................................... 79\n§195.579 What must I do to mitigate internal corrosion? Section 195.579(b) .................................... 81\n§195.579 What must I do to mitigate internal corrosion? Section 195.579(c) .................................... 83\n§195.579 What must I do to mitigate internal corrosion? Section 195.579(d) .................................... 85\n§195.581 Which pipelines must I protect against atmospheric corrosion and what coating material\nmay I use? Section 195.581(a) ........................................................................................................... 87\n§195.581 Which pipelines must I protect against atmospheric corrosion and what coating material\nmay I use? Section 195.581(b) ........................................................................................................... 89\n§195.581 Which pipelines must I protect against atmospheric corrosion and what coating material\nmay I use? Section 195.581(c) ........................................................................................................... 90\n§195.583 What must I do to monitor atmospheric corrosion control? Section 195.583(a) ................. 92\n§195.583 What must I do to monitor atmospheric corrosion control? Section 195.583(b) ................. 94\n§195.583 What must I do to monitor atmospheric corrosion control? Section 195.583(c) ................. 99\n§195.585 What must I do to correct corroded pipe? Section 195.585(a) ........................................101\n§195.585 What must I do to correct corroded pipe? Section 195.585(b)...……..….………...….…103\n§195.587 What methods are available to determine the strength of corroded pipe? .......................105\n§195.588 What Standards apply to direct assessment? Section 195.588 (a) ………….………..106\n§195.588 What Standards apply to direct assessment? Section 195.588 (b)(1) ……….……… 108\n§195.588 What Standards apply to direct assessment? Section 195.588 (b)(2)(i) ….………… 110\n§195.588 What Standards apply to direct assessment? Section 195.588 (b)(2)(ii) ….……….. .113\n§195.588 What Standards apply to direct assessment? Section 195.588 (b)(2)(iii) ….…….… 115\n§195.588 What Standards apply to direct assessment? Section 195.588 (b)(3)(i) ….……… ..... 117\n§195.588 What Standards apply to direct assessment? Section 195.588 (b)(3)(ii) …….…..…..119\n§195.588 What Standards apply to direct assessment? Section 195.588 (b)(3)(iii) …….….…..121\n§195.588 What Standards apply to direct assessment? Section 195.588 (b)(3)(iv) …….……...123\n§195.588 What Standards apply to direct assessment? Section 195.588 (b)(4)(i) …….…… ..... 125\n§195.588 What Standards apply to direct assessment? Section 195.588 (b)(4)(ii) ….……… .... 127\n§195.588 What Standards apply to direct assessment? Section 195.588 (b)(4)(iii) …….……...129\n§195.588 What Standards apply to direct assessment? Section 195.588 (b)(4)(iv) ….………...131\n§195.588 What Standards apply to direct assessment? Section 195.588 (b)(5)(i) ...….………..133\n§195.588 What Standards apply to direct assessment? Section 195.588 (b)(5)(ii) ..……….…..135\n§195.589 What corrosion control information do I have to maintain? Section 195.589(a)……...137\n§195.589 What corrosion control information do I have to maintain? Section 195.589(b)……...139\n§195.589 What corrosion control information do I have to maintain? Section 195.589(c) ............ 140\n3\n\n<<<PAGE 4>>>\n\nFor a complete “Glossary of Terms” please refer to the following link:\nhttp://www.phmsa.dot.gov/staticfiles/PHMSA/Pipeline/TQGlossary/Glossary.html\n4\n\n<<<PAGE 5>>>\n\nEnforcement\nGuidance Revision Date Code Section Section Title Existing Code\nLanguage\nOrigin of Code Last Amendment Interpretation\nSummaries\nAdvisory\nBulletin/Alert\nNotice Summaries\nOther Reference\nMaterial & Source\nGuidance\nInformation\nExamples of a\nProbable Violation\nor Inadequate\nProcedures\nExamples of\nEvidence\nCORROSION Part 195\n6 22 2016\n§195.551\nWhat do the regulations in this subpart cover?