Waterflooding Experiments with X-ray CT Imaging

London, Mike; Cameron, S.; Donald, James; Wassmuth, F.R.

doi:10.2118/170147-ms

Cited by 4 publications

(5 citation statements)

References 5 publications

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“…For this reason, several authors have presented results including Computed Tomography (CT). They are Batenburg et al (2015) [8], London et al (2014) [9], Hove et al (1990) [10], Hunt et al (1988) [11], Wang et al (1984) [12], Wellington and Vinegar (1987) [13], Vinegar and Wellington (1987) [14], Withjack (1988) [15], Withjack et al (2003) [16], Wan et al (2019) [17], Ouali et al (2019) [18]. It is important to highlight that core-flooding tests allow calibrating field simulation models reducing uncertainties on rockfluids interactions.…”

Section: Introductionmentioning

confidence: 99%

The effectiveness of computed tomography for the experimental assessment of surfactant-polymer flooding

Hernández

Moreno

2020

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

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The Surfactant-Polymer (SP) process is a type of Chemical Enhanced Oil Recovery (CEOR) method. They are still a challenge for the petroleum oil industry mainly because of the difficulty in designing and forecasting the process behavior on the field scale. Therefore, understanding of the phenomena associated with a CEOR process is of vital importance. For these reasons, this work discusses the benefits of Computed Tomography (CT) uses for the experimental assessment of a SP process. The research includes a literature review that allows identifying the main CT usages for petroleum engineering and a discussion concerning the effectiveness of mathematic expressions proposed for the tomography images treatment of two-phase flow displacement. The conducted experimental methodology can be reproduced to assess the benefits of any chemical Enhanced Oil Recovery (EOR) process with CT. Thus, this paper assesses the conventional waterflooding (WF) and SP flooding as secondary and tertiary oil recovery methods. The developed study allowed us to evaluate through CT images the porosity and the saturation profiles along the rock sample. Also, CT processed data enabled checking the volumetric material balance and determine the oil Recovery Factor (RF). The doubled checked SP data showed an RF increase of 17 and 10 percentage points for secondary and tertiary chemical injection schemes respect to conventional waterflooding. Finally, comparative results of the water cut (Wcut) evidenced the mobility ratio improvement and reduction on the remaining oil saturation.

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Section: Introductionmentioning

confidence: 99%

The effectiveness of computed tomography for the experimental assessment of surfactant-polymer flooding

Hernández

Moreno

2020

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

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“…Pore-throat tortuosity is the ratio of the actual length of the seepage channels and the apparent length the fluids flow through the seepage medium (the macro distance). Fluid particles flow through the medium in unit distance-the actual length of motion trajectory of the particle; this is an important parameter for the evaluation of the complexity of the seepage channel, but also one of the most important parameters in the prediction of reservoir permeability (Lonnes et al, 2003;London et al, 2014;Arash et al, 2014;Huang and Zhao, 2017;Nishank et al (2017a, b)).…”

Section: Introductionmentioning

confidence: 99%

Prediction of permeability and its anisotropy of tight oil reservoir via precise pore-throat tortuosity characterization and “umbrella deconstruction” method

