Investigation of pore-type heterogeneity and its control on microscopic remaining oil distribution in deeply buried marine clastic reservoirs

Sun, Panke; Xu, Huaimin; Zhu, Hanqing; Jia, Langbo; Hu, Xiaoni; Fang, Huijing; Jiang, Hanqiao; Zhang, Xu; Jiang, Tongwen; Xu, Jiang; Tian, Liyan

doi:10.1016/j.marpetgeo.2020.104750

Cited by 23 publications

(6 citation statements)

References 31 publications

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“…Thus, the study of the distribution of micro-remaining oil in the ultra-high water cut stage is required (Li et al, 2018). In this stage, many continuous oil phases fracture to form discontinuous oil phases distributed as tiny droplets in the pores and throat (Grattoni and Dawe, 2003;Meybodi et al, 2011;Li et al, 2017;Ding et al, 2018;Sun et al, 2021). The study of the flow law and distribution of these tiny oil droplets has important guiding significance for improving the overall reservoir recovery.…”

Section: Introductionmentioning

confidence: 99%

Experimental study of distribution and quantitative characterization of discontinuous oil phase based on micro-CT

et al. 2023

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When a sandstone reservoir enters the ultra-high water cut stage, the oil phase changes from continuous to discontinuous, which results in difficulties in the further development and utilization of the reservoir. It is important to clarify the flow law and distribution state of discontinuous oil phases to guide the remaining oil production. This study selected samples from sandstone reservoirs, accurately obtained oil and water phase information from digital core, and constructed matrix based on three-dimensional CT scanning to study the law of discontinuous oil phase distribution. We used digital cores to construct pore network models and calculate the pore radius, throat radius, pore-throat ratio, coordination number, and tortuosity to study the influence of pore structure on discontinuous oil phase flow law. A micro-displacement experiment consisting of two phases of simulated reservoir and development was designed. To improve the accuracy of the experiment, the related pressure was controlled to form bound water in the simulated reservoir formation stage. In the simulated reservoir development phase, in situ scanning of cores at different displacement stages was performed to obtain oil and water distributions at different stages in the same location. The number of oil droplets, 3D shape factor, Euler number, and saturation coefficient of the oil phase were calculated, and the micro-remaining oil clumps were quantitatively analyzed. According to the morphology and distribution characteristics, the remaining oil of the discontinuous phase was divided into the types of the throat, film, droplet, island, and corner. The results showed that the sample with a small pore-throat ratio, large coordination number, and small tortuosity was more likely to form dominant channels; moreover, the remaining oil was more concentrated in this state. In the remaining oil of the discontinuous phase, the number of droplets was the largest and had an obvious displacement effect. The island number was small because the selected samples had good connectivity and it is difficult to form large oil droplets in a single pore. In the ultra-high water cut stage, the throat number increased slowly, which was related to the formation of dominant channels. The corner and the film were difficult to displace; thus, their numbers increased steadily. The quantitative characterization of the discontinuous oil phase is helpful for further study of remaining oil at the pore scale.

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Section: Introductionmentioning

confidence: 99%

Experimental study of distribution and quantitative characterization of discontinuous oil phase based on micro-CT

et al. 2023

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“…In the process of investigating the effects of micro-heterogeneity on water injection development in oil and gas fields, scholars have drawn conclusions from experiments such as physical property analysis, casting thin-section observation, scanning electron microscopy and X-ray diffraction testing, CT scanning, and nuclear magnetic resonance. The results have indicated that porosity heterogeneity is a critical factor leading to a nonuniform water drive, and the stronger the porosity heterogeneity, the higher the likelihood of producing annular residual oil [18][19][20]. Pore heterogeneity and surface roughness primarily affect the permeability and storage space of reservoirs [21].…”

Section: Introductionmentioning

confidence: 99%

The Influence of Micro-Heterogeneity on Water Injection Development in Low-Permeability Sandstone Oil Reservoirs

Li,

Qu,

Wang

et al. 2023

Minerals

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Micro-heterogeneity in low-permeability sandstone oil reservoirs significantly influences the uniformity of water injection during development. This leads to the formation of preferred channels for water injection, causing premature water breakthroughs in oil wells. Not only does this reduce oil displacement efficiency, but it also enriches residual oil in the formation, which ultimately impacts the overall recovery rate. This study employed various methods, including thin-section casting, qualitative analysis through scanning electron microscopy, quantitative analysis of X-ray diffraction, high-pressure mercury intrusion and particle size, and experimental techniques, such as wettability and micro-displacement, to investigate the impact mechanism of micro-heterogeneity on water injection development in low-permeability oil reservoirs. A typical low-permeability sandstone oil reservoir in the Ordos Basin was used as a case study. The results reveal that the reservoir’s micro-heterogeneity is determined by the heterogeneity of the interstitial material, porosity, and particle size. Micro-heterogeneity plays a critical role in the flow characteristics and oil displacement efficiency of low-permeability oil reservoirs. The less the micro-heterogeneity, the better the water injection development outcome. This study suggests a technical policy adjustment method that is critical for guiding the development of low-permeability water injection oil reservoirs, thereby improving the effectiveness of water injection development.

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“…The fabric of connected pores, that is, their shape, orientation, and connectivity, largely controls rock properties such as permeability. An accurate 3D description of pore fabrics has therefore many applications, including geothermal energy usage (Aliyu & Chen, 2018; Frosch et al., 2000; Wagner et al., 2005; Zhang, Liu, et al., 2020), hydrocarbon exploitation, especially in tight rock (Chen et al., 2020; Gao & Hu, 2018; Kibria et al., 2018; Lai et al., 2018; Sun et al., 2021; Yang et al., 2017, 2018; Zhang, Liu, et al., 2020), and numerical simulations of fluid flow in reservoirs (Mehmani et al., 2020; Wang et al., 2009; Yang et al., 2019; Zhang et al., 2015). Pore fabrics can be characterized directly or indirectly, as defined below.…”

Section: Introductionmentioning

confidence: 99%

Quantitative Comparison of 3D Pore Space Properties With Magnetic Pore Fabrics—Testing the Ability of Magnetic Methods to Predict Pore Fabrics in Rocks

Zhou

Pugnetti

Foubert

et al. 2022

Geochem Geophys Geosyst

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Investigation of pore-type heterogeneity and its control on microscopic remaining oil distribution in deeply buried marine clastic reservoirs

Cited by 23 publications

References 31 publications

Experimental study of distribution and quantitative characterization of discontinuous oil phase based on micro-CT

Experimental study of distribution and quantitative characterization of discontinuous oil phase based on micro-CT

The Influence of Micro-Heterogeneity on Water Injection Development in Low-Permeability Sandstone Oil Reservoirs

Quantitative Comparison of 3D Pore Space Properties With Magnetic Pore Fabrics—Testing the Ability of Magnetic Methods to Predict Pore Fabrics in Rocks

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