\nThis subpart prescribes minimum requirements for protecting steel pipelines against\ncorrosion.\nHLPLSA 1979\nAmdt. 195-73, 66 FR 66994, Dec. 27, 2001\nNACE SP0169-2007\n1. Hazardous liquid and carbon dioxide pipelines are almost exclusively made of\nsteel.\n2. §195.551characterizes the activities that are covered by the standards in subpart\nH (i.e., protecting steel pipelines against external, internal, and atmospheric\ncorrosion). Procedures for controlling corrosion are required by §195.402(a) and\n§195.402(c)(3) including those for the design, installation, operation and\nmaintenance of CP systems. The criteria for cathodic protection are delineated in\nNACE RP 0169-2002, (to be superseded by NACE SP 0169-2007, effective October\n1, 2010) which is incorporated by reference.\n1. The operator is transporting a hazardous liquid by a pipeline made of a material\nother than steel and has not notified the Administrator of the hazardous liquid to be\ntransported and material used in the construction of the pipeline. (This would be a\nviolation of 195.8, not 195.551.)\nDepending on the circumstances, some of the examples listed in this section may be\ninadequate plans and procedures, and not probable violations. Thus, the\nenforcement tool to address these issues would be a Notice of Amendment and not\na Notice of Probable Violation or a Warning Letter. Section 3 of the Enforcement\nProcedures provides guidance on selecting the appropriate enforcement action.\n1. Hazardous liquids properties, pipe specifications, mill reports, invoices.\n5\n\n<<<PAGE 6>>>\n\nOther Special\nNotations\nIn the case of a metallic pipeline made from a material other than steel, the operator\nis required to notify the Administrator a minimum of 90 days prior to transporting the\nliquid under 195.8.\n6\n\n<<<PAGE 7>>>\n\nEnforcement\nGuidance Revision Date Code Section Section Title Existing Code\nLanguage\nOrigin of Code Last Amendment Interpretation\nSummaries\nAdvisory\nBulletin/Alert\nNotice Summaries\nOther Reference\nMaterial & Source\nGuidance\nInformation\nExamples of a\nProbable Violation\nor Inadequate\nProcedures\nExamples of\nEvidence\nOther Special\nNotations\nCORROSION Part 195\n6 22 2016\n§195.553\nWhat special definitions apply to this subpart?\nThis section provides definitions of terms such as “active corrosion”, “electrical\nsurvey” and pipeline environment” used in subpart H. In addition, it establishes\ndefinitions of “buried” and “you.” The definition of “buried” reflects the common\ncorrosion control practice of treating any portion of pipe in contact with the earth as if\nthat portion were buried. The term “you” has the same meaning as “operator.” The\nterms “direct assessment” and “external corrosion direct assessment” as utilized in\nthe integrity management programs are also defined.\nHLPLSA 1979\nAmdt 195-73, 66 FR 66994, Dec. 27, 2001; Amdt 195-85, 70 FR 61571, Oct. 25,\n2005.\nNACE Standard SP0169-2007\n1. Glossary of Terms\n7\n\n<<<PAGE 8>>>\n\nEnforcement\nGuidance CORROSION Part 195\nRevision Date 6 22 2016\nCode Section §195.555\nSection Title What are the qualifications for supervisors?\nExisting Code\nLanguage\nYou must require and verify that supervisors maintain a thorough knowledge of that\nportion of the corrosion control procedures established under §195.403(c) for which\nthey are responsible for insuring compliance.\nOrigin of Code HLPLSA 1979\nLast Amendment Amdt 195-73, 66 FR 66994, Dec. 27, 2001\nInterpretation\nSummaries\nAdvisory\nBulletin/Alert\nNotice Summaries\nOther Reference\nNACE Standard SP0169-2007\nMaterial & Source\nGuidance\nInformation\n1. These persons shall have knowledge of the physical sciences and principles of\nengineering and mathematics, acquired by education and related practical\nexperience, and shall be qualified to engage in the practice of corrosion control for\nexternal, internal, and atmospheric corrosion.