Capillary Pressure Behavior Research Articles

Experimental investigation of capillary pressure diagram in oil/water transition zone of low-permeability reservoirs

The oil/water transition zone, particularly pronounced in low-permeability formations with small pore diameters and high capillary pressure, contains a substantial portion of original oil in place. The capillary pressure curves provide essential data for the calculation of the original oil in place as well as the oilfield development simulation. However, the traditional single capillary pressure curve cannot provide enough information. To address this challenge, an experimental investigation was conducted to explore the capillary pressure diagrams within the oil/water transition zone of low-permeability reservoirs. The results shed light on the complex behavior of capillary pressure, the influence of initial water saturation, and the relationship between initial oil saturation and residual oil saturation. Incorporating the behavior of capillary pressure into reservoir simulation models can enhance reservoir characterization and improve the accuracy of oil production performance in low-permeability reservoirs.

Comparison of the mathematical modelling results of the relationship between cerebral ventricular size and capillary pressure based on experimental and clinical data

Aim of the study was to compare the results of mathematical modelling of the dependence between brain ventricle size and capillary pressure for humans and animals based on the equations of multicomponent poroelastic filtration for brain parenchyma. Material and methods. The study included two groups of animals - 4 male mice of each inbred line C57Bl/6 and BALB/C at the age of 12 weeks – and 4 healthy volunteers. The brain and cerebrospinal fluid system images of mice were obtained using an 11.7 T horizontal MR scanner, group of humans were examined using the Ingenia 3.0 T MRI scanner. An axial section at the level of –0.5 mm from bregma in the mouse groups and a frontal slice at the level of the middle of the bodies of the lateral and third ventricles, posterior to the foramen of Monroe in the human group were chosen as the geometry for mathematical modelling. Mathematical modelling is based on the stationary mathematical model of multicomponent poroelastic filtration. Multiple linear regression of mean ventricular wall displacement on fluid media interaction parameters was constructed to compare results obtained. Regression coefficients were compared using nonparametric analysis of variance based on the Kraskell–Wallis criterion and post-hoc Dunn’s criterion with Hill’s correction Results. A qualitative coincidence in the behavior of capillary pressure and mean ventricular wall displacement was demonstrated for the human and mouse groups. No significant differences were found between the two animal lines. For the animals characterized by small ventricular size (BALB/c), greater similarity to humans is observed than for the genetic line with hypertrophied ventricles (C57Bl/6). A significant difference between humans and mice is observed only for capillary-venous interaction. Conclusions. The low variance within groups and insignificant discrepancy between groups indicate the possibility of further accumulation of empirical data to establish correction coefficients of the animal model, which will bring it more in line with the model for humans. Thus, the analyzed models are sufficiently comparable with each other.

A critical review of capillary pressure behavior and characterization in fractional-wet reservoirs

A critical review of capillary pressure behavior and characterization in fractional-wet reservoirs

A new four stage model of capillary pressure in early age concrete: Insights from high capacity tensiometers

Capillary pressure is frequently measured to evaluate the shrinkage performance of concrete but has been limited to pressures <100 kPa preventing a better understanding of the early age factors affecting concrete durability. In this study, high capacity tensiometers (HCTs) were employed for the first time to investigate the behavior of early age concrete. The evolution of capillary pressure in Self-Consolidating Concrete (SCC) with and without shrinkage reducing admixture was evaluated. The results demonstrate that HCTs are capable of measuring capillary pressure beyond 1500 kPa. This transformative new record of capillary pressure behavior has enabled the development of a model for the capillary pressure in early age concrete correlated to water evaporation, self-desiccation, setting time, temperature, and hydration processes. This ability to quantify real-time capillary pressure change in concrete generates important implications for optimizing the commercial durability of SCC and for understanding the link between early age concrete processes and resultant mechanical performance.

