Review of Internal Corrosion Mechanisms in an Onshore Production Pipeline: a Case Study from the Eagle Ford Basin

Abstract This paper presents a comprehensive review of internal corrosion mechanisms observed in an 8-inch API 5L X52M onshore production line located in the Eagle Ford Basin. The pipeline, which transports multiphase fluids from a three well pad, exhibited signs of accelerated internal corrosion within the first year of operation. The review integrates metallurgical analysis, microbial DNA sequencing, and operational data to evaluate the contributing factors. Evidence of microbiologically influenced corrosion (MIC) was confirmed through DNA analysis, revealing the presence of sulfate-reducing and iron-oxidizing bacteria which could have been sourced from stagnant hydrotest water or the reservoir. Additionally, the presence of CO2 in the gas phase was identified as a contributor to the corrosion environment. Metallurgical examination revealed characteristic MIC pitting morphologies, while scale composition and flow conditions supported the potential for CO2 corrosion. This case study highlights the importance of proactive corrosion management strategies in new pipeline systems, including proper hydrotest water handling, early implementation of chemical treatment programs, and continuous monitoring. The findings provide valuable insights for improving internal corrosion control in similar onshore production environments.