Influence of carbonate reservoir mineral heterogeneities on contact angle measurements

Ferrari, Jean; Silveira, Bruno Marco de Oliveira; Florez, Jhonatan Jair Arismendi; Fagundes, Thais Bortotti; Silva, Mayara Antunes da Trindade; Skinner, Rodrigo; Ulsen, Carina; Carneiro, Cleyton de Carvalho

doi:10.1016/j.petrol.2020.108313

Cited by 17 publications

(11 citation statements)

References 23 publications

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“…Figure 4 shows the calculated contact angle for mixtures of formation brine and the three seawater schemes (SW0S, SW, and SW0NaCl). In addition, we include experimental contact angle values reported in literature of Brazilian Pre-Salt formation for FW (θ = 93.0 • ) [42], SW (θ = 63.0 • ), and SW0NaCl (θ = 55.0 • ) [43]. The experimental conditions are similar to our simulations.…”

Section: Wettability Alteration Modelingmentioning

confidence: 94%

Modeling Oil Recovery in Brazilian Carbonate Rock by Engineered Water Injection Using Numerical Simulation

et al. 2021

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Waterflooding remains the most commonly used method to improve oil recovery. Although the injected brine type is mainly dependent on its availability, few of its characteristics can be controlled during project design. Published laboratory work indicates that the adjustment of injected brine composition can cause an increase in oil production by wettability alteration. This research objective is to propose a novel four-step framework for modeling improved oil recovery by Engineered Water Injection from laboratory to numerical simulation for carbonate formations. We use a geochemical-based model that estimates contact angles to predict wettability alteration. The steps are (1) screening criteria, (2) geochemical evaluation, (3) wettability alteration modeling, and (4) coreflood history-match. We validate our framework by conducting history-match simulations of Brazilian Pre-Salt corefloods. Incremental oil recovery factors are between 5 to 11%, consistent with those reported during experiments. The reduction in residual oil saturation varied from 3 to 5%. This work is a new systematic procedure to model oil recovery using a comprehensive approach that is fundamental to understanding the underlying wettability alteration mechanisms by Engineered Water Injection.

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Section: Wettability Alteration Modelingmentioning

confidence: 94%

Modeling Oil Recovery in Brazilian Carbonate Rock by Engineered Water Injection Using Numerical Simulation

et al. 2021

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“…In addition, artificial intelligence (AI) has been widely used in the oil industry due to its outstanding performance, including development effect evaluation [77][78][79], data segmentation [80][81][82], and flow simulation [83,84]. In this study, the SOM machine learning method [55,85] was used to automatically classify the residual oil pattern. The SOM method is a kind of artificial neural network with unsupervised learning and consists of treating the samples as vectors in an n-dimensional space, defined by a set of variables.…”

Section: 42mentioning

confidence: 99%

“…These BMUs are projected on maps preserving the topological relationships of similarity between the samples, measured by the Euclidean distance, aggregating the nonlinear relationships of the set of variables. The SOM method has been widely used in image classification [86,87], environmental protection [88,89], energy exploitation [55], etc. The SOM has two layers of network structure: the input layer and the output layer (also called the competition layer).…”

Section: 42mentioning

confidence: 99%

“…Wettability is a tendency of a fluid to spread on or adhere to a solid and mineral surface in the presence of other immiscible fluids, which is perhaps the most critical factor that affects the oil recovery [54,55]. Wettability has a crucial impact on the behavior of multiphase flow during EOR [56].…”

Section: Introductionmentioning

confidence: 99%

“…For example, Arshadi et al [72] indicated that quartz and feldspar grains were mostly weakly water-wet, whereas calcite and dolomite were intermediate and weakly oil-wet. Ferrari et al [55] displayed that quartz minerals could increase the hydrophilic degree of the rock surface. But it is difficult to accurately segment different mineral components by only relying on the grayscale value of CT data since grayscale values of some minerals (e.g., quartz and feldspar) are very close.…”

