Review: Role of chemistry, mechanics, and transport on well integrity in CO2 storage environments

The potential leakage of CO 2 from a geological storage site through existing wells represents a major concern. An analysis of well distribution in the Viking Formation in the Alberta basin, a mature sedimentary basin representative for North American basins, shows that a CO 2 plume and/or acidified brine may encounter up to several hundred wells. If carbon dioxide is geologically stored in regions, such as this, that have experienced intensive exploration for petroleum products, the acidified brine will come into contact with numerous abandoned wells. Corrosion of the cement that seals the well could lead to rapid leakage, so it is essential to determine the duration and intensity of exposure to the acid. Detailed numerical simulations with Dynaflow, incorporating a flash calculation to find the phase distribution and speciation in the brine, indicate that the carbonated brine may spend years in contact with the cement in abandoned wells. Preliminary results from an ongoing experimental study of cement corrosion indicate that the rate of attack is rapid, when the pH of the solution is low, so the risk of leakage will be high if the acidic brine can flow through an annulus and bring fresh acid into contact with the cement.

Leakage of CO 2 Through Abandoned Wells: Role of Corrosion of Cement

Class C fly ash-based alkali activated cement as a potential alternative cement for CO2 storage applications

High-level integrity assessment of abandoned wells

Cement Core Experiments With a Conductive Leakage Pathway, Under Confining Stress and Alteration of Cement's Mechanical Properties Via a Reactive Fluid, as an Analog for CO2 Leakage Scenario

Effects Of C02 Attack on Cement in High-Temperature Applications

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Effects Of C02 Attack on Cement in High-Temperature Applications