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Modelling CO2-induced fluid–rock interactions in the Altensalzwedel gas reservoir. Part I: from experimental data to a reference geochemical model

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Abstract

Modelling fluid–rock interactions induced by CO2 is a key issue when evaluating the technical feasibility and long-term safety assessment of CO2 storage projects in deep formations. The German R&D programme CLEAN (CO2 Large-Scale Enhanced Gas Recovery in the Altmark Natural Gas Field) investigated the almost depleted onshore gas reservoir located in the Rotliegend sandstone at over 3,000-m depth. The high salinity of the formation fluids and the elevated temperature in the reservoir exceed the validity limits of commonly available thermodynamic databases needed for predictive geochemical modelling. In particular, it is shown that the activity model of Pitzer has to be applied, even if necessary input data for this model are incomplete or inconsistent for complex systems and for the considered temperatures. Simulations based on Debye-Hückel activity model lead to severe, systematic discrepancies already in the simple proposed reference case where experimental data could be used for comparison. A simplified geochemical model, consistent with the average measured composition of formation fluids and the prevailing mineralogical assemblage of the host rock, identifies the mineral phases most likely to be considered at equilibrium with the formation fluid. The simulated reactions due to CO2 injection, under the hypothesis of local thermodynamical equilibrium, result in a moderate reactivity of the system, with the dissolution of anhydrite cementation and haematite being the most relevant expected mineral reactions. This is compensated, at equilibrium, by the precipitation of new carbonates, like calcite and siderite, for an overall very small loss of porous space. The simulated rather small effect of mineral alteration is also due to the scarce amount of water available for reactions in the reservoir. The results of the model are qualitatively in line with observations from batch experiments and from natural analogues.

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Notes

  1. The ionic strength constitutes a measure of non-ideality of a concentrated solution, and is defined as: \(I=\frac{1}{2} \sum_i z_i^2 C_i ; C\) is the concentration in moles per kg water and z the specific charge of the i-th solute species.

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Acknowledgments

This study is part of the joint research project CLEAN, sponsored by the German Federal Ministry of Education and Research (BMBF) within the framework of the geoscientific research and development program "GEOTECHNOLOGIEN" (Grant No. 03G0704). The authors thank GDF SUEZ E&P DEUTSCHLAND GMBH for research collaboration within this program. The authors also thank the GRS for fruitful discussions in the context of the database compilation.

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Authors and Affiliations

  1. Helmholtz Centre Potsdam, GFZ German Research Centre for Geosciences, Telegrafenberg, 14473, Potsdam, Germany

    Marco De Lucia & Michael Kühn

  2. Institute of Geosciences, Geohydromodelling, CAU Christian Albrechts University of Kiel, Ludewig-Meyn-Str. 10, 24118, Kiel, Germany

    Sebastian Bauer & Christof Beyer

  3. Federal Institute for Geosciences and Natural Resources (BGR), Stilleweg 2, 30655, Hannover, Germany

    Thomas Nowak & Susanne Stadler

  4. Friedrich-Schiller-Universität Jena, Institute of Earth Sciences, Burgweg 11 D, 07749, Jena, Germany

    Dieter Pudlo

  5. Institute of Petroleum Engineering, Clausthal University of Technology, Agricolastraße 10, 38678, Clausthal-Zellerfeld, Germany

    Viktor Reitenbach

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  1. Marco De Lucia
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  2. Sebastian Bauer
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  3. Christof Beyer
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  4. Michael Kühn
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  8. Susanne Stadler
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Correspondence to Marco De Lucia.

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De Lucia, M., Bauer, S., Beyer, C. et al. Modelling CO2-induced fluid–rock interactions in the Altensalzwedel gas reservoir. Part I: from experimental data to a reference geochemical model. Environ Earth Sci 67, 563–572 (2012). https://doi.org/10.1007/s12665-012-1725-9

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