Evaluation Of Capillary Character In Petroleum Reservoir Rock

Rose, Walter; Bruce, William A.

doi:10.2118/949127-g

Cited by 93 publications

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“…This fact was confirmed by Brown [4], and Rose and Bruce [5]. Guthrie and Greenberger [1] proposed a linear correlation of the water saturation with porosity and permeability at a constant value of capillary pressure.…”

Section: Introductionmentioning

confidence: 76%

A New Method for Normalization of Capillary Pressure Curves

Desouky

2003

Oil & Gas Science and Technology - Rev. IFP

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Résumé -Nouvelle méthode pour la normalisation des courbes de pression capillaire -Une nouvelle méthode pour la normalisation de données de pression capillaire d'un réservoir a été développée. Celle-ci incorpore les effets de géométrie de pore (distribution de taille de pores et indicateur de zone d'écoulement), de lithologie et de saturation irréductible en eau. L'approche par zone d'écoulement a été utilisée pour classifier le réservoir en zones de géométrie de pore constantes. La fonction de Leverett a été alors corrélée à la saturation en eau normalisée pour chaque zone de réservoir pour grouper les données de pression capillaire de cette zone sur une courbe de tendance. La méthode nécessite des mesures de pression capillaire, de saturation irréductible en eau, et des données classiques de pétrophysique telles que la perméabilité et la porosité. Afin de vérifier la validité de la méthode proposée, les données de pression capillaire, saturation irréduc-tible en eau, et des données classiques de pétrophysique de grès argileux dans le golfe de Suez (Égypte) ont été obtenues et utilisées pour déterminer la précision des relations développées. Les calculs ont montré que le réservoir étudié possède quatre zones de géométrie de pore constantes. Un excellent accord existe entre les données mesurées et celles calculées avec des erreurs relatives moyennes de -5,8, -4,3, 3,7 et 4,4 % respectivement pour les zones de d'écoulement 1, 2, 3 et 4. of -5.8, -4.3, 3.7 and 4.4% for flow unit-1, unit-2, unit-3 and unit-4, respectively. Abstract -A New Method for Normalization of Capillary Pressure Curves -A new method for normalization of capillary pressure data of a reservoir was developed that incorporates the effects of pore geometry (pore size distribution index and flow zone indicator index), lithology index and irreducible water saturation. The hydraulic flow unit's approach was used to classify the reservoir formation into

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Section: Introductionmentioning

confidence: 76%

A New Method for Normalization of Capillary Pressure Curves

Desouky

2003

Oil & Gas Science and Technology - Rev. IFP

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“…For ideal uniform and unconsolidated rocks, Leverett 1940 computed the value of this term to be about 5. However, Rose and Bruce 1949 showed that this term (F S τ 2 ) could vary from 5 to 100 in real reservoir rocks. Many investigators have attempted to calculate permeability from porosity by using Eq.…”

Section: Hydraulic Zonation Theorymentioning

confidence: 99%

Flow units delineation of multiple hydrocarbon reservoirs using hydraulic zonation technique via cluster analysis algorithm, Zeit Bay Field, Gulf of Suez, Egypt

2016

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Investigation of hydraulic units in drilled wells through multiple reservoirs in Zeit Bay Field is the main target of this paper. Karim Limestone and Nubian Sandstone are target reservoirs in this study. Hydraulic zones provide a fundamental unit for subsequent reservoir characterization and simulation and also prove to be helpful in defining future well completion and work over practices. Hydraulic zonation by means of cluster analysis has been utilized to achieve this target. Hierarchical cluster analysis, elbow method, and kmeans clustering are the main steps of this analysis. Petrophysical properties obtained from cores are utilized to perform this zonation. These properties are permeability and porosity data. Results have been validated by comparing the geological behavior of each zone against the measured permeability curve. Finally through this zonation, flow units which have the potential to extract fluids are determined more accurately. Petroleum geologists and engineers are more interested in these results. The cluster analysis flow suggesting in this paper is cost-effective due to lack of need for any commercial software.

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“…According to Rose and Bruce (1949), the shape of the capillary pressure curves is the primary indication of pore geometry. High capillary pressure primarily shows the existence of small pores.…”

Section: Rock Typing From Pore Size Distributionmentioning

confidence: 99%

Rock Typing of Tight Gas Sands: A Case Study in Lance and Mesaverde Formations From Jonah Field

Aliyev

2015

Day 3 Wed, September 30, 2015

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The Jonah field is one of the biggest tight gas sand fields in the Green River basin. Production profiles from its deeper sections show high liquid hydrocarbons close to the Pinedale anticline, especially in Mesaverde and Lance formations. To assess the potential of condensate production, new approaches for rock classification are needed that will allow us to differentiate between discontinuous sandstone layers and the interbedded siltstones. Currently, the only cutoff used is for gamma ray: rocks below 75 API are designated as sandstones.Although, significant porosity and permeability variations occur within the sandstone zones, the only criterium used to differentiate between reservoir and non-reservoir rocks is porosity: sandstones with porosity > 6% are considered reservoir quality rocks. Porosity is considered main controlling factor on permeability. A 6% porosity cut off in sandstones was used in net-pay calculations. However, hydraulic rock typing demonstrates permeability is dependent on main pore throat radius, rather than porosity. This study presents rock typing for tight sandstones and siltstones with an understanding of petrophysical properties such as pore structure, porosity, permeability, and cementation.I studied 14 samples from the Mesaverde and Lance Formations with lithologies varying from clean sandstone to mudstone. X-ray diffraction (XRD) mineralogy and mercury injection capillary pressure (MICP) were measured for all samples. NMR transverse relaxation times (T 2 ) at 2 MHz were also measured for 10 water saturated samples. Nitrogen adsorption tests were performed on 8 samples. Ultrasonic velocities from 10 samples were measured at different confining pressure conditions. Thin section petrography was used to analyze the cementation and pseudomatrix clay effects on pore and pore throat size.MICP data are used to subdivide rocks into three groups based on pore throat size distribution: reservoir sandstones, non-reservoir sandstone and siltstone/mudstone. Dominant pore throat size for reservoir and non-reservoir sandstones are 400 and 100 nm, respectively.iii In order to apply pore throat size rock typing to downhole measurements, NMR pore size classification is used to identify formations. Pore size from NMR demonstrated equivalent behavior to pore throat size from MICP. The logarithmic mean values of T 2 transverse relaxation times for reservoir, non-reservoir sandstone and siltstone/mudstone are 22.2 ms, 3.4 ms and 0.29 ms, respectively. Clear separation of reservoir sandstone, non-reservoir sandstone and siltstone is seen based on compressibility behavior from compressional velocity during initial pressure loading. Reservoir sandstone demonstrates the highest compressibility. In addition, siltstone and mudstone were separated based on log differential pore volume distribution from N 2 adsorption data.Based on pore size distribution data, four main rock types are identified in Lance and Mesaverde formations in Jonah field. Rock typing based on gamma ray and porosity logs can be con...

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Evaluation Of Capillary Character In Petroleum Reservoir Rock

Cited by 93 publications

References 0 publications

A New Method for Normalization of Capillary Pressure Curves

A New Method for Normalization of Capillary Pressure Curves

Flow units delineation of multiple hydrocarbon reservoirs using hydraulic zonation technique via cluster analysis algorithm, Zeit Bay Field, Gulf of Suez, Egypt

Rock Typing of Tight Gas Sands: A Case Study in Lance and Mesaverde Formations From Jonah Field

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