Hydrofracking and Internal Corrosion Problems Identification and Confirmation in Shale Oil and Gas Production

Abstract Large volumes of fresh water when used for fracking of hydrocarbon producing horizons in oil and gas operations, unexpectedly comes with a heavy price tag with operational and safety implications. This paper identifies the essential on-site and laboratory testing protocols required to confirm both the extent and breadth of the array of internal corrosion drivers created downhole and transported to surface production pipelines in shale formations. Companion samples, when collected simultaneously and then subsequently site and lab tested for water chemistries, petrographic analysis (i.e. solids assaying) and genomic testing, will reliably and confidently provide the necessary insight of the actual drivers promoting internal OCTG (oilfield country tubular goods) and pipeline corrosion. The characterization of water chemistry wear-metals and contaminants, solids composition, particle sizes, densities and microbial speciation is essential for establishing the "corrosion story" before a failure occurs, if proactively applied. Sampling, testing, and confirmation of the presence of chemical, biological and mineral contaminants in hydrofracked oil or gas production effluent is essential to effect a pipeline integrity validation using advanced ICDA protocols like NACE SP0110-2024 WG-ICDA and NACE SP0116-2022 MP-ICDA. From there, credible internal corrosion predictive modeling can be achieved to positively identify, confirm, and mitigate the internal corrosion problems associated with hydrofracking.