\n2. A qualified person may be a registered professional engineer whose professional\nactivities include suitable experience in corrosion or a person recognized as a\ncorrosion specialist or cathodic protection specialist by NACE, or\na person with practical experience and training equivalent to the applicable NACE\nrequirements.\nExamples of a\nProbable Violation\nor Inadequate\nProcedures\n1. The operator cannot provide documentation that its supervisors have thorough\nknowledge and/or experience appropriate for their responsibilities.\nDepending on the circumstances, some of the examples listed in this section may be\ninadequate plans and procedures, and not probable violations. Thus, the\nenforcement tool to address these issues would be a Notice of Amendment and not\na Notice of Probable Violation or a Warning Letter. Section 3 of the Enforcement\nProcedures provides guidance on selecting the appropriate enforcement action.\nExamples of\n1. Position descriptions, documentation of training and experience.\nEvidence\n8\n\n<<<PAGE 9>>>\n\nOther Special\nNotations\nOperators may have a hierarchy of personnel responsible for ensuring adequate\ncorrosion control practices are applied to the company’s pipelines. Different\n(operator) supervisors may be responsible for various aspects of the operator’s\ncorrosion control program. The supervisor(s) discussed in this regulation are the\nresponsible person(s) who review actual field data for compliance and make\ndecisions concerning remedial action.\nIf the operator does not have qualified personnel, it may utilize the services of a\ncompetent, qualified contractor or consultant.\n9\n\n<<<PAGE 10>>>\n\nEnforcement\nGuidance Revision Date Code Section Section Title Existing Code\nLanguage\nOrigin of Code Last Amendment Interpretation\nSummaries\nAdvisory\nBulletin/Alert\nNotice Summaries\nOther Reference\nMaterial & Source\nGuidance\nInformation\nExamples of a\nProbable Violation\nor Inadequate\nProcedures\nExamples of\nEvidence\nOther Special\nNotations\nCORROSION Part 195\n6 22 2016\n§195.557(a)\nWhich pipelines must have coating for external corrosion control?\nExcept bottoms of aboveground breakout tanks, each buried or submerged pipeline\nmust have an external coating for external corrosion control if the pipeline is:\nConstructed, relocated, replaced, or otherwise changed after the applicable date in\n§195.401(c), not including the movement of pipe covered by §195.424.\nHLPLSA 1979\nAmdt 195-73, 66 FR 66994, Dec. 27, 2001\nNACE Standard SP0169-2007\n1. The operator must document the date its pipeline was constructed, relocated,\nreplaced, or otherwise changed.\n1. The operator has a pipeline that does not have an external coating and was\nconstructed, relocated, replaced, or otherwise changed after the applicable dates of\ninstallation in section 195.401(c).\nDepending on the circumstances, some of the examples listed in this section may be\ninadequate plans and procedures, and not probable violations. Thus, the\nenforcement tool to address these issues would be a Notice of Amendment and not\na Notice of Probable Violation or a Warning Letter. Section 3 of the Enforcement\nProcedures provides guidance on selecting the appropriate enforcement action.\n1. Construction/repair records.\n10\n\n<<<PAGE 11>>>\n\nEnforcement\nGuidance CORROSION Part 195\nRevision Date 6 22 2016\nCode Section §195.557(b)\nSection Title Which pipelines must have coating for external corrosion control?\nExisting Code\nLanguage\nExcept bottoms of aboveground breakout tanks, each buried or submerged pipeline\nmust have an external coating for external corrosion control if the pipeline is:\nConverted under §195.5 and;\n(1) Has an external coating that substantially meets §195.559 before the pipeline is\nplaced in service; or\n(2) Is a segment that is relocated, replaced, or substantially altered.