Controlling potential far‐field brine leakage from CO₂ storage formations using deep extraction wells: Numerical and experimental testing

Abstract

Injecting CO 2 into deep geologic formations for storage purposes induces large pressure build-up that risks caprock integrity. Naturally occurring faults or pressure-induced fractures in the caprock can act as conductive leakage pathways resulting in potential contamination of the overlying shallow aquifers. Previous studies explored using brine extraction to manage such elevated pressure in the storage formation. In this paper, we extended the use of this technique to control far-field brine leakage. Extraction wells are placed in the storage zone to reduce the leakage flow through reversing the pressure-gradient locally, while minimizing the brine concentrations in the escaped-fraction by utilizing the dilution capacity of the overlying formations. The developed approach incorporated the Genetic Algorithm with transport model simulations to optimize well-placements and extraction-rates. An approximately 8m long intermediate-scale tank designed to mimic brine leakage migration in the field was used to validate this approach as field data are not available. We further evaluated the approach numerically using a hypothetical leakage scenario at the Vedder storage formation in San-Joaquin basin to assess its practicality for field implementation. The results showed that storage zone heterogeneity and fractures' permeabilities can significantly affect the optimum locations and pumping rates of the extraction wells. Brine leakage can be controlled by extracting a native-brine volume less than 50% of the injected CO 2 volume. The target concentrations in the shallow aquifer determines the extraction rates required to control a leakage through a fracture or a buried thrust fault. The study is useful to develop remediation strategies for carbon storage operations.

A New Calculation Method of Well Leakage in Gas Well with Annular Pressure

“…One of the important reasons for causing annular pressure is the failure of pipe integrity, and the rate of annular leakage is one of the most core parameters for determining whether the integrity of gas wells has failed [4][5][6] . Due to the problems of high temperature, high pressure and sour gas, how to safely and effectively determine the leakage area and leakage rate of gas wells in the annulus is currently facing technical challenges [7,8] .…”