2019

Journal of Petroleum Science and Engineering

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A B S T R A C TThis study aimed to investigate the prediction method of permeability and its anisotropy of tight oil reservoir via precise pore-throat tortuosity characterization and "umbrella deconstruction" method combining the approaches of the field emission SEM imaging, high resolution image processing, fine and large-scale mathematical statistics, nonlinear regression and other technical means.In this paper, the authors proposed the new calculation model of pore-throat tortuosity, the absolute permeability and the permeability anisotropy based on the improved deep understanding of reservoir. Results of the prediction on the tight oil reservoir of "YANCHANG" formation in Ordos Basin show that the errors of the new method in this paper are the smallest among the total five methods, respectively 0.023 × 10 −3 μm 2 and 0.090 × 10 −3 μm 2 ; the average values of other four methods were 0.090 × 10 −3 μm 2 and 0.108 × 10 −3 μm 2 , respectively. The predicted results have higher accordance with the measured results, which proved the practicality of the new method. The samples has the highest permeability at the angle of 0°(180°/360°) and the permeability values are equal to 0.25 × 10 −3 μm 2 . Similarly, the sample has the lowest permeability at the angle of 22.5°(202.5°), 90°(270°), and 112.5°(292.5°), the permeability values are all equal to 0.06 × 10 −3 μm 2 . At the same time, the calculation of permeability anisotropy results shows that the anisotropy of tight oil reservoirs is very significant, and the permeability value in one direction is obviously higher than which in other directions.It is concluded that the precise description of pore throat geometry, especially the calculation of pore-throat tortuosity parameter, is one of the most important parameters affecting the prediction accuracy of permeability theoretically. Meanwhile, there are dominant seepage channels, which would play a very important guiding role in the prediction of hydrocarbon accumulation and seepage capacity.The conclusion will provide a more rigorous theoretical basis for the rapid and accurate evaluation of the physical properties of unconventional reservoirs. distortion of surface roughness into pore throat resulted in the underestimation of permeability. Arash et al. (2016) estimated three-dimensional coordination numbers from two-dimensional cross-sectional images and explored the error of absolute permeability prediction using pore network flow model. An et al. (2016) studied the effects of pore throat ratio, coordination number and pore throat orientation on absolute permeability using a regular network model. Shah et al. (2016) predicted the properties of pore network, such as the number of pore and throat, average pore throat radius and coordination number, and used Lattice Boltzmann (LBM) or pore network (PNM) modeling to simulate single-phase and dual-phase flow. Three-dimensional core image can be obtained after CT scanning, and digital core can be built after filtering and segmentation. Yang et al. (2016) gets the rock

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“…The characterisation of mineralogical heterogeneity, especially of some brittle minerals, is significant in enhancing the recovery efficiency of unconventional hydrocarbon, because minerals influence the distribution characteristics of hydraulic fracturing. In addition, according to the principle of sedimentology, the formation of pore throats is essentially due to the accumulation, compaction and subsequent diagenesis of minerals, and this is achieved by the primary and secondary boundaries of minerals, where the boundaries of pore throats are the grain boundaries after denudation, transportation and reconstruction [12][13][14]. Pore-throat characteristics largely reflect the sorting and grinding properties of minerals, which is a true reflection of the deposition, compaction and modification processes.…”

Section: Introductionmentioning

confidence: 99%

A new and more precise experiment method for characterizing the mineralogical heterogeneity of unconventional hydrocarbon reservoirs

Pang

Shi

2018

Fuel

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This study is aimed to introduce the new and more precise experiment method which could characterize the mineralogical heterogeneity of unconventional hydrocarbon reservoirs. As the 2D characterization methods and techniques still have a large amount of information to be excavated with quite strong vitality, the new method could be used to discover the minerals directly under the FE-SEM combining with the EDS method after considering both the resolution (10 nm) and representativeness (20 mm). The higher the ratio of the maximum to the minimum and the mean square deviation of each mineral parameter in thin sections from 8 different directions, the higher the microscopic heterogeneity of the reservoir. The new method would help to the study on enhancing the remaining unconventional hydrocarbon recovery.

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Waterflooding Experiments with X-ray CT Imaging

Cited by 4 publications

References 5 publications

The effectiveness of computed tomography for the experimental assessment of surfactant-polymer flooding

The effectiveness of computed tomography for the experimental assessment of surfactant-polymer flooding

Prediction of permeability and its anisotropy of tight oil reservoir via precise pore-throat tortuosity characterization and “umbrella deconstruction” method

A new and more precise experiment method for characterizing the mineralogical heterogeneity of unconventional hydrocarbon reservoirs

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