\nOrigin of Code HLPLSA 1979\nLast Amendment Amdt 195-73, 66 FR 66994, Dec. 27, 2001\nInterpretation\nSummaries\nAdvisory\nBulletin/Alert\nNotice Summaries\nOther Reference\nNACE Standard SP0169-2007\nMaterial & Source\nGuidance\nInformation\n1. The operator should maintain pipeline design documents to demonstrate that an\nexternal coating is specified; and construction documents to demonstrate that the\ncoating was applied, and pipe dig/exposure reports to document that it is evaluating\nthe condition of the external coating on its pipeline whenever its buried pipeline is\nexposed.\nExamples of a\nProbable Violation\nor Inadequate\nProcedures\n1. The operator has not evaluated the existing coating of a converted pipeline to\ndetermine whether it substantially meets the requirements of §195.559.\n2. The operator has not coated a pipeline segment that is relocated, replaced, or\nsubstantially altered.\nDepending on the circumstances, some of the examples listed in this section may be\ninadequate plans and procedures, and not probable violations. Thus, the\nenforcement tool to address these issues would be a Notice of Amendment and not\na Notice of Probable Violation or a Warning Letter. Section 3 of the Enforcement\nProcedures provides guidance on selecting the appropriate enforcement action.\nExamples of\n1. Construction/repair records\nEvidence\n11\n\n<<<PAGE 12>>>\n\nOther Special\nNotations\nSection 195.5 allows up to 12 months for the operator to comply with the subpart H\nrequirements for a converted pipeline.\n12\n\n<<<PAGE 13>>>\n\nEnforcement\nGuidance CORROSION Part 195\nRevision Date 6 22 2016\nCode Section §195.559(a)\nSection Title What coating material may I use for external corrosion control?\nExisting Code\nLanguage\nCoating material for external corrosion control under §195.557 must:\nBe designed to mitigate corrosion of the buried or submerged pipeline.\nOrigin of Code HLPLSA 1979\nLast Amendment Amdt 195-73, 66 FR 66994, Dec. 27, 2001\nInterpretation\nSummaries\nAdvisory\nBulletin/Alert\nNotice Summaries\nOther Reference\nNACE SP0169-2007\nMaterial & Source\nGuidance\nInformation\n1. The operator’s procedures or specifications should require the use of a material\ndesigned for application to prevent corrosion of buried or submerged metallic\nstructures, including pipelines.\n2. The operator’s manual should address procedures on the use and application of\ncoatings such as: Hot-applied bituminous tapes, Petrolatum tapes, Wax tapes, etc.\nIf applicable, the operator’s manual should also address procedures on the use and\napplication of coatings used for weighting in submerged services or for insertion in\nbored/drilled crossings such as Concrete coatings and Abrasive Resistant over\ncoating.\n3. Some of the common types of pipeline coatings utilized in the industry include:\nFusion Bonded Epoxy, Coal Tar Enamel, Tape coatings, etc.; such coatings are\nwidely used throughout the pipeline industry and likely to be found in operators’\nmanuals.\n13\n\n<<<PAGE 14>>>\n\nExamples of a\n1. The operator does not have procedures regarding the selection of a proper\nProbable\nViolation or\nInadequate\nProcedures\ncoating.\n2. The operator has utilized a coating that does not possess the required corrosion\nmitigating properties.\nDepending on the circumstances, some of the examples listed in this section may be\ninadequate plans and procedures, and not probable violations. Thus, the\nenforcement tool to address these issues would be a Notice of Amendment and not\na Notice of Probable Violation or a Warning Letter. Section 3 of the Enforcement\nProcedures provides guidance on selecting the appropriate enforcement action.\nExamples of\n1. Coating specifications, O&M Manual\nEvidence\nOther Special\nNotations\nCoating specifications and procedures are usually reviewed during construction\ninspections or after an incident where failed coating is suspected.