Applications of digital core analysis and hydraulic flow units in petrophysical characterization

Chen, Xiaojun; Zhou, Yingfang

doi:10.26804/ager.2017.01.02

Cited by 26 publications

(6 citation statements)

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“…For horizontally and vertically retrieved core-plugs at a given value of porosity, permeability varies over several orders of magnitude proving the highly heterogeneous characteristics of the reservoir understudy ( Figure 5). distribution of values around the mean is calculated (Chen and Zhou, 2017). In such cases, when more than one PSRT/PDRT exists, the overall distribution of that index is a superposition of the individual distributions around their mean value.…”

Section: Case Studymentioning

confidence: 99%

A new approach in petrophysical rock typing

Mirzaei‐Paiaman

Ostadhassan

Rezaee

et al. 2018

Journal of Petroleum Science and Engineering

108

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Petrophysical rock typing in reservoir characterization is an important input for successful drilling, production, injection, reservoir studies and simulation. In this study petrophysical rock typing is divided into two major categories: 1) a petrophysical static rock type (PSRT): a collection of rocks having the same primary drainage capillary pressure curves or unique water saturation for a given height above the free water level, 2) a petrophysical dynamic rock type (PDRT): a set of rocks with a similar fluid flow behavior. It was shown that static and dynamic rock types do not necessarily overlap or share petrophysical properties, regardless of wettability. In addition, a new index is developed to define PDRTs via the Kozeny-Carman equation and Darcy's law. We also proposed a different index for delineation of PSRTs by combining the Young-Laplace capillary pressure expression and the Kozeny-Carman equation. These new indices were compared with the existing theoretical and empirical indices. Results showed that our indices are representatives of previously developed models which were also tested with mercury injection capillary pressure, water-oil primary drainage capillary pressure, and water-oil relative permeability data on core plugs from a highly heterogeneous carbonate reservoir in an Iranian oil field. This study enabled us to modify the conventional J-function to enhance its capability of normalizing capillary pressure data universally.

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Section: Case Studymentioning

confidence: 99%

A new approach in petrophysical rock typing

Mirzaei‐Paiaman

Ostadhassan

Rezaee

et al. 2018

Journal of Petroleum Science and Engineering

108

View full text Add to dashboard Cite

show abstract

“…The advantage of this method is that it can visually observe the spatial geometry distribution of the pore in the core, and can reflect the formation information (Zhang et al, 2017). The emerging digital core technology is a method of establishing the network model, which is based on the microscopic test method to obtain the pore space distribution and the particle structure inside the core by computer simulation (Yang et al, 2015(Yang et al, , 2016An et al, 2016;Chen et al, 2017b). Through the establishment of fractal model or network model and the combination of conventional experimental analysis and advanced constant speed and nuclear magnetic experiment, it is of great significance to deeply analyze the microscopic porethroat structure of low permeability and ultra-low permeable reservoir.…”

Section: Recent Developments and Extensionsmentioning

confidence: 99%

Recent advances on microscopic pore characteristics of low permeability sandstone reservoirs

Huang

Meng

et al. 2018

Adv. Geo-Energy Res.

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Understanding oil and gas production from low-permeability sandstones requires an understanding of the porosity. This paper reviews the analysis of data from hundreds of cores' microscopic pore characteristics of low-permeability sandstone reservoirs from Chang 6 reservoir of Ji-yuan oilfield in ordos basin. And this paper is to embody the methods used in the study of low permeable sandstone reservoir in recent years and the results reflected in it. For example, by analyzing the rock of Chang 6 reservoirs, it can be seen that the rock of Chang 6 reservoirs is mostly developed by Feldspar Sandstone, its internal pore types are diverse, the pore size is mainly small pore type, the second is fine pore, and has continuous spectral distribution, and the distribution is single peak shape. Different methods have been used to study low-permeability sandstones, including scanning electron microscope, casting thin plate, physical test means, highpressure mercury, constant velocity mercury, NMR experiments. The results show that the pore-throat combination types of reservoir are mainly small pore-micro-larynx. The main type of reservoir throat is mainly flaky throat. The extremely strong heterogeneity in the layer is the key to the efficiency and effect of water flooding. Therefore, the exploration and development of low permeable sandstone reservoirs can be guided by the analysis of relevant parameters.

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“…ese two key features indicate that we can use the core-shell microsphere for nearwellbore zone blockage, whereas the polymeric microsphere for deep formation blockage. Based on the X-ray computed tomography (CT), 3D digital core structure models [41] can be developed to evaluate the applicability of di erent types of microspheres.…”

Section: Core-shellmentioning

confidence: 99%

Experimental Study on Expansion Characteristics of Core-Shell and Polymeric Microspheres

Diwu

Jiang

Hou

et al. 2018

Journal of Nanotechnology

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Traditional polymeric microsphere has several technical advantages in enhancing oil recovery. Nevertheless, its performance in some field application is unsatisfactory due to limited blockage strength. Since the last decade, novel core-shell microsphere has been developed as the next-generation profile control agent. To understand the expansion characteristic differences between these two types of microspheres, we conduct size measurement experiments on the polymeric and core-shell microspheres, respectively. The experimental results show two main differences between them. First, the core-shell microsphere exhibits a unimodal distribution, compared to multimodal distribution of the polymeric microsphere. Second, the average diameter of the core-shell microsphere increases faster than that of the polymeric microsphere in the early stage of swelling, that is, 0–3 days. These two main differences both result from the electrostatic attraction between core-shell microspheres with different hydration degrees. Based on the experimental results, the core-shell microsphere is suitable for injection in the early stage to block the near-wellbore zone, and the polymeric microsphere is suitable for subsequent injection to block the formation away from the well. A simple mathematical model is proposed for size evolution of the polymeric and core-shell microspheres.

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Applications of digital core analysis and hydraulic flow units in petrophysical characterization

Cited by 26 publications

References 100 publications

A new approach in petrophysical rock typing

A new approach in petrophysical rock typing

Recent advances on microscopic pore characteristics of low permeability sandstone reservoirs

Experimental Study on Expansion Characteristics of Core-Shell and Polymeric Microspheres

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