Correlation between sandstone permeability and capillary pressure curves

Guo, Boyun; Ghalambor, Ali; Duan, Shengkai

doi:10.1016/j.petrol.2004.02.016

Cited by 39 publications

(19 citation statements)

References 7 publications

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“…The previous researches have been dedicated to the correlation of MICP parameters, mainly mercury saturation and capillary pressure, and reservoir permeability [66][67][68][69]. Swanson parameter and capillary parachor, two parameters derived from MICP, have a positive correlation to permeability value in both coarse and tight sandstone [67,69].…”

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

confidence: 99%

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

confidence: 99%

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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“…Permeability values were derived from MICP curves prior to generating the combined capillary curves, since numerous authors defined empirical equations between Thomeer-parameters and permeability [33,38,[51][52][53][54][55][56][57][58][59][60][61]. Permeability was estimated for all of the 26 samples using Thomeer-, and Swanson-methods.…”

Section: Integration and Interpretation Of Data (Figure 5-part 6b)mentioning

confidence: 99%

Revisiting the applications of drainage capillary pressure curves in water-wet hydrocarbon systems

Nemes

2016

Open Geosciences

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Abstract:The main focus of the paper is to introduce a new approach at studying and modelling the relationship of initial water saturation profile and capillarity in water-wet hydrocarbon reservoirs, and describe the available measurement methods and possible applications. As a side track it aims to highlight a set of derivable parameters of mercury capillary curves using the Thomeer-method. Since the widely used mercury capillary pressure curves themselves can lead to over-, or underestimations regarding in-place and technical volumes and misinterpreted reservoir behaviour, the need for a proper capillary curve is reasonable. Combining the results of mercury and centrifuge capillary curves could yield a capillary curve preserving the strengths of both methods, while overcoming their weaknesses. Mercury injection capillary curves were normalized by using the irreducible water saturations derived from centrifuge capillary pressure measurements of the same core plug, and this new, combined capillary curve was applied for engineering calculations in order to make comparisons with other approaches. The most significant benefit of this approach is, that all of the measured data needed for a valid drainage capillary pressure curve represents the very same sample piece.

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“…Numerous studies generalized and extended the Kozeny-Carman equation [45]. Recently, Krause et al [61] pointed out that such a relationship may be in contradiction with the porosity-permeability correlation implied by the capillary pressure scaling law [68], which also is used for evaluating the permeability from porosity measurements [42,100], including tight sands [27,106]. Image subsampling and flow simulations shows a power-low trend.…”

Section: Simulation Of the Flow And Evaluation Of Permeabilitymentioning

confidence: 99%