Materials Performance Supplements

Corrosion Management for Pipeline Integrity 2018

Materials Performance is the world's most widely circulated magazine dedicated to corrosion prevention and control. MP provides information about the latest corrosion control technologies and practical applications for every industry and environment.

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15 CORROSION MANAGEMENT FOR PIPELINE INTEGRIT Y SUPPLEMENT TO MP MATERIALS PERFORMANCE JUNE 2018 To develop a successful field joint coat- ing system, the engineer needs to consider additional factors such as specifying the correct product to ensure compatibility of the material to the mainline coating, and the overall coating system's performance with respect to pipeline operating condi- tions. The corrosion rate depends on vari- ous parameters, including but not limited to pipeline operating temperatures, soil or water conductivity, external accelerators, acids and alkalis, microbiologically inf lu- enced corrosion, chemical attack, stray cur- rent corrosion, and pipeline stresses that lead to stress corrosion cracking. Based on the nature of the parent coat- ing or factor y-applied coating, the field joint coating system may consist of single or multiple layers of selected protective coating materials. These are applied for numerous purposes that include corrosion control, mechanical protection, thermal insulation, and adhesion. While there are a variety of materials used as a pipeline field joint coating, the following are the most predominantly used and specified systems for pipeline protection: cold applied poly- meric tape, polyethylene (PE) and polypro- pylene (PP) heat shrink sleeves used in con- j u n c t i o n w i t h o r w i t h o u t a p r i m e r, fusion-bonded epoxy (FBE), liquid epoxy, PP coatings applied on FBE, PE coatings applied on FBE, polychloroprene coatings, polyurethane (PUR), three-layer polyeth- ylene coatings (3LPE), three-layer polypro- pylene coatings (3LPP), and three-layer polyolefin coatings (3LPO). Standard for Field Joint Coatings All coatings have distinct advantages and disadvantages, with many property and characteristic variables that should be taken into consideration. There have been many developments in recent years regard- ing standards for field joint coating sys- tems. In 2016, the second edition of ISO 21809 1 was published. This standard speci- fies the requirements for a field joint coat- ing on seamless or welded steel pipes for buried and submerged sections of pipeline transportation systems used in the petro- l eum , p etro ch emi cal , and natural ga s industries as defined in ISO 13623. 2 ISO 21809 has clear definitions, scopes, requirements, and recommendations for engineers to follow. For example, it elabo- rates on surface preparation techniques; material selection; material testing; mate- rial field testing; acceptance and rejection criteria requirements for joint preparation and repairs; and testing methods such as thickness checks, holiday detection, peel stren g th , a d h e sion t e stin g, h o t wat er immersion testing, degree of cure, cathodic disbondment, impact resistance, indenta- tion resistance, oxidation induction times, and flexibility. It is essential that the pipeline is fully protected from corrosion so petroleum products are contained, and this standard is a major leap in achieving this. References 1 ISO 21809-3:2016, "Petroleum and natural gas industries—External coatings for buried or submerged pipelines used in pipeline trans- portation systems—Part 3: Field joint coat- ings" (Geneva, Switzerland: ISO, 2016). 2 ISO 13623:2009, "Petroleum and natural gas industries—Pipeline transportation systems" (Geneva, Switzerland: ISO, 2009). About the Author Lee Wilson is a corrosion specialist with Corrosion Control and Solutions, Tyne and Wear, United Kingdom, email: wilsonlee78@ outlook.com. A NACE member for more than 10 years and a Fellow of ICorr, Wilson is also a NACE International-certified Corrosion Specialist; Coating Inspector—Levels 1, 2, and 3; Protective Coating Specialist; and Senior Corrosion Technologist. Focus on the implementation and management of an integrity program for a pipeline system. Serving as the key engineering training track for the PCIM engineer, taking this course demonstrates to employers that you're dedicated to extending the life of their pipelines and taking the first step in becoming NACE certified. The course covers: § Components of pipeline integrity § Overview of CFR 49 and integrity requirements § Risk assessment and technical challenges § Integrity verification and assessment § Remediation activities, repair methods § Inspection and assessment intervals § Post-integrity assessment risk analysis Pipeline Corrosion Integrity Management Implement a Corrosion Management Strategy Visit nace.org/courses for complete course description.

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