Modeling and monitoring of foam propagation in highly permeable porous media under lateral water flow

Foam injection is a promising option for soil remediation applications. However, predicting how it will propagate in highly permeable aquifers under groundwater flow is challenging. Here, we have studied pressure and saturation variations during foam propagation. A 2D tank packed with 1 mm glass beads was used to study foam injection in highly permeable porous media under lateral flow. Specifically, we evaluated the efficiency of pressure and time-domain reflectometer (TDR) sensors to predict foam propagation using an imaging technique. A numerical model coupling two-phase flow and surfactant transport was developed to simulate the experimental results. This model takes into account the effect of non-Newtonian behavior of foam, surfactant concentration, and critical capillary pressure through the definition of the mobility reduction factor (MRF). The experimental results show that the foam injection pressure first increases with a logarithmic law and then stabilizes. This pressure stabilization can be related to the state of pseudo-equilibrium between foam generation and destruction. We observed an asymmetrical foam propagation due to water lateral flow. Comparisons of the liquid saturation fields calculated by analysis of TDR probes and estimated by imaging show that the TDR sensors monitor foam propagation well in saturated porous media. They can predict the shape of the injected foam. Contrary to pressure sensors, it is possible to capture weak foam behavior using TDR sensors. Finally, the numerical model we have developed correctly captures the shape of foam propagation and its ability to divert water flows. This model produces the propagation of the strong foam well and predicts the saturation and pressure fields with good precision.

Capillary Pressure Behavior of CO2 - Shale System at Elevated Temperatures

In this study, changes in capillary entry pressure of shale when interacting with CO2, under different temperatures have been investigated. The combined impact of temperature and petrophysical properties of shale (water content, water activity, permeability and porosity) on capillary entry pressure was addressed. Pressure breakthrough measurements were used to evaluate the minimum entry pressure of CO2 through shale. A heavy-duty oven was used to vary the temperature in order to investigate the impact of temperature on CO2 capillary entry pressure through shale. Results showed that capillary entry pressure of shale when interacting with CO2 was highly affected by temperature. Higher temperatures decreased capillary entry pressure of shale. We believe that pore dilation, where pore throat size expands due to the application of heat, may have caused this decrease in capillary entry pressure. However, in some cases higher temperature activated clay swelling that may have caused an apparent decrease in pore throat radii of shale which translated into higher capillary entry pressure. Results also showed that there exists no distinct relationship between petrophysical properties of shale and its measured capillary entry pressure when interacting with CO2 at different temperatures. Heat could alter pore throat radii and cause pore dilation which may alter measured capillary entry pressure. Interfacial tension decreases with increasing temperature and that can be attributed to the weakening of intermolecular forces at the two immiscible fluids interface. Swelling of clay could be related to temperature-induced transition from passive to an active clay.

Developing a saturation-height function for reservoir rock types and comparing the results with the well log-derived water saturation, a case study from the Fahliyan formation, Dorood oilfield, Southwest of Iran

Determining the potential of reservoirs and production zones is very important to reach maximum product performance and decrease hydrocarbon recovery costs. The calculation of the Water Saturation (SW) significantly affects oil-in-place estimations. The Saturation-Height Function (SHF) is operated to predict the saturation in the reservoir for a given height above the free water level. Typical approaches for predicting water saturation as a function of rock properties and height above contact include two types, those based on capillary pressure curve averaging and log-based techniques. The goal of this study is to define an appropriate SHF and SW using the usual functions to delineate production zones using rock typing with an example from the Dorood oilfield in the Persian Gulf. In this study first, the reservoir has been divided into different rock types and water saturation is estimated by different methods in each rock type. The Reservoir Quality Index (RQI) along with Water Saturation profile for representative rock types were used for determining reservoir zones. Accordingly, a formulation was developed to model the behavior of Capillary Pressure (PC) as a characteristic of SW and to determine the Free Water Level (FWL) based on laboratory data. To achieve this goal, the appropriate saturation-height functions and their coefficients were chosen for representative reservoir rock types. The Pc curves are classified based on Discrete Rock Types (DRT) and a proper saturation-height function was assigned for individual rock types. Finally, some of the most common equations for calculating SHF were fitted to the representative Pc curve of each rock type and coefficients of the equation for any rock type were determined by using the MATLAB software in the studied carbonate reservoir. After investigating the results of fitting different SHF, water saturation was calculated using a modified lambda function and compared with the log-derived water saturation. The SHF applied, could be used to estimate saturations of unreachable zones of the field.

