Research Article | OPEN ACCESS
Modeling CO2-H2-S Corrosion of Tubular at Elevated Pressure and Temperature
Rida Elgaddafi, Ramadan Ahmed and Subhash Shah
University of Oklahoma, Sarkeys Energy Center, 100 Boyd St, Room 1180, Norman, OK 73019, USA
Research Journal of Applied Sciences, Engineering and Technology 2016 7:510-524
Received: November ‎11, ‎2015 | Accepted: February ‎10, ‎2016 | Published: October 05, 2016
Abstract
This study is aimed at improving carbon steel corrosion prediction in CO2-H2S environment. Corrosion is one of the major challenges faced by the oil and gas industry. This is mainly because of corrosive nature of formation fluids. Often produced hydrocarbons are accompanied by brine containing acidic gases such as carbon dioxide and hydrogen sulfide. A number of CO2-H2S corrosion models have been developed to predict corrosion of carbon steel under low-pressure (partial pressures of CO2- and H2-S less than 12 and 30 bar, respectively) and low-temperature. These models overestimate corrosion rate at high-pressure and high-temperature (HPHT) due to the application of the Henry’s law in predicting solubility of CO2 and H2S in NaCl solution (brine) under HPHT. In this study, an improved corrosion model, which utilizes thermodynamic based gas solubility model, has been developed to predict concentration of corrosive gases (CO2 and H2S) in brine solution saturated with natural gas. The corrosion model is verified using experimental data available in the literature. Predominantly, model predictions show good agreement with corrosion rate measurements obtained under various conditions.
Keywords:
Corrosion, tubular, carbon dioxide , hydrogen sulfide , pressure , temperature,
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Competing interests
The authors have no competing interests.
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