Alireza Salehi’s Post

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Senior Material, Corrosion and Welding Engineer at Subsea7

When dealing with Top of Line Corrosion (TLC) in gas pipelines, operators often face operational reliability challenges and significant economic hurdles. The choice of external anticorrosion coating plays a critical role in managing TLC severity, particularly affecting the Overall Heat Transfer Coefficient (OHTC) on infield subsea flowlines. Gas temperature decrease correlates with increased TLC severity, prompting considerations for temperature reductions at pipeline inlets to boost Water Condensation Rate (WCR) in initial segments where 625 CRA clad utilized in these areas in smaller amount. Considering the lower WCR downstream, where TLC rates are less severe Carbon Steel (CS) with ample Corrosion Allowance (CA) and ensuring at least 95% Corrosion Inhibitor Availability (CIA) proves to be a cost-effective solution, given the extensive pipeline length. Fusion Bonded Epoxy (FBE) and Thermally Spray Aluminium (TSA) coatings, with lower OHTC, are suitable for rigid spools and early-stage flowlines, while 3LPP emerges as a viable choice for external corrosion protection along the pipeline. #PipelineCorrosion #Corrosion #TLC #PipelineCoating #SubseaPipeline #CorrosionManagement #MaterialSelection #IntegrityManagement

  • Courtesy of AIE
Amir Attarchi

CEng | MICorr | NACE Corrosion Specialist | Materials Technology Lead at Saipem

6mo

I don’t take corrosion inhibitor as a barrier to Top of Line Corrosion, it does have no impact or a very little impact on TLC. In fact, managing TLC during operation is quite challenging, but it should be studied and managed through design phase.

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