\n14\n\n<<<PAGE 15>>>\n\nEnforcement\nGuidance\nRevision Date Code Section Section Title Existing Code\nLanguage\nOrigin of Code Last Amendment Interpretation\nSummaries\nAdvisory\nBulletin/Alert\nNotice Summaries\nOther Reference\nMaterial & Source\nGuidance\nInformation\nExamples of a\nProbable Violation\nor Inadequate\nProcedures\nCORROSION Part 195\n6 22 2016\n§195.559(b)\nWhat coating material may I use for external corrosion control?\nCoating material for external corrosion control under §195.557 must:\nHave sufficient adhesion to the metal surface to prevent under film migration of\nmoisture.\nHLPLSA 1979\nAmdt 195-73, 66 FR 66994, Dec. 27, 2001\nNACE SP0169-2007; NACE Standard RP0394-2002; NACE Standard RP0402-\n2002; NACE Standard RP0375-99; NACE Standard RP0105-2005; NACE Standard\nRP0303-2003; NACE Standard RP0602-2002; NAPCA BULLETIN 16-94; 3M™\nScotchkote™ Fusion-Bonded Epoxy Coating 6233 Data Sheet; and 3M™\nScotchkote™ Fusion-Bonded Epoxy Coating 6233/206N/226N/226N+Field Joint\nApplication Guide.\n1. The operator’s procedures or specifications should require the use of a material\ndesigned for application to prevent corrosion of buried or submerged metallic\nstructures, including pipelines.\n1. The operator does not have procedures regarding the selection of a proper\ncoating.\n2. The operator has utilized a coating that does not possess the required adhesive\nproperties.\nDepending on the circumstances, some of the examples listed in this section may be\ninadequate plans and procedures, and not probable violations. Thus, the\nenforcement tool to address these issues would be a Notice of Amendment and not\na Notice of Probable Violation or a Warning Letter. Section 3 of the Enforcement\nProcedures provides guidance on selecting the appropriate enforcement action.\n15\n\n<<<PAGE 16>>>\n\nExamples of\nEvidence\n1. Coating specifications, O&M Manual, Review of any incident where insufficient\nadhesion of the coating may have been a contributing factor. Pictures of areas of\ndisbonded coating on relatively newly coated or recoated pipe.\nOther Special\nNotations\nProper surface preparation is critical for ensuring sufficient adhesion. The operator\nshould follow the manufacturer’s recommendations and applicable industry\nstandards to ensure adequate surface preparation.\nIn additions to the Other Ref. Material & Sources noted above, the following are\nexamples of additional source material for reference (including specific coating\nproducts, specific data sheet/ application and inspection specifications, and\nperformance criteria):\na. NAPCA BULLETIN 16-94\nNAPCA RECOMMENDED PRACTICE FOR\nSURFACE CONDITION OF PIPE AS\nRECEIVED AT THE COATING PLANT\nb. NAPCA Bulletin 17-98\nFBE Anomalies\nTrouble-Shooting Guide\nc. NAPCA Bulletin 6-69-94-2\nSUGGESTED PROCEDURES FOR\nCOATING OF GIRTH WELDS\nWITH FUSION BONDED EPOXY\nd. 3M™ Scotchkote™\nFusion-Bonded Epoxy Coating 6233/206N/226N/226N+\nField Joint Application Guide\n16\n\n<<<PAGE 17>>>\n\nEnforcement\nGuidance CORROSION Part 195\nRevision Date 6 22 2016\nCode Section §195.559(c)\nSection Title What coating material may I use for external corrosion control?\nExisting Code\nLanguage\nCoating material for external corrosion control under §195.557 must:\nBe sufficiently ductile to resist cracking.\nOrigin of Code HLPLSA 1979\nLast Amendment Amdt 195-73, 66 FR 66994, Dec. 27, 2001\nInterpretation\nSummaries\nAdvisory\nBulletin/Alert\nNotice Summaries\nOther Reference\nNACE SP0169-2007\nMaterial & Source\nGuidance\nInformation\n1. The operator’s procedures or specifications should require the use of a material\ndesigned for application to prevent corrosion of buried or submerged metallic\nstructures, including pipelines.\n2. Examples of specific coating products in use by pipeline operators include:\na. 3M™ Scotchkote™ Liquid Epoxy Coating 323P\nData Sheet and Application Instructions\nb. 3M™ Scotchkote™\nFusion-Bonded Epoxy Coating 6233\nData Sheet\nExamples of a\nProbable Violation\nor Inadequate\nProcedures\n1. The operator does not have procedures regarding the selection of a proper\ncoating.\n2. The operator has utilized a coating that does not possess the required cracking\nresistance.