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

Al-Yaseri, Ahmed; Lebedev, Maxim; Vogt, Sarah J.; Johns, Michael L.; Barifcani, Ahmed; Iglauer, Stefan

doi:10.1016/j.petrol.2015.01.018

Cited by 82 publications

(43 citation statements)

References 38 publications

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“…After further SC CO 2 injection a further decrease in ⌬P is apparent, which indicates an increase in permeability, consistent with the above single-phase permeability values. The T2 time range shifted to the left, which indicates creation of smaller pores (Talabi et al, 2009;Al-Yaseri et al, 2015). These results are also consistent with the medical CT images (Fig.…”

Section: Resultssupporting

confidence: 90%

Geo-Mechanical Weakening of Limestone Due to Supercritical CO2 Injection

Zhang

Sarmadivaleh

Lebedev

et al. 2016

Day 3 Thu, March 24, 2016

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CO 2 injection into limestone reservoirs is a typical process in enhanced oil recovery operations, and it is also suggested for carbon geo-storage. However, CO 2 , together with water, is acidic and creates medium strength acid (pH value 3-4) at HP/HT (High Pressure/High Temperature) conditions. At the same time, it is well known that carbonates react and dissolve when exposed to acid. It can, therefore, be expected that the limestone properties change significantly during CO 2 injection.We thus hypothesized that limestone dissolution results in a substantial reduction of mechanical strength of the rock, with potential subsequent (mechanical) collapse of the rock -which would represent a major geohazard and could lead to land subsidence. We therefore conducted HP/HT core flooding tests on Savonnières limestone plugs; the plugs were thoroughly characterised with various experimental techniques (NMR-T2 response, porosity, dynamic permeability, acoustic response, x-ray computed tomography and rock-mechanical tests) before and after acid injection, i.e. exposure to supercritical CO 2 .We indeed measured a significant dissolution of the rock and associated substantial mechanical weakening of the rock. Differently shaped wormholes formed, which strongly influenced the mechanical behaviour. Furthermore, a significant permeability increase was observed (up to 42.3% increase after injection), consistent with wormhole formation. We conclude that CO 2 injection may pose a geohazard if the geo-mechanical strength of the reservoir is compromised.

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Section: Resultssupporting

confidence: 90%

Geo-Mechanical Weakening of Limestone Due to Supercritical CO2 Injection

Zhang

Sarmadivaleh

Lebedev

et al. 2016

Day 3 Thu, March 24, 2016

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“…Quantitatively, the total difference in contact angle after removal of the reversibly bonded nanoparticles was $15°, which is smaller than the drastic reduction caused by the nanofluid itself (À98°). Mechanistically, it is likely that the silica nanoparticles chemisorbed onto the surface (on patches which were not modified by the silane and thus contained surface silanol groups [65]; such silanol groups probably strongly interacted with the silanol groups on the silica particle surface, this has also been observed in recent formation damage studies, Al-Yaseri et al [66]). These adsorption effects were observed with AFM and on SEM images, see above.…”

Section: Adsorption Characteristics: Reversible Versus Irreversible Amentioning

confidence: 77%

Wettability alteration of oil-wet carbonate by silica nanofluid

Al-Anssari

Barifcani

Wang

et al. 2016

Journal of Colloid and Interface Science

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363

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Changing oil-wet surfaces toward higher water wettability is of key importance in subsurface engineering applications. This includes petroleum recovery from fractured limestone reservoirs, which are typically mixed or oil-wet, resulting in poor productivity as conventional waterflooding techniques are inefficient. A wettability change toward more water-wet would significantly improve oil displacement efficiency, and thus productivity. Another area where such a wettability shift would be highly beneficial is carbon geo-sequestration, where compressed CO2 is pumped underground for storage. It has recently been identified that more water-wet formations can store more CO2. We thus examined how silica based nanofluids can induce such a wettability shift on oil-wet and mixed-wet calcite substrates. We found that silica nanoparticles have an ability to alter the wettability of such calcite surfaces. Nanoparticle concentration and brine salinity had a significant effect on the wettability alteration efficiency, and an optimum salinity was identified, analogous to that one found for surfactant formulations. Mechanistically, most nanoparticles irreversibly adhered to the oil-wet calcite surface (as substantiated by SEM-EDS and AFM measurements). We conclude that such nanofluid formulations can be very effective as enhanced hydrocarbon recovery agents and can potentially be used for improving the efficiency of CO2 geo-storage.

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“…The interactions of clays and other minerals with water and HCl could result in dissolution, precipitation, plugging, clay swelling, and fine migration that may cause formation damage (Al-Yaseri et al 2015;Clarke 2014;Hayatdavoudi and Ghalambor 1996;Simon and Anderson 1990;Zhou et al 1995). Interaction of water with different clays could result in clay swelling and fine migration.…”

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confidence: 99%

Clay minerals damage quantification in sandstone rocks using core flooding and NMR

Kamal

Hanfi

Elkatatny

et al. 2018

J Petrol Explor Prod Technol

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Sandstone oil reservoirs consist of different clay minerals such as kaolinite, illite, and chlorite. These clay minerals highly affect the formation damage during enhanced oil recovery (EOR) and well stimulation operations in these reservoirs. No attention was paid to investigate the effect of these clay minerals on the formation damage during different reservoir processes. In addition, no solution was introduced to mitigate the effect of clay minerals on the formation damage in sandstone reservoirs. In this study, the effect of clay mineral contents and type on the formation damage was studied in detail by injecting water and HCl as damaging fluids. Bandera grey, Berea, and Bandera brown sandstone rocks with various clay mineral contents were studied. XRD was used to characterize the sandstone rocks to determine the clay type and content in each rock. Two core plugs from each rock were selected for HCl and water injection. Core flooding experiments were performed to measure the initial and final permeability. In the core flooding experiments, fluids were injected into the cores at 25 °C and at a backpressure of 1000 psi. SEM was carried out before and after flooding for the tested rocks to locate the change in the clay distribution inside the rocks. The NMR analysis of core samples was done before and after flooding with the damaging fluid to quantify the formation damage and to find the possible damaging mechanism. NMR was used to locate the damage inside the rock due to the migration of clay minerals. Based on the core flooding, SEM, and NMR analysis, the maximum damage by the fresh water took place in Berea sandstone core due to fine migration and clay swelling. The illite clay mineral and chlorite can cause the formation damage on HCl injection. Illite can break down and migrates in the cores during the acid injection. In sandstone acidizing, chlorite clay mineral caused iron hydroxide precipitation inside the cores during treatment with mud acid. NMR showed that clay minerals plugged the pore throats of the rocks and reduced the rock permeability during the injection of fresh water.

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

Cited by 82 publications

References 38 publications

Geo-Mechanical Weakening of Limestone Due to Supercritical CO2 Injection

Geo-Mechanical Weakening of Limestone Due to Supercritical CO2 Injection

Wettability alteration of oil-wet carbonate by silica nanofluid

Clay minerals damage quantification in sandstone rocks using core flooding and NMR

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