Core flooding laboratory experiment validates numerical simulation of induced permeability change in reservoir sandstone

Bartels, J.; Kühn, Michael; Schneider, W.; Clauser, Christoph; Pape, H.; Meyn, Volker; Lajcsak, Ivo

doi:10.1029/2002gl014901

Cited by 20 publications

(22 citation statements)

References 7 publications

(11 reference statements)

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“…The mineral deposit developed in this case on geological time scales. On the contrary, an exponent of 12.0 has been determined in core flooding laboratory experiments, representing the technical time scale, where anhydrite re-located (dissolved and subsequently precipitated) within a temperature front (Bartels et al 2002). Note that permeability calculated from porosity using Kozeny-Carman type of equation assumes that tortuosity is constant.…”

Section: Effect Of Temperaturementioning

confidence: 99%

CO2 injection into saline carbonate aquifer formations I: laboratory investigation

et al. 2007

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Although there are a number of mathematical modeling studies for carbon dioxide (CO 2 ) injection into aquifer formations, experimental studies are limited and most studies focus on injection into sandstone reservoirs as opposed to carbonate ones. This study presents the results of computerized tomography (CT) monitored laboratory experiments to analyze permeability and porosity changes as well as to characterize relevant chemical reactions associated with injection and storage of CO 2 in carbonate formations. CT monitored experiments are designed to model fast near well bore flow and slow reservoir flows. Highly heterogeneous cores drilled from a carbonate aquifer formation located in South East Turkey were used during the experiments. Porosity changes along the core plugs and the corresponding permeability changes are reported for different CO 2 injection rates and different salt concentrations of formation water. It was observed that either a permeability increase or a permeability reduction can be obtained. The trend of change in rock properties is very case dependent because it is related to distribution of pores, brine composition and thermodynamic conditions. As the salt concentration decreases, porosity and the permeability decreases are less pronounced. Calcite deposition is mainly influenced by orientation, with horizontal flow resulting in larger calcite deposition compared to vertical flow.

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Section: Effect Of Temperaturementioning

confidence: 99%

CO2 injection into saline carbonate aquifer formations I: laboratory investigation

et al. 2007

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“…In the lab experiment a sandstone drill core of 0.5 m length was prepared with anhydrite, and a thermal gradient was established by heating the inflow area to 80°C and the outflow area to 100°C. The purpose of the study was to quantify the relocation of anhydrite (first dissolution and then precipitation) within a thermal gradient and determining the resulting porosity and permeability changes over a time span of nearly 20 days (474 h; Bartels et al 2002). Laboratory measurements and the simulation results were very similar and showed that permeability in the inflow area increased, and anhydrite precipitation correlated positively with low permeability parts of the core (Fig.…”

Section: Validation Of the Numerical Codementioning

confidence: 86%

Coupled Process Models as a Tool for Analysing Hydrothermal Systems

et al. 2009

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Hydrothermal systems are characterised by complex interactions between heat transfer, fluid flow, deformation, species transport and chemical reactions. Numerical models can provide quantitatively constrained information in regions where acquisition of new data is difficult or expensive thus providing a means for reducing risks, costs, and effort during targeting, production, and management of resources linked to hydrothermal systems. Here we show how numerical simulations of hydrothermal processes can be used to better understand coupled reactive transport in modern geothermal systems and in ancient hydrothermal ore deposits.

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“…It simulates the physical and chemical processes at a thermal front propagating through a reservoir by making temperature, pressure, flow rate and salinity in a sandstone core comparable to the conditions in a deep geothermal hot-water reservoir. The model is verified by comparison of simulation results with porosity and permeability observed after the core flooding experiment (Bartels et al 2002). The experiment was performed on a core of Bentheim sandstone, which is a very clean quartz sandstone, cemented by quartz.…”

Section: Reactive Flow With Permeability Feedbackmentioning

confidence: 91%

Reactive flow and permeability prediction — numerical simulation of complex hydrogeothermal problems

Bartels

Clauser

Kühn

et al. 2005

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Simulating complex flow situations in hydrogeothermal reservoirs requires coupling of flow, heat transfer, transport of dissolved species, and heterogeneous geochemistry. We present results of simulations for typical applications using the numerical simulator SHEMAT/Processing SHEMAT. Heat transfer is non-linear, since all thermal fluid and rock properties depend on temperature. Due to the coupling of fluid density with both temperature and concentrations of dissolved species, the model is well suited to simulate density-driven flow.Dissolution and precipitation of minerals are calculated with an improved version of the geochemical modelling code PHRQPITZ, which accurately calculates geochemical reactions in brines of low to high ionic strength and temperatures of 0-150°C. Changes in pore space structure and porosity are taken into account by updating permeability with respect to porosity changes due to precipitation and dissolution of minerals. This is based on a novel relationship between porosity and pen~neability, derived from a fractal model of the pore space structure and its changes due to chemical water-rock interaction.A selection of model studies performed with SHEMAT completes the review. Examples highlight both density-driven and reactive flow with permeability feedback. With respect to the former, the thermohaline free convection Elder's problem, and density-driven free convection in a coastal aquifer with geothermal exploitation, are considered. Mineral redistribution and associated permeability change during a core flooding experiment; reaction front fingering in reservoir sandstone; and long-term changes in reservoir properties during the operation of a geothermal installation, are all considered in relation to reactive flow with permeability feedback.

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Core flooding laboratory experiment validates numerical simulation of induced permeability change in reservoir sandstone

Cited by 20 publications

References 7 publications

CO2 injection into saline carbonate aquifer formations I: laboratory investigation

CO2 injection into saline carbonate aquifer formations I: laboratory investigation

Coupled Process Models as a Tool for Analysing Hydrothermal Systems

Reactive flow and permeability prediction — numerical simulation of complex hydrogeothermal problems

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