Rock-fabric-specific capillary pressure models were developed by Lucia (1995, 1999). New data acquired in this study compare well with the existing Class 1 model. However, new data from ARFN 2 and 3 samples do not fit previous models. We developed new models for ARFN 2 and 3 rocks using the Thomeer method. Saturation was calculated for the reservoir

The breakthrough pressures (Pb) and Thomeer shape factors (C) are defined for each capillary pressure curve We did this using data up to 1000psi mercury capillary pressure because this equates to the maximum reservoir thickness i.e. 200m Thomeer Model in a Tight Gas Reservoir

Mohamed S. El Sharawy 60 Thomeer (1983) model (Eq. 24) gives a good correlation, when using (Fg), that derived from the type curve. Using (Fg) derived from Wu (2004) method, the relation is improved considerably and recorded the highest correlation among the used models (Table 3). The Thomeer hyperbolas so determined are converted to capillary pressure curves. Continuous capillary pressure (P c ) curves of subsurface rock formations adjacent wells are determined based on translation relaxation time (T 2 ) data from nuclear magnetic resonance (NMR) and from wireline well logs, such as resistivity logs, to obtain water saturation (S w ) of the rock in the formations. I also incorporate characteristics of capillary pressure behavior using the classic Brooks-Corey power-law model.

With this methodology, capillary pressure will cover a larger volume of the reservoir than the volume covered by the SCAL. J. H. M. Thomeer, “Introduction of a Pore Geometrical Factor Defined by a Capillary Pressure Curve,” Transaction of AIME, Vol. 219, No. 2057, 1960, pp. 354-358. core.

Wireline logs can ap-proximate what these water saturations may be, but do not actually measure Sw directly. Hence, when it comes to building reservoir models and estimating volumes in-place, capillary pressure based saturation-height models are used to describe Sw. OURSE OJETIVES the target audience. Mohamed S. El Sharawy 60 Thomeer (1983) model (Eq.

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The foundation of my new model is the petrophysical relation between absolute permeabil- ity and capillary-pressure/wetting phase saturation properties. I also incorporate characteristics of capillary pressure behavior using the classic Brooks-Corey power-law model. The final form of my new proposed model allowed us to Converting Capillary Pressures to the Height Domain. The pressure gradients for the oil and water phases are determined by the fluid densities.

2017-04-26

•The Thomeer model of capillary pressure is a hyperbolic relation between Mercury Injection. Pressure (Pc) and Bulk Volume (Vb) Occupied (by the non- wetting 12 Apr 2018 injection capillary pressure (MICP) data by using Thomeer hyperboles, with proven application in a tight carbonate reser- voir in the Middle Thomeer proposed a model of the following form for describing mercury-injection capillary pressure data: RTENOTITLE.

J. H. M. Thomeer, “Introduction of a Pore Geometrical Factor Defined by a Capillary Pressure Curve,” Transaction of AIME, Vol. 219, No. 2057, 1960, pp. 354-358. The capillary pressure function We propose the following functional form for capillary pressure curves:; (1 ') (1) ' a S S n S S d P P o c c > > + − = where , o P c is the capillary pressure scaling factor, S, S' are mobile and ir reducible saturation fractions, respectively, d defines the curvature and controls the distance, f(d) , from the level is defined as the elevation where the capillary pressure is zero. The above equation gives the mapping between the elevation and the capillary pressure.
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It is based on previous study, and largely empirical. It is tested with over 200 samples covering a wide range of lithology iv (clean sandstone, shaly sandstone, and carbonates dominated by intergranular pores). Capillary Pressure Model. Andy May (10/2/2013) The capillary pressure model is based entirely upon special core analysis. Following is a description of the model.

2016-01-19 The Thomeer Analysis is a method to evalute mercury injection capillary pressure (MICP) data. The resulting fitting parameters (displacement pressure, pore geometric factor, Bulk volume occupied at infinitive pressure) can be used to characterize the pore structure and to build a saturation model.
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THE OPTIMUM MODEL FOR PERMEABILITY PREDICTION FROM MERCURY INJECTION CAPILLARY PRESSURE DATA: A CASE STUDY OF THE NUBIA SANDSTONE, GULF OF SUEZ, EGYPT

I also incorporate characteristics of capillary pressure behavior using the classic Brooks-Corey power-law model. The final form of my new proposed model allowed us to predict absolute permeability as a function of effective porosity, irreducible wetting phase saturation, displacement or threshold pressure corresponding pore throat radius, and basic pore size characteristics.

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The capillary pressure curves of the three different blocks are described in figure 3(a). The capillary pressure curves can characterize the pore structure of the core samples. There are multiple pore structures among the selected core samples because of the various capillary pressure curves.

The technique is based on the observation that the location and shape of a capillary pressure curve reflect characteristics of the pore structure of the sample. Thomeer J. H. M., Introduction of a pore geometrical factor defined by the capillary pressure curve, J Petrol Technol 1960, 12, 73–77. [33] Purcell W. R., Capillary Pressures – Their Measurement Using Mercury and the Calculation of Permeability Therefrom, J Petrol Technol 1949, 1, 39–48.