\nDepending on the circumstances, some of the examples listed in this section may be\ninadequate plans and procedures, and not probable violations. Thus, the\nenforcement tool to address these issues would be a Notice of Amendment and not\na Notice of Probable Violation or a Warning Letter. Section 3 of the Enforcement\nProcedures provides guidance on selecting the appropriate enforcement action.\n17\n\n<<<PAGE 18>>>\n\nExamples of\nEvidence\n1. Coating specifications, O&M Manual, Review of any incident where cracking of\nthe coating may have been a contributing factor.\nOther Special\nNotations\n18\n\n<<<PAGE 19>>>\n\nEnforcement\nGuidance CORROSION Part 195\nRevision Date 6 22 2016\nCode Section §195.559(d)\nSection Title What coating material may I use for external corrosion control?\nExisting Code\nLanguage\nOrigin of Code HLPLSA 1979\nCoating material for external corrosion control under §195.557 must:\nHave enough strength to resist damage due to handling and soil stress.\nLast Amendment Amdt 195-73, 66 FR 66994, Dec. 27, 2001\nInterpretation\nSummaries\nAdvisory\nBulletin/Alert\nNotice Summaries\nOther Reference\nNACE SP0169-2007\nMaterial & Source\nGuidance\nInformation\n1. The operator’s procedures or specifications should require the use of a material\ndesigned for application to prevent corrosion of buried or submerged metallic\nstructures, including pipelines.\n2. Examples of specific coating products in use by pipeline operators include:\na. 3M™ Scotchkote™ Liquid Epoxy Coating 323P\nData Sheet and Application Instructions\nb. 3M™ Scotchkote™\nFusion-Bonded Epoxy Coating 6233\nData Sheet\nExamples of a\nProbable Violation\nor Inadequate\nProcedures\n1. The operator does not have procedures regarding the selection of a proper\ncoating.\nproperties.\n2. The operator has utilized a coating that does not possess the required strength\nDepending on the circumstances, some of the examples listed in this section may be\ninadequate plans and procedures, and not probable violations. Thus, the\nenforcement tool to address these issues would be a Notice of Amendment and not\na Notice of Probable Violation or a Warning Letter. Section 3 of the Enforcement\nProcedures provides guidance on selecting the appropriate enforcement action.\n19\n\n<<<PAGE 20>>>\n\nExamples of\n1. Coating specifications, O&M Manual\nEvidence\nOther Special\nNotations\n20\n\n<<<PAGE 21>>>\n\nEnforcement\nGuidance CORROSION Part 195\nRevision Date 6 22 2016\nCode Section §195.559(e)\nSection Title Existing Code\nLanguage\nCoating material for external corrosion control under §195.557 must:\nSupport any supplemental cathodic protection.\nOrigin of Code HLPLSA 1979\nWhat coating material may I use for external corrosion control?\nLast Amendment Amdt 195-73, 66 FR 66994, Dec. 27, 2001\nInterpretation\nSummaries\nAdvisory\nBulletin/Alert\nNotice Summaries\nOther Reference\nNACE SP0169-2007\nMaterial & Source\nGuidance\nInformation\n1. The operator’s procedures or specifications should require the use of a material\ndesigned for application to prevent corrosion of buried or submerged metallic\nstructures, including pipelines.\n2. Examples of specific coating products in use by pipeline operators include:\na. 3M™ Scotchkote™ Liquid Epoxy Coating 323P\nData Sheet and Application Instructions\nb. 3M™ Scotchkote™\nFusion-Bonded Epoxy Coating 6233\nData Sheet\nExamples of a\n1. The operator does not have procedures regarding the selection of a proper\nProbable Violation\nor Inadequate\nProcedures\ncoating.\n2. The operator has utilized a coating that does not support supplemental cathodic\nprotection.\nDepending on the circumstances, some of the examples listed in this section may be\ninadequate plans and procedures, and not probable violations. Thus, the\nenforcement tool to address these issues would be a Notice of Amendment and not\na Notice of Probable Violation or a Warning Letter. Section 3 of the Enforcement\nProcedures provides guidance on selecting the appropriate enforcement action.