Laboratory validation of steady-state-transient test to determine relative permeability and capillary pressure

Hemmati, Nassim; Borazjani, Sara; Yang, Shuyan; Badalyan, Alexander; Genolet, L.; Behr, Aron; Zeinijahromi, Abbas; Bedrikovetsky, Pavel

doi:10.1016/j.fuel.2022.123940

Cited by 9 publications

(4 citation statements)

References 56 publications

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“…Hence, creating a situation with a low mobility ratio and low capillary number values facilitates oil production during chemical flooding. Therefore, the application of AVBP–ethanol–NC as the flooding agent assists the incremental oil recovery in this study. ,, …”

Section: Results and Discussionmentioning

confidence: 99%

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Application of a Novel Green Nano Polymer for Chemical EOR Purposes in Sandstone Reservoirs: Synergetic Effects of Different Fluid/Fluid and Rock/Fluid Interacting Mechanisms

Khaksar Manshad,

Kabipour,

Mohammadian

et al. 2023

ACS Omega

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In this research, a novel natural-based polymer, the Aloe Vera biopolymer, is used to improve the mobility of the injected water. Unlike most synthetic chemical polymers used for chemical-enhanced oil recovery, the Aloe Vera biopolymer is environmentally friendly, thermally stable in reservoir conditions, and compatible with reservoir rock and fluids. In addition, the efficiency of the Aloe Vera biopolymer was investigated in the presence of a new synthetic nanocomposite composed of KCl−SiO 2 −xanthan. This chemically enhanced oil recovery method was applied on a sandstone reservoir in Southwest Iran with crude oil with an API gravity of 22°. The Aloe Vera biopolymer's physicochemical characteristics were initially examined using different analytical instruments. The results showed that the Aloe Vera biopolymer is thermally stable under reservoir conditions. In addition, no precipitation occurred with the formation brine at the salinity of 80,000 ppm. The experimental results showed that adding ethanol with a 10% volume percentage reduced interfacial tension to 15.3 mN/m and contact angle to 108°, which was 52.33 and 55.56% of these values, respectively. On the other hand, adding nanocomposite lowered interfacial tension and contact angle values to 4 mN/m and 48°, corresponding to reducing these values by 87.53 and 71.42%, respectively. The rheology results showed that the solutions prepared by Aloe Vera biopolymer, ethanol, and nanocomposite were Newtonian and fitted to the Herschel−Bulkley model. Finally, core flooding results showed that the application of a solution prepared by Aloe Vera biopolymer, ethanol, and nanocomposite was effective in increasing the oil recovery factor, where the maximum oil recovery factor of 73.35% was achieved, which could be attributed to the IFT reduction, wettability alteration, and mobility improvement mechanisms.

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Section: Results and Discussionmentioning

confidence: 99%

“…In addition to the RF, other required parameters, such as postflooding water saturation (Swc) and relative permeability (Kr) of phases, can be obtained from the flooding test, as well. Figure illustrates a schematic of a flooding apparatus and its various components used in this study. − …”

Section: Methodsmentioning

confidence: 99%

Application of a Novel Green Nano Polymer for Chemical EOR Purposes in Sandstone Reservoirs: Synergetic Effects of Different Fluid/Fluid and Rock/Fluid Interacting Mechanisms

Khaksar Manshad,

Kabipour,

Mohammadian

et al. 2023

ACS Omega

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“…The methods for obtaining relative permeability are mainly classified into experimental measurement methods and model prediction methods. − At present, the experimental measurement is the main method to obtain the relative permeability curve in the oilfield, and it has achieved good application results in conventional oil and gas reservoirs. − Due to the complex pore structure and strong heterogeneity of tight sandstone reservoirs, measuring relative permeability by experimental methods is challenging; , many scholars have established mathematical models to predict relative permeability. − Based on the relationship between relative permeability and measured capillary pressure–saturation curves, relative permeability can be predicted through the capillary pressure curves. According to Purcell’s (1949) permeability prediction method, Burdine (1953), Corey (1954), and Brooks and Corey (1966) proposed a relative permeability model based on capillary pressure.…”

Section: Introductionmentioning

confidence: 99%

Nuclear Magnetic Resonance T₂ Distribution-Based Gas–Water Relative Permeability Prediction in Tight Sandstone Reservoirs: A Case Study on Central Sichuan Basin, China

Wei,

Xie,

Wang

et al. 2024

Energy Fuels

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The relative permeability (K r ) measurement of tight sandstones is challenging due to its low porosity, low permeability, and complex pore structure. Nuclear magnetic resonance (NMR) technology has the advantages of being fast, nondestructive, and noninvasive while also continuously evaluating tight reservoirs. Based on NMR technology, it is of great significance to establish an effective and reliable relative permeability prediction model to solve practical problems in oil fields. In this paper, a method for predicting gas−water relative permeability in tight sandstone reservoirs is proposed based on NMR transverse relaxation time (T 2 ) distribution. The gas−water relative permeability measurements are performed for tight sandstone reservoirs in the Central Sichuan Basin, China. On the basis of the analysis of the gas−water permeability features in the study area, the reservoir characteristics are clarified. Based on the NMR theories, two T 2 −K r prediction models (model 1 and optimal model 2) are derived and established, and the model performance is analyzed using experimental data and existing models (Purcell and Brooks-Corey). Finally, the optimal model is used to process NMR logging data, obtain continuous relative permeability curves, and perform a productivity prediction. The effectiveness and applicability of the method are verified using relative permeability experiments and the oil testing data. The proposed method can provide effective guidance for the prediction of relative permeability curves and productivity evaluation of tight sandstone reservoirs.