ON CO2 SEQUESTRATION: CHANGES IN CO2 ENTRY PRESSURE AND ADSORPTION CAPACITY BY HEAT

Geological sequestration of CO2 requires a deep permeable geological formation where captured CO2 can be stored and an overlying impermeable caprock that prevents buoyant CO2 from leaking upward to the surface. Shale formations are good seals due to their abundancy and typically ultralow permeability. Shale's excellent sealing ability makes it a good caprock formation. The correct evaluation of the CO2 sequestration ability of shale caprocks, also referred to as sealing capacity, must be conducted under high-pressure and high-temperature conditions representative of in situ conditions. The CO2 sequestration quality of shale caprocks, sealing capacity, is usually evaluated through measurements of CO2 capillary entry pressure into shale caprocks. In this work, CO2 capillary entry pressure in different shales under a wide range of temperatures (298-428 K) is measured using an incremental pressure transmission methodology. The impact of temperature on the physicochemical and petrophysical properties of shale is addressed, and their indirect effect on CO2 capillary entry pressure is analyzed. Furthermore, the influence of temperature on interfacial tension between CO2 and shale's pore fluid and contact angle is examined. Also, the effect of temperature on CO2 sorption on clay sites is analyzed. The experimental outcome exhibited that capillary entry pressure increases steadily and appreciably for shales (A and B) up to a certain temperature (around 358.15 K), after which the behavior of capillary entry pressure of CO2 for both shales changes markedly. For shale (A), the increase in measured capillary entry pressure for temperatures above 358.15 K slows down significantly, ranging between 841 and 851 psi compared to its measured value of 835 psi at 358.15 K. As for shale (B), the reaction is completely different, where measured capillary entry pressures of CO2 for temperatures above 358.15 K decreased noticeably as measured capillary entry pressures dropped from 534 psi at 358.15 K to 473 psi at 428.15 K. Results show that temperature has a profound impact on CO2 capillary entry pressure when interacting with shales through the alteration of shale's physicochemical and petrophysical properties. Data suggests that pore throat size could be altered by heat through a phenomenon called pore dilation. It was also clearly shown that higher temperature causes higher interfacial tension, which indeed causes higher capillary entry pressures when CO2 interacts with shale. Moreover, results indicate that high temperature could energize active swelling clays and invoke a transition of inactive clays to active swelling clays. High temperature causes clay swelling and may produce hydrational and expansive stresses in shale, especially when confined, which could induce fissures and microfractures. The creation of fissures and microfractures could enhance shale's average pore radii and permeability, thus reducing the capillary entry pressure. In addition, results suggest that the adsorption capacity of CO2 on clay sites decreases with increasing temperature and that the presence of smectite clay greatly enhances the swelling potential of shale upon exposure to CO2.

Application of Nanotechnology in Enhanced Oil Recovery

Responding to the growing demand in the oil industry is possible in two ways: by finding new hydrocarbon resources or by increasing extraction from existing oil reservoirs. Increasing production efficiency by modifying EOR methods is quite obvious while the process of exploring new oil fields is declining and many oil fields are in the final stages of production; Because in many reservoirs of the world about two-thirds of the oil in situ cannot be extracted by conventional methods. Recovery mechanisms in EOR operation can also be enhanced using nanotechnology. Nanotechnology-assisted EOR processes depend on several factors: mobility control using viscosity-increasing solutions, altering the rock wettability, reducing the interfacial tension (IFT), and lowering the oil viscosity using nanocatalysts. The efficiency depends on how the process behaves at both the macro and micro scales. The microscopic efficiency considers the displacement of the fluids at a poral scale and measures how effective the displacing agent is in mobilizing oil and rocks to make contact. In this regard, the geometry of the pores, capillary pressure, viscous forces, rock wettability, and rheological behavior play a major role. The macroscopic efficiency is the relationship between the connected reservoir volume being swept by the injected fluid and the volume of oil originally in the reservoir and parameters affecting this factor are: the rock heterogeneity and its anisotropy, the absolute permeability, the mobility ratio, and the gravitational segregation. Downstream processes such as petroleum refining are employed to extract up to 40% more gasoline in catalytic cracking units than their predecessors. In upstream operations, the first application of nanotechnology was the development of nano-enhanced materials. Nanotechnologically enhanced oil recovery processes involve (a) the addition of nanoparticles in the displacing agent enhancing its rheological properties, which are known as nanofluids; (b) the use of nanoparticles as stabilizing agents in the formation of nanoemulsions; and finally, (c) active nanoparticles working as nanocatalysts injected to perform in-situ upgrading operations in the porous medium before extraction.