\n21\n\n<<<PAGE 22>>>\n\nExamples of\n1. Coating specifications, O&M Manual\nEvidence\nOther Special\nNotations\n22\n\n<<<PAGE 23>>>\n\nEnforcement\nGuidance CORROSION Part 195\nRevision Date 6 22 2016\nCode Section §195.559(f)\nSection Title What coating material may I use for external corrosion control?\nExisting Code\nLanguage\nCoating material fo r external corrosion control under §195.557 must:\nIf the coating is an insulating type, have low moisture absorption and provide high\nelectrical resistance.\nOrigin of Code HLPLSA 1979\nLast Amendment Amdt 195-73, 66 FR 66994, Dec. 27, 2001\nInterpretation\nSummaries\nAdvisory\nBulletin/Alert\nNotice Summaries\nOther Reference\nNACE SP0169-2007\nMaterial & Source\nGuidance\nInformation\n1. The operator’s procedures or specifications should require the use of a material\ndesigned for application to prevent corrosion of buried or submerged metallic\nstructures, including pipelines.\n2. Examples of specific coating products in use by pipeline operators include:\na. 3M™ Scotchkote™ Liquid Epoxy Coating 323P\nData Sheet and Application Instructions\nb. 3M™ Scotchkote™\nFusion-Bonded Epoxy Coating 6233\nData Sheet\nExamples of a\nProbable Violation\nor Inadequate\nProcedures\n1. The operator does not have procedures regarding the selection of a proper\ncoating.\n2. The operator has utilized a coating that does not have the required moisture\nabsorption and insulating properties.\nDepending on the circumstances, some of the examples listed in this section may be\ninadequate plans and procedures, and not probable violations. Thus, the\nenforcement tool to address these issues would be a Notice of Amendment and not\na Notice of Probable Violation or a Warning Letter. Section 3 of the Enforcement\nProcedures provides guidance on selecting the appropriate enforcement action.\n23\n\n<<<PAGE 24>>>\n\nExamples of\n1. Coating specifications, O&M Manual\nEvidence\nOther Special\nNotations\n24\n\n<<<PAGE 25>>>\n\nEnforcement\nGuidance Revision Date Code Section Section Title Existing Code\nLanguage\nOrigin of Code Last Amendment Interpretation\nSummaries\nAdvisory\nBulletin/Alert\nNotice Summaries\nOther Reference\nMaterial & Source\nCORROSION Part 195\n6 22 2016\n§195.561(a)\nWhen must I inspect pipe coating used for external corrosion control?\nYou must inspect all external pipe coating required by § 195.557 just prior to\nlowering the pipe into the ditch or submerging the pipe.\nHLPLSA 1979\nAmdt 195-73, 66 FR 66994, Dec. 27, 2001\nNACE SP0169-2007\n25\n\n<<<PAGE 26>>>\n\nGuidance\nInformation\nExamples of a\nProbable Violation\nor Inadequate\nProcedures\nExamples of\nEvidence\nOther Special\nNotations\n1. Electrical testing is commonly known as “jeeping.”\n2. The voltage utilized for the electrical testing should be in accordance with the\nmanufacturer’s recommendations or applicable industry standards. The voltage may\nvary with coating thickness and type; such as over girth welds, fittings, or coating\nrepairs.\n3. Some examples of appropriate jeep settings for pipeline coatings can be found in\nthe following NACE Standards:\na. NACE SP0490-2007\nStandard Practice Holiday Detection of Fusion-Bonded Epoxy External\nPipeline Coatings of 250 to 760 μm (10 to 30 mil)\nb. NACE Standard RP0274-2004 Standard Recommended Practice\nHigh-Voltage Electrical Inspection of Pipeline Coatings\n4. Coating material damaged or improperly installed must be repaired.\n1. The operator did not inspect the coating prior to lowering into the ditch or\nsubmerging the pipe.\nDepending on the circumstances, some of the examples listed in this section may be\ninadequate plans and procedures, and not probable violations. Thus, the\nenforcement tool to address these issues would be a Notice of Amendment and not\na Notice of Probable Violation or a Warning Letter. Section 3 of the Enforcement\nProcedures provides guidance on selecting the appropriate enforcement action.