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“…supercritical CO2 and were able to simultaneously determine relative permeability and capillary pressure (Pini & Benson 2013). Borazjani et al 2021 andHemmati et al 2022 used a steady-state approach and in addition also the transient unsteady-state periods when changing fractional flow to determine both relative permeability and capillary pressure. Even though it has been recently demonstrated that it is indeed possible to perform steady-state relative experiments also with H2 (Lysyy et al 2022a), one attractive option is to consider instead the unsteady-state method which is better suited for handling the fluids of interest such as CO2 or H2 and operates generally at much less injection volumes than the steady-state method which is more favorable from a laboratory perspective in particular for H2 from a safety perspective (Rezaei et al 2022).…”

Section: Introductionmentioning

confidence: 99%

Simultaneous Determination of Relative Permeability and Capillary Pressure from an Unsteady-State Core Flooding Experiment?

Berg

Dijk

Ünsal³

et al. 2023

Preprint

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For modelling studies of underground storage of carbon dioxide and hydrogen, it is important to have a consistent set of relative permeability and capillary pressure-saturation functions. For consistency reasons, it is an advantage to determine both in one single experiment using the same rock and fluid sample, however, experimental measurements typically have challenges. While unsteady-state type of flow experiments is in principle suited for deriving relative permeability and capillary pressure functions, we provide a methodology to optimize the experimental settings such that the simultaneous determination of these functions can succeed within an acceptable uncertainty range, which involve multi-rate flow experiments and in-situ saturation monitoring. We provide details of the inverse modelling methodology which is a self-contained Python code that includes both the 1D flow model and the optimization method for the assisted history match. This methodology can be used for interpreting experiments, but also to optimize the design of the experiment and to reach a desired/acceptable uncertainty range.The purpose of this work is to provide the concrete assessment of unsteady-state type of experiments with the purpose of simultaneously obtaining relative permeability and capillary pressure-saturation functions by means of a ground-truth example, to detail the methodology used and make the Python code with a self-contained 1D flow solver accelerated by the numba just-in-time compiler publicly available. The results underline that the simultaneous determination of relative permeability and capillary pressure-saturation functions are possible only in specially designed multi-rate experiments where several saturation profiles before breakthrough are captured and the capillary end-effect is fully resolved. These conditions are not necessarily met for the more general type of unsteady-state experiments typically used in the more general Special Core Analysis (SCAL).

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Laboratory validation of steady-state-transient test to determine relative permeability and capillary pressure

Cited by 9 publications

References 56 publications

Application of a Novel Green Nano Polymer for Chemical EOR Purposes in Sandstone Reservoirs: Synergetic Effects of Different Fluid/Fluid and Rock/Fluid Interacting Mechanisms

Application of a Novel Green Nano Polymer for Chemical EOR Purposes in Sandstone Reservoirs: Synergetic Effects of Different Fluid/Fluid and Rock/Fluid Interacting Mechanisms

Nuclear Magnetic Resonance T₂ Distribution-Based Gas–Water Relative Permeability Prediction in Tight Sandstone Reservoirs: A Case Study on Central Sichuan Basin, China

Simultaneous Determination of Relative Permeability and Capillary Pressure from an Unsteady-State Core Flooding Experiment?

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Laboratory validation of steady-state-transient test to determine relative permeability and capillary pressure

Cited by 9 publications

References 56 publications

Application of a Novel Green Nano Polymer for Chemical EOR Purposes in Sandstone Reservoirs: Synergetic Effects of Different Fluid/Fluid and Rock/Fluid Interacting Mechanisms

Application of a Novel Green Nano Polymer for Chemical EOR Purposes in Sandstone Reservoirs: Synergetic Effects of Different Fluid/Fluid and Rock/Fluid Interacting Mechanisms

Nuclear Magnetic Resonance T2 Distribution-Based Gas–Water Relative Permeability Prediction in Tight Sandstone Reservoirs: A Case Study on Central Sichuan Basin, China

Simultaneous Determination of Relative Permeability and Capillary Pressure from an Unsteady-State Core Flooding Experiment?

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Nuclear Magnetic Resonance T₂ Distribution-Based Gas–Water Relative Permeability Prediction in Tight Sandstone Reservoirs: A Case Study on Central Sichuan Basin, China