How does the pore-throat size control the reservoir quality and oiliness of tight sandstones? The case of the Lower Cretaceous Quantou Formation in the southern Songliao Basin, China

Xi, Kelai; Cao, Yingchang; Haile, Beyene Girma; Zhu, Rixiang; Jahren, Jens; Bjørlykke, Knut; Zhang, Xiangxiang; Hellevang, Helge

doi:10.1016/j.marpetgeo.2016.05.001

Cited by 210 publications

(113 citation statements)

References 36 publications

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“…Dong et al demonstrated that the slippage effect is more remarkable in smaller throats by comparing volcanic core samples with similar permeabilities, but different throat size distributions [19]. The depositional environments result in complicated throat size distributions in a tight formation, which implies that the contribution of the slippage effect to the absolute permeability would significantly change in distinct pore-throat systems [20,21]. Nevertheless, no attempts have been made to determine the absolute/Klinkenberg permeability of a tight formation conditioned to its pore-throat systems.…”

Section: Introductionmentioning

confidence: 99%

Determination of Klinkenberg Permeability Conditioned to Pore-Throat Structures in Tight Formations

et al. 2017

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This paper has developed a pragmatic technique to efficiently and accurately determine the Klinkenberg permeability for tight formations with different pore-throat structures. Firstly, the authors use steady-state experiments to measure the Klinkenberg permeability of 56 tight core samples under different mean pore pressures and confining pressures. Secondly, pressure-controlled mercury injection (PMI) experiments and thin-section analyses are conducted to differentiate pore-throat structures. After considering capillary pressure curve, pore types, throat size, particle composition, and grain size, the pore-throat structure in the target tight formation was classified into three types: a good sorting and micro-fine throat (GSMFT) type, a moderate sorting and micro-fine throat (MSMFT) type, and a bad sorting and micro throat (BSMT) type. This study found that a linear relationship exists between the Klinkenberg permeability and measured gas permeability for all three types of pore-throat structures. Subsequently, three empirical equations are proposed, based on 50 core samples of data, to estimate the Klinkenberg permeability by using the measured gas permeability and mean pore pressure for each type of pore-throat structure. In addition, the proposed empirical equations can generate accurate estimates of the Klinkenberg permeability with a relative error of less than 5% in comparison to its measured value. The application of the proposed empirical equations to the remaining six core samples has demonstrated that it is necessary to use an appropriate equation to determine the Klinkenberg permeability of a specific type of pore-throat structure. Consequently, the newly developed technique is proven to be qualified for accurately determining the Klinkenberg permeability of tight formations in a timely manner.

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Section: Introductionmentioning

confidence: 99%

Determination of Klinkenberg Permeability Conditioned to Pore-Throat Structures in Tight Formations

et al. 2017

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“…Its relationship with the permeability indicates that permeability of these tight reservoirs is determined by the throat size distribution significantly (Figure 8(a)). Empirically, permeability is mainly contributed by the part of larger throats and the increase of smaller throats in proportion decreases the permeability [28]. Comparing the throat radius distribution and the corresponding contribution to the permeability between the samples having different permeability value indicates that high permeability sample has more large throats, and the permeability result from the relative larger throat dominated the total permeability (Figure 8(b)).…”

Section: The Influence Of Pore-throat Geometry On Porosity Andmentioning

confidence: 94%

“…To investigate the fluid performance in tight clastic rock reservoir, some experiments and studies returned back to the essential issues, including the pore-throat structure and physical interaction of fluid-pore-wall in the tight reservoir [6,10,13,[15][16][17][18][19][20][21][22][23][24]. However, the pore-throat structures are various significantly in tight clastic rock reservoir and the fluid flow inside needs to be particularly concerned [25][26][27][28][29].…”

Section: Introductionmentioning

confidence: 99%

“…This technique was used by lots of scholars to research the pore-throat structures and try to relate these characteristics to simple and easy obtained parameters, such as permeability and porosity, and further to estimate the reservoir quality for economic fluid pay [32][33][34][35]. With the increase of unconventional hydrocarbon resource exploitation in recent years, some applications have to be conducted in the tight fine-grained sandstone, siltstone, carbonate rocks, and shale [3,15,28,[36][37][38]. By controlling the mercury injection rate to be constant approximately and in a very low magnitude, the capillary-pressure curves can be obtained by partitioning the total capillary-pressure curve (normal capillary-pressure curve) into two subcurves, the subison capillary-pressure curve, which details the distribution of pore bodies, and the rison capillary-pressure curve, which details the distribution of throats bodies [39].…”

Section: Introductionmentioning

confidence: 99%

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The Controls of Pore-Throat Structure on Fluid Performance in Tight Clastic Rock Reservoir: A Case from the Upper Triassic of Chang 7 Member, Ordos Basin, China

et al. 2018

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The characteristics of porosity and permeability in tight clastic rock reservoir have significant difference from those in conventional reservoir. The increased exploitation of tight gas and oil requests further understanding of fluid performance in the nanoscale pore-throat network of the tight reservoir. Typical tight sandstone and siltstone samples from Ordos Basin were investigated, and rate-controlled mercury injection capillary pressure (RMICP) and nuclear magnetic resonance (NMR) were employed in this paper, combined with helium porosity and air permeability data, to analyze the impact of pore-throat structure on the storage and seepage capacity of these tight oil reservoirs, revealing the control factors of economic petroleum production. The researches indicate that, in the tight clastic rock reservoir, largest throat is the key control on the permeability and potentially dominates the movable water saturation in the reservoir. The storage capacity of the reservoir consists of effective throat and pore space. Although it has a relatively steady and significant proportion that resulted from the throats, its variation is still dominated by the effective pores. A combination parameter ( ) that was established to be as an integrated characteristic of pore-throat structure shows effectively prediction of physical capability for hydrocarbon resource of the tight clastic rock reservoir.

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“…Although air/mercury injection technique is commonly applied [17,19,20], this method has several weak points. As mercury is injected under high pressure, sensitive pores can be damaged.…”

Section: Introductionmentioning

confidence: 99%

Predicting relative permeability from experimental capillary pressure porous plate test for two phase flow

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How does the pore-throat size control the reservoir quality and oiliness of tight sandstones? The case of the Lower Cretaceous Quantou Formation in the southern Songliao Basin, China

Cited by 210 publications

References 36 publications

Determination of Klinkenberg Permeability Conditioned to Pore-Throat Structures in Tight Formations

Determination of Klinkenberg Permeability Conditioned to Pore-Throat Structures in Tight Formations

The Controls of Pore-Throat Structure on Fluid Performance in Tight Clastic Rock Reservoir: A Case from the Upper Triassic of Chang 7 Member, Ordos Basin, China

Predicting relative permeability from experimental capillary pressure porous plate test for two phase flow

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