Re-evaluation of Petro physical Properties in Yammama Formation at Nasiriya Field

Jassim, Karrar Hayder; Al-Sudani, Jalal A.

doi:10.31699/ijcpe.2019.3.8

Cited by 4 publications

(4 citation statements)

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“…Ф is micro pores porosity, and Ф is macro pores porosity. Microporosity was adjusted by the factor ( = 0.75) to exclude matrix effect from micropores, and image porosity is calculated using Equation (22).…”

Section: Porosity and Pore Space Characteristics Determinationmentioning

confidence: 99%

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Digital Rock Samples Porosity Analysis by OTSU Thresholding Technique Using MATLAB

Tawfeeq

Al-Sudani²

2020

IJCPE

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Porosity plays an essential role in petroleum engineering. It controls fluid storage in aquifers, connectivity of the pore structure control fluid flow through reservoir formations. To quantify the relationships between porosity, storage, transport and rock properties, however, the pore structure must be measured and quantitatively described. Porosity estimation of digital image utilizing image processing essential for the reservoir rock analysis since the sample 2D porosity briefly described. The regular procedure utilizes the binarization process, which uses the pixel value threshold to convert the color and grayscale images to binary images. The idea is to accommodate the blue regions entirely with pores and transform it to white in resulting binary image. This paper presents the possibilities of using image processing for determining digital 2D rock samples porosity in carbonate reservoir rocks. MATLAB code created which automatically segment and determine the digital rock porosity, based on the OTSU's thresholding algorithm. In this work, twenty-two samples of 2D thin section petrographic image reservoir rocks of one Iraqi oil field are studied. The examples of thin section images are processed and digitized, utilizing MATLAB programming. In the present study, we have focused on determining of micro and macroporosity of the digital image. Also, some pore void characteristics, such as area and perimeter, were calculated. Digital 2D image analysis results are compared to laboratory core investigation results to determine the strength and restrictions of the digital image interpretation techniques. Thin microscopic image porosity determined using OTSU technique showed a moderate match with core porosity.

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Section: Porosity and Pore Space Characteristics Determinationmentioning

confidence: 99%

“…Porosity is a crucial property of rock due to measuring potential storage volume of hydrocarbons. In the carbonate reservoir, porosity ranges about 0.01-0.35 [22]. The volume fraction of void spaces, i.e.…”

mentioning

confidence: 99%

Digital Rock Samples Porosity Analysis by OTSU Thresholding Technique Using MATLAB

Tawfeeq

Al-Sudani²

2020

IJCPE

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“…The result is that brittle, ductile, fractured rocks, vugular pores, or tight formations may all exit within small intervals of these reservoirs [1,2]. Typically, coring and rock testing are the ideal methods to determine the rock's mechanical properties, but core samples can be only samples at a well location, as well as core samples, are normally limited due to cost and timesaving purposes [3,4]. To overcome these challenges, dynamic determination of rock mechanical properties can be considered as the starting point to quantify these properties for applications related to reservoir geomechanics.…”

Section: -Introductionmentioning

confidence: 99%

2D and 3D Modeling of Rock Mechanical Properties of Khasib Formation in East Baghdad Oil Field

Steer,

Hadi,

Ellafi

2023

IJCPE

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Knowing the distribution of the mechanical rock properties and the far field stresses for the field of interest is an important task for many applications concerning reservoir geomechanics, including wellbore instability analysis, hydraulic fracturing, sand production, reservoir compaction, and subsidence. A major challenge with determining the rock's mechanical properties is that they cannot be directly measured at the borehole. Furthermore, the recovered carbonate core samples for performing measurements are limited and they provide discrete data for specific depths. The purpose of this study is to build 2D and 3D geomechanical models of the Khasib reservoir in the East Baghdad oil field/ Central area. TECHLOG.2015.3 software was used to build the 1D-MEM while Petrel E&P 2018.2 software was used to build the 3D distributions of rock mechanical properties. The Khasib formation has nine units (from K1 to K9). The current results support the evidence that the horizontal stresses are somewhat similar for all layers in the vertical case, but their distribution varies horizontally due to the changes in pore pressures. The pore pressure increases vertically, but its distribution within one layer is different due to the production from different wells. Elastic and strength characteristics of rock, including Young modulus, Poisson ratio, and unconfined compressive strength (UCS), have the same behavior, the highest value of the parameters appeared in the surface layer (K1). This layer is more stiff than other layers that have high porosities and high permeability. The internal friction angle for all formations ranges between 38o-40o, which gives a good harmonization with the limestone friction angle. The 3D distribution of the rock's mechanical properties revealed the carbonate heterogeneity because of its marine depositional environment and complex diagenetic processes. The findings of this study can be used for future geomechanical applications in the East Baghdad oil field including wellbore stability analysis, fault reactivation, and CO2 sequestration.

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“…Water saturation has been estimated using Indonesian model in IP software. This model had been derived originally to study water saturation in carbonate reservoir, as it used for calculating effective water saturation in shaly formations that are independent of the shale distribution in the reservoir, so, the overestimation by Archie equation due to the presence of shale is avoided[12].…”

mentioning

confidence: 99%

The Use of Nuclear Magnetic Resonance (NMR) Measurements and Conventional Logs to Predict Permeability for a Complex Carbonate Formation

Alkhayyat

Kadhim

Yousif

2021

Journal of Petroleum Research and Studies

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Permeability is one of the most important property for reservoir characterization, and its prediction has been one of the fundamental challenges specially for a complex formation such as carbonate, due to this complexity, log analysis cannot be accurate enough if it’s not supported by core data, which is critically important for formation evaluation. In this paper, permeability is estimated by making both core and log analysis for five exploration wells of Yammama formation, Nasiriyah oil field. The available well logging recorders were interpreted using Interactive Petrophysics software (IP) which used to determine lithology, and the petrophysical properties. Nuclear Magnetic Resonance (NMR) Measurements is used for laboratory tests, which provide an accurate, porosity and permeability measurements. The results show that the main lithology in the reservoir is limestone, in which average permeability of the potential reservoir units’ values tend to range from 0.064275 in zone YA to 20.74 in zone YB3, and averaged porosity values tend to range from 0.059 in zone YA to 0.155 in zoneYB3. Zone YB3 is found to be the best zone in the Yammama formation according to its good petrophysical properties. The correlation of core-log for permeability and porosity produce an acceptable R^2 equal to 0.618, 0.585 respectively

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Re-evaluation of Petro physical Properties in Yammama Formation at Nasiriya Field

Cited by 4 publications

References 4 publications

Digital Rock Samples Porosity Analysis by OTSU Thresholding Technique Using MATLAB

Digital Rock Samples Porosity Analysis by OTSU Thresholding Technique Using MATLAB

2D and 3D Modeling of Rock Mechanical Properties of Khasib Formation in East Baghdad Oil Field

The Use of Nuclear Magnetic Resonance (NMR) Measurements and Conventional Logs to Predict Permeability for a Complex Carbonate Formation

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