Different effects of temperature and salinity on permeability reduction by fines migration in Berea sandstone

Rosenbrand, Esther; Kjøller, Claus; Riis, Jacob Fabricius; Kets, F.; Fabricius, Ida Lykke

doi:10.1016/j.geothermics.2014.06.004

Cited by 97 publications

(47 citation statements)

References 37 publications

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“…A further possible source of variability is the effect of chemical and structural pore space alteration over time. Depending on the flow conditions, on the salinity, acidity, and temperature of the brine and on the minerals present in the rock, fines migration and mineral dissolution or precipitation can take place [55][56][57].…”

Section: A Repeatability Of Pore-filling States In Experimentsmentioning

confidence: 99%

Validation of model predictions of pore-scale fluid distributions during two-phase flow

et al. 2018

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Pore-scale two-phase flow modeling is an important technology to study a rock's relative permeability behavior. To investigate if these models are predictive, the calculated pore-scale fluid distributions which determine the relative permeability need to be validated. In this work, we introduce a methodology to quantitatively compare models to experimental fluid distributions in flow experiments visualized with microcomputed tomography. First, we analyzed five repeated drainage-imbibition experiments on a single sample. In these experiments, the exact fluid distributions were not fully repeatable on a pore-by-pore basis, while the global properties of the fluid distribution were. Then two fractional flow experiments were used to validate a quasistatic pore network model. The model correctly predicted the fluid present in more than 75% of pores and throats in drainage and imbibition. To quantify what this means for the relevant global properties of the fluid distribution, we compare the main flow paths and the connectivity across the different pore sizes in the modeled and experimental fluid distributions. These essential topology characteristics matched well for drainage simulations, but not for imbibition. This suggests that the pore-filling rules in the network model we used need to be improved to make reliable predictions of imbibition. The presented analysis illustrates the potential of our methodology to systematically and robustly test two-phase flow models to aid in model development and calibration.

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Section: A Repeatability Of Pore-filling States In Experimentsmentioning

confidence: 99%

Validation of model predictions of pore-scale fluid distributions during two-phase flow

et al. 2018

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“…Areas which face this problem include hydrology, where the focus is on water production [McDowell et al, 1986;Bradford et al, 2001;Torkzaban et al, 2007], geothermal engineering, where cold water is pumped through subsurface reservoirs to produce warm water [Mahmoudi et al, 2010;Rosenbrand et al, 2014;Rosenbrand et al, 2015], wellbore drilling [Byrne et al 2007, Civan 2007] and petroleum recovery, where water is injected to maintain reservoir pressure and mobilize additional hydrocarbons by viscous forces [Ahmed and McKinney, 2005;and Iglauer et al 2010]. …”

Section: Introductionmentioning

confidence: 99%

“…the water must not contain solid particles which are larger than a certain maximum size [Bennion 1998]. It is thus important to understand the particles' impact on fluid dynamics and associated pore-scale plugging mechanisms, which cause the formation damage [Nowark and Krueger, 1951;Krueger et al 1967;McDowell et al, 1986;Ryan and Elimelech, 1996;Civan 2007;Rosenbrand et al, 2014 and2015].…”

Section: Introductionmentioning

confidence: 99%

Pore-scale analysis of formation damage in Bentheimer sandstone with in-situ NMR and micro-computed tomography experiments

Al-Yaseri

Lebedev

Vogt

et al. 2015

Journal of Petroleum Science and Engineering

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Iglauer, Pore-scale analysis of formation damage in Bentheimer sandstone with in-situ NMR and micro-computed tomography experiments, Journal of Petroleum Science and Engineering, http://dx. AbstractWe investigated fines movement through sandstone in-situ at the micrometre pore scale and studied the associated pore-scale mechanisms leading to formation damage. We used two insitu techniques to accomplish this, namely nuclear magnetic resonance T 2 relaxation time (NMR) measurements (of pore size distributions) and high resolution x-ray micro-computed tomography (µCT; at high resolutions of (0.89µm) 3 and (3.4µm) 3 ). The µCT images showed the precise 3D location of the fines particles in the plug and demonstrated that initially pore throats are plugged, followed by filling of adjacent pore bodies by solid particles. These measurements in combination with traditionally used (indirect) permeability and production curve measurements and ex-situ SEM imaging enabled us to propose a new mechanistic pore-scale plugging model; furthermore we demonstrated that the amount of fines trapped decayed rapidly with core depth. We conclude that it is feasible to analyse formation damage in-situ by a combination of NMR and µCT measurements. AbstractWe investigated fines movement through sandstone in-situ at the micrometre pore scale and studied the associated pore-scale mechanisms leading to formation damage. We used two insitu techniques to accomplish this, namely nuclear magnetic resonance T 2 relaxation time (NMR) measurements (of pore size distributions) and high resolution x-ray micro-computed tomography (µCT; at high resolutions of (0.89µm) 3 and (3.4µm) 3 ). The µCT images showed the precise 3D location of the fines particles in the plug and demonstrated that initially pore throats are plugged, followed by filling of adjacent pore bodies by solid particles. These measurements in combination with traditionally used (indirect) permeability and production curve measurements and ex-situ SEM imaging enabled us to propose a new mechanistic pore-scale plugging model; furthermore we demonstrated that the amount of fines trapped decayed rapidly with core depth. We conclude that it is feasible to analyse formation damage in-situ by a combination of NMR and µCT measurements.

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“…Investigations on formation damages due to particle redistribution in sandstone reservoirs were performed and the existence of a critical flow rate was confirmed by Ochi and Vernoux (1998). Rosenbrand et al (2015) attributed the reduction of the permeability of reacted sandstones to the migration of fine particles, depending on the salinity of the percolating fluid and temperature. Another study shows that the decrease in permeability of kaolinite containing sandstones is related to the dissolution and re-precipitation of the kaolinite (Rosenbrand et al 2014).…”

mentioning

confidence: 95%

Flow-through experiments on the interaction of sandstone with Ba-rich fluids at geothermal conditions

et al. 2017

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Different effects of temperature and salinity on permeability reduction by fines migration in Berea sandstone

Cited by 97 publications

References 37 publications

Validation of model predictions of pore-scale fluid distributions during two-phase flow

Validation of model predictions of pore-scale fluid distributions during two-phase flow

Pore-scale analysis of formation damage in Bentheimer sandstone with in-situ NMR and micro-computed tomography experiments

Flow-through experiments on the interaction of sandstone with Ba-rich fluids at geothermal conditions

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