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51318-11261-Aqueous Simulation Provides Additional Evidence for Corrosion in Horizontal Casing Failures

Picture for Aqueous Simulation Provides Additional Evidence for Corrosion in Horizontal Casing Failures
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Operators are experiencing severe pitting corrosion on horizontal casing in the Eagle Ford region. Using aqueous modeling, it is possible to simulate the corrosion that would occur in the presence of those species.

Product Number: 51318-11261-SG
Author: Tracey Jackson
Publication Date: 2018
Industry: Oil and Gas Production
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$20.00
$20.00

Operators are experiencing severe pitting corrosion on horizontal casing in the Eagle Ford region. The most severe pitting was estimates and ~240 mpy (~6.60 mm/yr) based on linear extrapolation. For the well of interest the toe sleeve was opened and perforated to perform a small acid fracturing job. The well was then filled with 1% KCI containing biocide. The process leaves the well open to the reservoir but in non-flowing condition. Five months after initial completions work, corrosion was observed when completions were resumed. Two limited inspections were performed showing pitting near the middle of the horizontal section with no corrosion closer to the vertical section. The question was to determine the if the damage in the horizontal section could be due to fluid in the well (1% wt. KCI) mixing with formation fluids (containing 1mol% CO2 and formation brine which included high amounts of acetic and propionic acids). Using aqueous modeling, it is possible to simulate the corrosion that would occur in the presence of those species.

Key Words: well horizontal, CO2 corrosion, organic acids, aqueous modeling,

 

Operators are experiencing severe pitting corrosion on horizontal casing in the Eagle Ford region. The most severe pitting was estimates and ~240 mpy (~6.60 mm/yr) based on linear extrapolation. For the well of interest the toe sleeve was opened and perforated to perform a small acid fracturing job. The well was then filled with 1% KCI containing biocide. The process leaves the well open to the reservoir but in non-flowing condition. Five months after initial completions work, corrosion was observed when completions were resumed. Two limited inspections were performed showing pitting near the middle of the horizontal section with no corrosion closer to the vertical section. The question was to determine the if the damage in the horizontal section could be due to fluid in the well (1% wt. KCI) mixing with formation fluids (containing 1mol% CO2 and formation brine which included high amounts of acetic and propionic acids). Using aqueous modeling, it is possible to simulate the corrosion that would occur in the presence of those species.

Key Words: well horizontal, CO2 corrosion, organic acids, aqueous modeling,

 

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