\n1. O&M Manual, Maintenance records, Manufacturer’s maintenance\nrecommendations, photographs, construction records.\n26\n\n<<<PAGE 27>>>\n\nEnforcement\nGuidance Revision Date Code Section Section Title Existing Code\nLanguage\nOrigin of Code Last Amendment Interpretation\nSummaries\nAdvisory\nBulletin/Alert\nNotice Summaries\nOther Reference\nMaterial & Source\nCORROSION Part 195\n6 22 2016\n§195.561(b)\nWhen must I inspect pipe coating used for external corrosion control?\nYou must repair any coating damage discovered.\nHLPLSA 1979\nAmdt 195-73, 66 FR 66994, Dec. 27, 2001\nNACE SP0169-2007\n27\n\n<<<PAGE 28>>>\n\nGuidance\nInformation\nExamples of a\nProbable Violation\nor Inadequate\nProcedures\nExamples of\nEvidence\nOther Special\nNotations\n1. The operator must protect the coating from damage as it is being lifted, installed\ninto the ditch, and backfilled. The operator should maintain applicable procedures\nthat address areas such as the type of fabric slings with stringers that will be used to\nlift and place the pipe in the ditch; how the pipe is protected from rocks in the backfill,\netc. The operator’s procedures should also address protection of the pipeline in the\nditch, backfilling, and ditch padding. Supporting blocks used during construction\nshould be spaced so as to prevent damage to the coating where the blocks support\nthe pipe. Supporting blocks should not remain under the pipeline when it is\nbackfilled.\n2. The operator should have developed procedures for taking precautions to protect\nthe coating while installing pipe in such a manner. Some operators may elect to\ninstall an abrasion-resistant coating, such as various concrete materials, over the\ndielectric coating used for the cathodic protection. The operator should utilize an\nappropriate bore size/diameter ratio and a sufficient bend radius to minimize\npotential damage to the coating (and possibly to the pipe). The operator should also\ninspect for damage on the pipe visible in the bore’s exit pit. Damage noted to the\ncoating and/or pipe in the exit pit might indicate that additional undetected damage\nmay have occurred during the installation to the coating and/or the pipe that is not\nvisible. Note if the operator is doing any type of testing on the carrier pipe after\nboring or pulling to determine the effectiveness of the coating as a dielectric between\nthe casing or soil.\n3. Coating material damaged or improperly installed must be repaired.\n1. The operator did not properly repair coating damage discovered during an\ninspection.\nDepending on the circumstances, some of the examples listed in this section may be\ninadequate plans and procedures, and not probable violations. Thus, the\nenforcement tool to address these issues would be a Notice of Amendment and not\na Notice of Probable Violation or a Warning Letter. Section 3 of the Enforcement\nProcedures provides guidance on selecting the appropriate enforcement action.\n1. Manufacturer(s)’ inspection recommendations, O&M Manual, installation records,\nphotographs.\n28\n\n<<<PAGE 29>>>\n\nEnforcement\nGuidance CORROSION Part 195\nRevision Date 6 22 2016\nCode Section §195.563(a)\nSection Title Which pipeline must have cathodic protection?\nExisting Code\nLanguage\nEach buried or submerged pipeline that is constructed, relocated, replaced, or\notherwise changed after the applicable date in §195.401(c) must have cathodic\nprotection. The cathodic protection must be in operation not later than 1 year after\nthe pipeline is constructed, relocated, replaced, or otherwise changed, as applicable.\nOrigin of Code HLPLSA 1979\nLast Amendment Amdt 195-73, 66 FR 66994, Dec. 27, 2001\nInterpretation\nSummaries\nAdvisory\nBulletin/Alert\nNotice Summaries\nOther Reference\nNACE SP0169-2007\nMaterial & Source\nGuidance\nInformation\n1. The operator must install its pipeline in accordance with § 195.401(c). Any\npipeline ","truncated":true,"body_characters":205127}