Next Article in Journal
Saffman–Taylor Instability in Yield Stress Fluids: Theory–Experiment Comparison
Previous Article in Journal
DEM/CFD Simulations of a Pseudo-2D Fluidized Bed: Comparison with Experiments
Previous Article in Special Issue
Instability of a Diffusive Boundary Layer beneath a Capillary Transition Zone
Article Menu

Export Article

Open AccessArticle

Innovative CO2 Injection Strategies in Carbonates and Advanced Modeling for Numerical Investigation

1
Foundation Ciudad de la Energía (CIUDEN), Avenida del Presidente Rodríguez Zapatero, 24492 Cubillos del Sil, Spain
2
Geogreen, 2 Rue des Martinets, 92500 Rueil-Malmaison, France
*
Author to whom correspondence should be addressed.
Fluids 2019, 4(1), 52; https://doi.org/10.3390/fluids4010052
Received: 15 January 2019 / Revised: 6 March 2019 / Accepted: 8 March 2019 / Published: 16 March 2019
(This article belongs to the Special Issue Fundamentals of CO2 Storage in Geological Formations)
  |  
PDF [14215 KB, uploaded 26 March 2019]
  |  

Abstract

Carbon sequestration in deep saline aquifers was recently developed at the industrial scale. CO2 injection experiences in carbonates are quite limited, most of them coming from projects carried out in porous mediums in the USA and Canada. Hontomín (Spain) is the actual on-shore injection pilot in Europe, being a naturally fractured carbonate reservoir where innovative CO2 injection strategies are being performed within the ENOS Project. CO2 migration through the fracture network existing on site produces hydrodynamic, mechanical and geochemical effectsdifferent from those caused by the injection in mediums with a high matrix permeability. The interpretation of these effects is required to design safe and efficient injection strategies in these formations. For this, it is necessary to determine the evolution of pressure, temperature and flow rate during the injection, as well as the period of pressure recovery during the fall-off phase. The first results from the not-continuous injections (8–24 h) conducted at Hontomín reveal the injection of liquid CO2 (density value of 0.828 t/m3) and the fluid transmissivity through the fractures. Taking into account the evolution of the pressure and flow rate showed variations of up to 23% and 30% respectively, which means that the relevant changes of injectivity took place. The results were modeled with a compositional dual media model which accounts for both temperature effects and multiphase flow hysteresis because alternative brine and CO2 injections were conducted. Advanced modeling shows the lateral extension of CO2 and the temperature disturbance away from the well. View Full-Text
Keywords: CO2 storage; fracture network; injection strategies; evolution of pressure; temperature and flow rate; compositional dual media model CO2 storage; fracture network; injection strategies; evolution of pressure; temperature and flow rate; compositional dual media model
Figures

Figure 1

This is an open access article distributed under the Creative Commons Attribution License which permits unrestricted use, distribution, and reproduction in any medium, provided the original work is properly cited (CC BY 4.0).
SciFeed

Share & Cite This Article

MDPI and ACS Style

de Dios, J.C.; Le Gallo, Y.; Marín, J.A. Innovative CO2 Injection Strategies in Carbonates and Advanced Modeling for Numerical Investigation. Fluids 2019, 4, 52.

Show more citation formats Show less citations formats

Note that from the first issue of 2016, MDPI journals use article numbers instead of page numbers. See further details here.

Article Metrics

Article Access Statistics

1

Comments

[Return to top]
Fluids EISSN 2311-5521 Published by MDPI AG, Basel, Switzerland RSS E-Mail Table of Contents Alert
Back to Top