Permeability versus porosity

Make a plot of absolute permeability versus porosity for a 50 micron pore size using the Carman-Kozeny relationship. 

FIGURE 2.19 Permeability versus porosity plot for shaly sands with three different clay types pore-filling kaolinite, pore-lining chlorite, and pore-bridging illite. Redrawn after Neasham (1977). 

The paper of Neasham (1977) allows an insight (Fig. 2.19) and it demonstrates in a permeability versus porosity plot the influence of clay t5tpe and morphology. 

Figure 2.21 shows permeability versus porosity for non-vuggy carbonates. The average particle size is used as the controlling parameter. Straight lines separate data collectives with respect to particle size. The figure confirms two tendencies as learned from siliciclastic sediments ... 

FIGURE 2.23 Permeability versus porosity for carbonate samples from Austria HD— Hauptdolomite, WD—Wettersteindolomite. Muller-Huber (2013). 

Muller-Huber (2013) investigated low porous carbonate rocks from Austria. Figure 2.23 shows a plot of permeability versus porosity. The measured permeabilities range from slightly less than 0.05 up to 1190 md. In elastics, permeability depends strongly on porosity, fri craitrast, the permeability of carbonates is controlled not solely by porosity, but also by the pore and fracture geometry. 

Fig. 16. Helium permeability and porosity versus depth, showing generally higher values of permeability and porosity above the oil-water interface due to continuation of cementation and compaction in the water zone.

Fig. 2.22 Permeabilities derived from least square inversion based on Biot-Stoll s theory versus porosities for the four sediment cores 40KL, 47KL, GeoB2821-l, and PS2567-2. The regular spacing of the permeability values is due to the increment (10 permeability values per decade) used for the optimization process in the inversion scheme. NFO and FNO as in Figure 2.19. Modified after Breitzke (2000).

FIGURE 4 Air permeability versus bulk porosity of nanofiber mats. 

In damage assessment, it is necessary first to find information on the reservoir geology, as well as the mineralogy. An understanding of the rock type (sandstone or carbonate) and other features, including permeability and porosity, is critical. This includes the nature of porosity (matrix versus naturally fractured) and how permeability is distributed (i.e., how it varies) across the producing interval—or the injection interval, as the case may be. 

Besides porosity, the pore size has a dominant influence on permeabihty. Figure 2.17 shows permeability versus grain size for Bentheim sandstone with a strong correlation. Regression results in the equation... 

Bang et al. (2000) published experimental data from a North Sea well interval and plotted vertical permeability versus horizontal permeability (Fig. 2.20). The reservoir is a homogeneous sand body with generally high porosities (up to 30%) . 

FIGURE 2.21 Permeability (air) versus porosity for various particle-size groups in non-vuggy carbonate rocks. Lucia (1983, 1999, 2007). 

Figure 4-293. Invasion diameter versus invasion time for various formation permeabilities, (a) Filtrate invaded porosity 20% mudcake permeability 1 pd mudcake thickness 0.25 differential pressure 500 psi. (b) Filtrate invaded porosity 30% mudcake permeability 1 pd mudcake thickness 0.25 differential pressure 500 psi. (Courtesy Louisiana State University [99]. ...

Fig. 3.7.4 (A) CRMI results of pressure versus volume on the Berea sandstone sample with a porosity of 20% and permeability 0.2 darcy. The two lines are raw CRMI data and the corrected data by a calibration run. Transducer noise was also filtered. The amount of the correction is fairly small and the two data sets overlap. (B) CRMI pore body volume distribution showing a predominant peak at around 20 nL. Figure from Ref. [57] with permis-...

A) Pressure-controlled mercury porosimetry procedure. It consists of recording the injected mercury volume in the sample each time the pressure increases in order to obtain a quasi steady-state of the mercury level as P,+i-Pi >dP>0 where Pj+i, Pi are two successive experimental capillary pressure in the curve of pressure P versus volume V and dP is the pressure threshold being strictly positive. According to this protocol it is possible to calculate several petrophysical parameters of porous medium such as total porosity, distribution of pore-throat size, specific surface area and its distribution. Several authors estimate the permeability from mercury injection capillary pressure data. Thompson applied percolation theory to calculate permeability from mercury-injection data. 

Fig. 8. Matrix porosity versus permeability reduction in faults. The upper trend describes the range of permeabilities observed within actively deforming cataclastic deformation bands. Permeabilities ate enhanced at low porosities, and slightly reduced at high porosities. The lower trend describes how inactive faults after burial show highly reduced permeability relative to the matrix. This permeability reduction gets more significant with increasing matrix porosity.

Fig. 8. Porosity versus air permeability for Norphlet sandstones from Mobile Bay. The data plotted are from the reservoir interval and are divided according to stratification type (determined by examination of core). Tight-zone samples have porosity <8% and air permeability < 1 mD regardless of stratifieation type and are excluded from this plot.

Coupling relations between seepage field and deformation field include relations among porosity and permeability change versus stress and pore pressure, as expressed in a exponential function in equation (11) and the effects of flow on mechanical... 

Because the ceramic porous structure depends on the shape of individual grains and the way they are packed, different factors can affect the two major characteristics of membrane supports, mechanical strength and porosity. The pseudoplastic behavior of the paste during extrusion is responsible for an exponential dependence of extrusion velocity versus applied pressure. High pressures to increase support permeability and strength have been emphasized in the literature [14]. These can be linked to a better (more dense) particle pack-... 

Figure 1. Plots of permeability, Ar, versus intercommunicating (open) porosity, specific surface area (per unit of pore volume) and irreducible water saturation, are considered in the data fitting, showing both the measured and fitted data for VuktyPskiy gas-condensate deposit, USSR. 

The pore volume (later referred to as PV or t) and the porosity, ( ) of the dry packed core is first determined from the weight and measured grain density of the Ottawa sand (2.65 g/cc) and the bulk volume of the core. The permeability of the sandpack to gas is then measured in a N2 permeameter from a minimum of six values of pressure drop versus flowrate. The core is placed in a multifluid flow displacement apparatus for saturation with brine or fresh water. The saturated core is oil flooded to irreducible water saturation, at rates which make the capillary pressure... 

The manufacture of DPMs based on infiltrated molten carbonates in the porosity of perovskite membranes constitutes the most recent and innovative application of perovskites for CO2 capture. Since the first studies reported by Wade and coworkers [33] and Lin and coworkers [34], many efforts have been made to develop stable high-flux membranes for CO2 separation. Table 39.5 collects the most remarkable results, whereas Figvue 39.12 plots the permeance versus permeability plots for dual-phase perovskite-carbonate materials compared with low-temperature CO2 separating membranes (zeolites and MOFs/ZIFs). 

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