Contribution of dynamic capillary pressure to rainfall infiltration in thin homogeneous growth substrates

The use of green roofs to help mitigate storm water contributions to urban flooding has been gaining popularity but is hindered by the limited data on the performance of such roofs with regard to storm water runoff mitigation. The underlying issue stems from the inherent complexity of modeling subsurface multiphase flow. Modeling of this phenomena requires calculating the contributions of substrate microstructure characteristics, the influence of the wetting and non-wetting phases upon each other, and the effect of the microstructure on the wetting phase. Previously we have observed how the microstructure can affect detention, however the quantification of this relationship is still missing. In the present paper we present numerical simulations of wetting phase infiltration of a thin monodisperse packed bed in order to understand and quantify the impact of microstructure geometry on storm water infiltration of a green roof substrate. For a slightly hydrophilic case, (θ=82°), we find that a dominant mechanism underlying this relationship is the microstructure-induced dynamic behavior of the capillary pressure. We determine that at larger packing ratios (ratio of packed bed depth to particle size), the influence of hydraulic head diminishes and behaves conversely for thinner layers, particularly when larger pores are present. Indeed, thin beds composed of large particles can exhibit high flow velocities that in turn affect the capillary pressure within the substrate. We observe that the capillary pressure can shift from negative values denoting capillary suction to positive ones which cause valve-like blocking effects on the flow; dependent upon the flow velocity as determined by the microstructure. In particular, we find that the capillary pressure depends on the value of the pore-scale gravity-induced flow velocity, quantified through a characteristic Capillary number. The provided quantification of this relationship can be invaluable from a design perspective to understand the behavior of capillary pressure of different substrates under a variety of flow rates prior to testing substrate candidates. In addition, a comparison of the behavior of the dynamic component of capillary pressure to other works is undertaken. Flow homogeneity is also found to be linked to the flow velocity, and consequently to the microstructure.

Analysis of evaporating liquid bridge in horizontal fractures

The formation of liquid bridge is pertinent to many fields including seepage into underground fractured rocks as an environmental issue and capillary continuity between matrix blocks which controls oil recovery in fractured reservoirs. Evaporation from the surface of liquid bridge into the surrounding gas could affect the stability of liquid bridge and fracture capillary pressure, which is not well discussed in the available literatures. In this research, by the aid of analogy between the diffusive flux and electrostatic potential, a new model for predicting evaporation rate from a liquid bridge inside a horizontal fracture is presented. The proposed model is then coupled with Young-Laplace equation to evaluate volume, shape and capillary pressure of liquid bridge as evaporation proceeds. Close agreement (R2 = 0.994) observed between model predictions and experimental data of evaporating liquid bridge, confirms reliability of the assumptions and the methodology made in model development. For the first time the impact of presence of solid substrate on evaporation rate as a function of liquid bridge volume, length and contact angle is described by a new mathematical expression. It has been found that transient behavior of fracture capillary pressure for a more realistic mode of evaporating liquid bridge, in which both contact angle and contact line change, indicates an initial increase, reaching to a maximum value, and finally a sharp decrease before rupture of bridge. In some cases, the capillary pressure of evaporating liquid bridge might reach to twice/half of its initial value. For liquid bridges with sufficient initial volume in thin fractures, stability period is prolonged and fracture capillary pressure values are greater, resulting a higher degree of capillary continuity. Results of this work help to better understand the gas-liquid transport in fractured porous media incorporating mass transfer between liquid bridge and surrounding gas for possible application in simulation models.

Methodology for Concurrent Multi-Parametric Physical Modeling of a Target Natural Unfractured Homogeneous Sandstone

In petroleum, geological and environmental science, flow through porous media is conventionally studied complementarily with numerical modeling/simulation and experimental corefloods. Despite advances in numerical modeling/simulation, experimental corefloods with actual samples are still desired for higher-specificity testing or more complex mechanistic studies. In these applications, the lack of advances in physical modeling is very apparent with the available options mostly unchanged for decades (e.g., sandpacks of unconsolidated packing materials, industry-accepted substitutes with fixed/mismatching petrophysical properties such as Berea sandstone). Renewable synthetic porous media with adjustable parameters are the most promising but have not advanced adequately. To address this, a methodology of advanced physical modeling of the fundamental parameters of dominant mineralogy, particle size distribution, packing, and cementation of a target natural porous media is introduced. Based upon the tight physical modeling of these four fundamental parameters, the other derived parameters of interests including wettability, porosity, pore throat size distribution, permeability, and capillary pressure can be concurrently modeled very close as well by further fine-tuning one of the fundamental parameters while holding the rest constant. Through this process, concurrent multi-parametric physical modeling of the primary petrophysical parameters including particle size distribution, wettability, porosity, pore throat size distribution, permeability, capillary pressure behavior in a target sandstone becomes possible.