Section: Introductionmentioning

confidence: 99%

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Effects of Wettability and Minerals on Residual Oil Distributions Based on Digital Rock and Machine Learning

Zhang

Lin

et al. 2022

Lithosphere

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The wettability of mineral surfaces has significant impacts on transport mechanisms of two-phase flow, distribution characteristics of fluids, and the formation mechanisms of residual oil during water flooding. However, few studies have investigated such effects of mineral type and its surface wettability on rock properties in the literature. To unravel the dependence of hydrodynamics on wettability and minerals distribution, we designed a new experimental procedure that combined the multiphase flow experiments with a CT scan and QEMSCAN to obtain 3D digital models with multiple minerals and fluids. With the aid of QEMSCAN, six mineral components and two fluids in sandstones were segmented from the CT data based on the histogram threshold and watershed methods. Then, a mineral surface analysis algorithm was proposed to extract the mineral surface and classify its mineral categories. The in situ contact angle and pore occupancy were calculated to reveal the wettability variation of mineral surface and distribution characteristics of fluids. According to the shape features of the oil phase, the self-organizing map (SOM) method, one of the machine learning methods, was used to classify the residual oil into five types, namely, network, cluster, film, isolated, and droplet oil. The results indicate that each mineral’s contribution to the mineral surface is not proportional to its relative content. Feldspar, quartz, and clay are the main minerals in the studied sandstones and play a controlling role in the wettability variation. Different wettability samples show various characteristics of pore occupancy. The water flooding front of the weakly water-wet to intermediate-wet sample is uniform, and oil is effectively displaced in all pores with a long oil production period. The water-wet sample demonstrates severe fingering, with a high pore occupancy change rate in large pores and a short oil production period. The residual oil patterns gradually evolve from networks to clusters, isolated, and films due to the effects of snap-off and wettability inversion. This paper reveals the effects of wettability of mineral surface on the distribution characteristics and formation mechanisms of residual oil, which offers us an in-deep understanding of the impacts of wettability and minerals on multiphase flow and helps us make good schemes to improve oil recovery.

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Mineralogy, microstructures and geomechanics of rock salt for underground gas storage

Vandeginste

Buysschaert

et al. 2023

Deep Underground Science and Engineering

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Rock salt has excellent properties for its use as underground leak‐proof containers for the storage of renewable energy. Salt solution mining has long been used for salt mining, and can now be employed in the construction of underground salt caverns for the storage of hydrogen gas. This paper presents a wide range of methods to study the mineralogy, geochemistry, microstructure and geomechanical characteristics of rock salt, which are important in the engineering of safe underground storage rock salt caverns. The mineralogical composition of rock salt varies and is linked to its depositional environment and diagenetic alterations. The microstructure in rock salt is related to cataclastic deformation, diffusive mass transfer and intracrystalline plastic deformation, which can then be associated with the macrostructural geomechanical behavior. Compared to other types of rock, rock salt exhibits creep at lower temperatures. This behavior can be divided into three phases based on the changes in strain with time. However, at very low effective confining pressure and high deviatoric stress, rock salt can exhibit dilatant behavior, where brittle deformation could compromise the safety of underground gas storage in rock salt caverns. The proposed review presents the impact of purity, geochemistry and water content of rock salt on its geomechanical behavior, and thus, on the safety of the caverns.

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Influence of carbonate reservoir mineral heterogeneities on contact angle measurements

Cited by 17 publications

References 23 publications

Modeling Oil Recovery in Brazilian Carbonate Rock by Engineered Water Injection Using Numerical Simulation

Modeling Oil Recovery in Brazilian Carbonate Rock by Engineered Water Injection Using Numerical Simulation

Effects of Wettability and Minerals on Residual Oil Distributions Based on Digital Rock and Machine Learning

Mineralogy, microstructures and geomechanics of rock salt for underground gas storage

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