Chemical changes in fluid composition due to CO2 injection in the Altmark gas field: preliminary results from batch experiments

Huq, Farhana; Blum, Philipp; Marks, Michael A.W.; Nowak, Marcus; Haderlein, Stefan B.; Grathwohl, Peter

doi:10.1007/s12665-012-1687-y

Cited by 25 publications

(16 citation statements)

References 41 publications

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“…These suggestions are in accordance with PHREEQC calculations by Huq et al (2012) on the Rotliegend sandstones of the Altmark. Their considerations were made on batch experiments on the same sample set and at most similar test conditions like described in this contributions.…”

Section: Discussionsupporting

confidence: 89%

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The chemical dissolution and physical migration of minerals induced during CO2 laboratory experiments: their relevance for reservoir quality

et al. 2015

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The characterization of the quality and storage capacity of geological underground reservoirs is one of the most important and challenging tasks for the realization of carbon capture and storage (CCS) projects. One approach for such an evaluation is the upscaling of data sets achieved by laboratory CO 2 batch experiments to field scale. (Sub)-microscopic, petrophysical, tomographic, and chemical analytical methods were applied to reservoir sandstone samples from the Altmark gas field before and after static autoclave batch experiments at reservoir-specific conditions to study the relevance of injected CO 2 on reservoir quality. These investigations confirmed that the chemical dissolution of pore-filling mineral phases (carbonate, anhydrite), associated with an increased exposure of clay mineral surfaces and the physical detachment and mobilization of such clay fines (illite, chlorite) are most appropriate to modify the quality of storage sites. Thereby the complex interplay of both processes will affect the porosity and permeability in opposite ways-mineral dissolution will enhance the rock porosity (and permeability), but fine migration can deteriorate the permeability. These reactions are realized down to *lm scale and will affect the fluidrock reactivity of the reservoirs, their injectivity and recovery rates during CO 2 storage operations.

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Section: Discussionsupporting

confidence: 89%

“…Their considerations were made on batch experiments on the same sample set and at most similar test conditions like described in this contributions. Therefore, the results of Huq et al (2012) can also be applied to the investigations presented here and anhydrite dissolution even at Altmark reservoir conditions is most likely.…”

Section: Discussionmentioning

confidence: 93%

The chemical dissolution and physical migration of minerals induced during CO2 laboratory experiments: their relevance for reservoir quality

et al. 2015

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“…CO 2 -water-rock studies using ultra-pure distilled water as the reaction fluid indicate geochemical impacts will be more extensive during geological CO 2 storage in lowsalinity formations (e.g. Ketzer et al, 2009;Huq et al, 2012;Terzi et al, 2014). While such studies provide conceptual insights into geological CO 2 storage in low-salinity reservoirs, further research is required to constrain long-term reaction pathways and identify potential tracers of CO 2 migration under representative sequestration conditions.…”

Section: Salinity and Co 2 Storagementioning

confidence: 99%

“…Johnson et al, 2004;Allen et al, 2005;Druckenmiller and Maroto-Valer, 2005;Xu et al, 2005;Zerai et al, Chemical Geology 399 (2015) [123][124][125][126][127][128][129][130][131][132][133] 2006; Ketzer et al, 2009;Huq et al, 2012;Okuyama et al, 2013). Due to the prevalence of saline waters in deep reservoirs and the jurisdictional moratoria on CCS in fresher aquifers, fewer studies have explicitly examined low-salinity formations under CO 2 storage conditions (e.g.…”

Section: Introductionmentioning

confidence: 99%

Characterizing long-term CO 2 –water–rock reaction pathways to identify tracers of CO 2 migration during geological storage in a low-salinity, siliciclastic reservoir system

2015

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“…Uncertainties involved in the process have necessitated wide interest in the various phenomena, comprising but not limited to the following areas: monitoring of the fate of CO 2 once injected , Eigestad et al, 2009, Lindeberg and Bergmo, 2003, Nordbotten et al, 2005a, Nordbotten et al, 2005b, Pruess, 2008a, Pruess, 2008b, Xu et al, 2006; reservoir containment and capacity estimation , Kopp et al, 2009, Liao and Shangguan, 2009, Nunez-Lopez et al, 2008, Okwen et al, 2010, Wei and Saaf, 2009, Zhou et al, 2008; pressure build-up (Birkholzer et al, 2009, Mathias et al, 2009b, Rutqvist et al, 2007, Streit and Hillis, 2004, Streit, 2002 and for brine formations, fluid displacement (Nicot et al, 2009, Nicot, 2008. Other areas of concern comprise geochemical/chemical issues such as changes in fluid composition following the injection of CO 2 (Huq et al, 2012) and diagenesis due to fluid-rock interactions . Potential areas for CO 2 storage include depleted oil and gas reservoirs, coal bed seams and deep saline formations.…”

Section: Introductionmentioning

confidence: 99%

Carbon dioxide injection and associated hydraulic fracturing of reservoir formations

Eshiet

Sheng

2013

Environ Earth Sci

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The storage potential of subsurface geological systems makes them viable candidates for long term disposal of significant quantities of CO 2 . The geo-mechanical responses of these systems as a result of injection processes as well as the protracted storage of CO 2 are aspects that require sufficient understanding. A hypothetical model has been developed that conceptualises a typical well-reservoir system comprising an injection well where the fluid (CO 2 ) is introduced and a production/abandoned well sited at a distant location. This was accomplished by adopting a numerical methodology (Discrete Element Method), specifically designed to investigate the geo-mechanical phenomena whereby the various processes are monitored at the inter-particle scale. Fracturing events were simulated. In addition, the influence of certain operating variables such as injection flow rate and fluid pressure was studied with particular interest in the nature of occurring fractures and trend of propagation, the pattern and magnitude of pressure build-up at the well vicinity, pressure distribution between well regions and pore velocity distribution between well regions.Modelling results generally show an initiation of fracturing caused by tensile failure of the rock material at the region of fluid injection; however, fracturing caused by shear failure becomes more dominant at the later stage of injection. Furthermore, isolated fracturing events were observed to occur at the production/abandoned wells that were not propagated from the injection point. This highlights the potential of CO 2 introduced through an injection well, which could be used to enhance oil/gas recovery at a distant production well. The rate and magnitude of fracture development is directly influenced by the fluid injection rate. Likewise, the magnitude of pressure build-up is greatly affected by the fluid injection rate and the distance from the point of injection.The DEM modelling technique illustrated provides an effective procedure that allows for more specific investigations of geo-mechanical mechanisms occurring at sub-surface systems. The application of this 2 Corresponding Author:Address: School of Civil Engineering, University of Leeds, UK e-mail: y.sheng@leeds.ac.uk 2 methodology to the injection and storage of CO 2 facilitates the understanding of the fracturing phenomenon as well as the various factors governing the process.

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Chemical changes in fluid composition due to CO2 injection in the Altmark gas field: preliminary results from batch experiments

Cited by 25 publications

References 41 publications

The chemical dissolution and physical migration of minerals induced during CO2 laboratory experiments: their relevance for reservoir quality

The chemical dissolution and physical migration of minerals induced during CO2 laboratory experiments: their relevance for reservoir quality

Characterizing long-term CO 2 –water–rock reaction pathways to identify tracers of CO 2 migration during geological storage in a low-salinity, siliciclastic reservoir system

Carbon dioxide injection and associated hydraulic fracturing of reservoir formations

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