Rapid reactions between CO2, brine and silicate minerals during geological carbon storage : modelling based on a field CO2 injection experiment

Bickle, Mike and Kampman, Niko and Chapman, Hazel and Ballentine, Chris and Dubacq, Benoit and Galy, Albert and Sirikitputtisak, Tule and Warr, Oliver and Wigley, Max and Zhou, Zheng (2017) Rapid reactions between CO2, brine and silicate minerals during geological carbon storage : modelling based on a field CO2 injection experiment. Chemical Geology, 468. pp. 17-31. ISSN 0009-2541

[thumbnail of 1-s2.0-S0009254117304291-main]
PDF (1-s2.0-S0009254117304291-main)
1_s2.0_S0009254117304291_main.pdf - Accepted Version
Available under License Creative Commons Attribution-NonCommercial-NoDerivs.

Download (1MB)


The dissolution of CO2 into formation brines and the subsequent reactions of the CO2-charged brines with reservoir minerals are two key processes likely to increase the security of geological carbon-dioxide storage. These processes will be dependent on the permeability structure and mineral compositions of the reservoirs, but there is limited observational data on their rates. In this paper we report the cation and anion concentrations and Sr, oxygen and carbon isotopic compositions of formation waters from four extraction wells sampled at surface, over ~ 6 months after commencement of CO2 injection in a five spot pattern for enhanced oil recovery at the Salt Creek field, Wyoming. Sampled fluids, separated from the minor oil component, exhibit near-monotonic increases in alkalinity and concentrations of cations but little change in Cl and Br concentrations and oxygen and deuterium isotope ratios. The increases in alkalinity are modelled in terms of reaction with reservoir calcite and silicate minerals as the changes in fluid chemistry and Sr-isotopic compositions are inconsistent with simple addition of injected fluids sampled over the course of the experiment. The reservoir mineral chemical and isotopic compositions are characterised by sampling core as well as surface exposures of the Frontier Formation elsewhere in Wyoming. The evolution of the fluid chemistries reflects extensive dissolution of both carbonate and silicate minerals over the course of the six months sampling implying rapid dissolution of CO2 in the formation waters and reaction of CO2-bearing brines with formation minerals. Rates of CO2 diffusion into the brines and advection of CO2 charged brines in the reservoir are sufficiently slow that, if present, calcite should react to be close to equilibrium with the fluids. This allows estimation of the CO2 partial pressures in the sampled fluids and comparison with the thermodynamic driving force for the relatively rapid average plagioclase dissolution rates of ~ 10− 12 mol·m− 2·s− 1.

Item Type:
Journal Article
Journal or Publication Title:
Chemical Geology
Additional Information:
This is the author’s version of a work that was accepted for publication in Chemical Geology. Changes resulting from the publishing process, such as peer review, editing, corrections, structural formatting, and other quality control mechanisms may not be reflected in this document. Changes may have been made to this work since it was submitted for publication. A definitive version was subsequently published in Chemical Geology, 468, 2017 DOI: 10.1016/j.chemgeo.2017.07.031
Uncontrolled Keywords:
?? geological carbon storageco2 injection experimentfluid-mineral reactionsplagioclase dissolution ratesenhanced oil recoverygeochemistry and petrologygeology ??
ID Code:
Deposited By:
Deposited On:
08 Aug 2017 10:12
Last Modified:
31 Dec 2023 00:50