Parametric modeling of autogenous shrinkage of sodium silicate-activated slag

In this study, a simple modeling scheme was employed to observe the autogenous shrinkage of sodium silicate-activated slag (SSAS)- one of the most widely used alkali-activated materials. The model parameters, including internal relative humidity, saturation degree of pores, capillary pressure, bulk modulus, and hydration degree were experimentally obtained. The mechanism of SSAS shrinkage was explored using the obtained modeling parameters, which may have some physical quantities, and was discussed comparatively with the shrinkage characteristics of OPC. The results indicated that the most important factors influencing the large shrinkage of SSAS were the high capillary pressure and creep-like behavior, which correlated with pore formation, rather than the stiffness of the matrix and the hydrate type.

A new formulation for non-equilibrium capillarity effect using multi-gene genetic programming (MGGP): accounting for fluid and porous media properties

Dynamic coefficient as an important parameter in determination of the dynamic behavior of capillary pressure is considered as a function of various fluid and porous media properties. In this study, a new and general formulation for predicting the dynamic coefficient was proposed and developed through which the key fluid and porous media properties are accounted for. For expressing new formulation, multi-gene genetic programming (MGGP) was employed. Efficiency and robustness of the proposed model were investigated through experimental data and statistical measures of performance. A parametric study was designed to evaluate the impact of different parameters on the dynamic coefficient. Results show that the developed model is valid for a wide range of the conditions of two-phase flow in porous media. The model is a prerequisite for the accurate design, modeling, and application of dynamic capillarity effect in various fields of fluid flow in porous media. Furthermore, a new dimensionless number, the so-called dynamic effect number, was proposed and formulated which quantifies dynamic capillary force to viscous force ratio. Such a number would be useful and practical for the upscaling process and quantification of dominant forces in two-phase flow in porous media where limited experimental data are present.

Inertia Controlled Capillary Pressure at the Juncture between Converging and Uniform Channels

In this research, we reveal the transient behavior of capillary pressure as the fluid-fluid interface travels across the juncture between a converging and uniform capillary, via high-resolution CFD (Computational Fluid Dynamics) simulations. Simulations were performed at different wetting conditions (strong-wet and intermediate-wet) and capillary wall convergence angles. Our results demonstrate that as the angle of convergence increases, capillary pressure at the junction decreases commensurately. Moreover, in contrast to strong-wet conditions, the profile of capillary pressure at the converging-uniform capillary juncture under intermediate-wet conditions is highly non-monotonic, being characterized by a parabola-like form. This non-monotonic behavior is a manifestation of strong inertial forces governing dynamic fluid-fluid interface morphology. This yields conditions that promote the advancement of the fluid-fluid interface, as inertial forces partially nullify the capillary pressure required for the immiscible interface to enter the uniform capillary. In addition to numerical analysis detailed above, a novel theoretical stability criteria that is capable of distinguishing between stable (capillary dominated) and unstable (inertia dominated) interfacial regimes at the converging-uniform capillary juncture is also proposed. In summary, this fundamental study offers new insights into the interface invasion protocol, and paves the way for the re-evaluation of capillary junction controlled interfacial dynamics.

Impact of Confining Stress on Capillary Pressure Behavior During Drainage Through Rough Fractures

AbstractWe study, numerically, the behavior of capillary pressure (Pc) during slow immiscible displacement in a rough fracture as a function of the degree of fracture aperture heterogeneity that results from two distinct mechanisms: normal confining stress and fracture surface correlation. We generate synthetic self‐affine rough fractures at different correlation scales, solve the elastic contact problem to model the effect of confining stress, and simulate slow immiscible displacement of a wetting fluid by a nonwetting one using a modified invasion percolation model that accounts for in‐plane curvature of the fluid‐fluid interface. Our modeling results indicate that the power spectral density, S(f), of Pc, can be used to qualitatively characterize fracture aperture heterogeneity. We show that the distribution of forward avalanche sizes follows a power law , with exponent α=2, in agreement with previously reported values for porous media and equal to the expected theoretical exponent for a self‐organized criticality process.

English

This work aims to characterize petrographically some of the transition zone plug samples in order to understand the impact of diagenetic processes on the transition zone rock quality. Three carbonate samples were collected from the same well which cuts through a thick transition zone of a heterogeneous cyclic carbonate reservoir of Abu Dhabi with respect to depth. The petrographic analysis was conducted by the thin sections study and scanning electron microscope (SEM) imaging in order to interpret the main depositional facies, diagenetic features and how the poro-perm characteristics were affected by them. SEM analysis is utilized in order to observe and recognize in detail the diagenetic relationships between different mineral phases or cement types and to help in identifying the pore geometry. Diagenesis in the transition zone is very extensive especially affected by micritization and cementation. The diagenetic features are increasing with depth as the zone is having higher water saturations. The importance of this analysis is to better understand the rock fabric heterogeneity and capillary pressure behavior as a function of depth of thick carbonate transition zones. Key words: Transition zones, diagenesis, petrographic analysis, scanning electron microscope study, carbonate reservoirs.

Investigating the relative permeability behavior of microporosity‐rich carbonates and tight sandstones with multiscale pore network models

AbstractThe relative permeability behavior of rocks with wide ranges of pore sizes is in many cases still poorly understood and is difficult to model at the pore scale. In this work, we investigate the capillary pressure and relative permeability behavior of three outcrop carbonates and two tight reservoir sandstones with wide, multimodal pore size distributions. To examine how the drainage and imbibition properties of these complex rock types are influenced by the connectivity of macropores to each other and to zones with unresolved small‐scale porosity, we apply a previously presented microcomputed‐tomography‐based multiscale pore network model to these samples. The sensitivity to the properties of the small‐scale porosity is studied by performing simulations with different artificial sphere‐packing‐based networks as a proxy for these pores. Finally, the mixed‐wet water‐flooding behavior of the samples is investigated, assuming different wettability distributions for the microporosity and macroporosity. While this work is not an attempt to perform predictive modeling, it seeks to qualitatively explain the behavior of the investigated samples and illustrates some of the most recent developments in multiscale pore network modeling.

A new universal permeability model derived from mercury capillary pressure data

This paper presents the construction and verification of a new better semi-analytical, statistically derived universal model than that modified from Huet and Blasingame equation for estimating absolute permeability from mercury injection capillary pressure data. The foundation of my new model is the petrophysical relation between absolute permeability and capillary pressure/wetting phase saturation properties. I also incorporate the characteristics of capillary pressure behavior using the classic Brooks-Corey power-law model. The final form of my new proposed model allows 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. I built my model using 189 sets of mercury-injection (Hg-air) capillary pressure data and measured permeability including core samples from several reservoirs both carbonate and sandstone lithologies. I identified this correlation by quantifying its accuracy and precision based on regression analysis. I compare permeability estimates obtained from Huet and Blasingame mercury-injection capillary pressure-based model and my new universal predicted permeability model to a set of laboratory measured permeability of my studied core sample and previously published data results, respectively, where I quantifying the method's accuracy and precision based on error analysis. The measured permeability samples range is from 0.003 to 5,341 md. I review current employed models that are classified as belonging to Poiseuille model.

Using Capillary Pressure Derived Parameters for Improving Permeability Prediction

This paper presents the construction and verification of a new better semi-analytical, statistically derived universal model than that modified from Huet and Blasingame equation for estimating absolute permeability from mercury injection capillary pressure data. The foundation of my new model is the petrophysical relation between absolute permeability 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 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. I built my model using 189 sets of mercury—injection (Hg-air) capillary pressure data and measured permeability-including core samples from several reservoirs both carbonate and sandstone lithologies. I identified this correlation by quantifying its accuracy and precision based on regression analysis. I compared permeability estimates obtained from Huet and Blasingame mercury-injection capillary-pressure-based model and my new universal predicted permeability model to a set of laboratory measured permeability of my studied core sample and previously published data results respectively, where I quantified the method’s accuracy and precision based on error analysis. The measured permeability samples range is from 0.003 mD to 5341 mD. I review current employed models that are classified as belonging to Poiseuille model.