Effect of Porosity on Rock Brittleness

Heidari, Mojtaba; Khanlari, Gholamreza; Torabi-Kaveh, Mehdi; Kargarian, S.; Saneie, S.

doi:10.1007/s00603-013-0400-0

Cited by 73 publications

(22 citation statements)

References 17 publications

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“…The tested granite gneiss has a compact structure with a mean porosity of 1.79 % and an initial density of 2.61 g cm -3 . Compared with sedimentary rocks such as sandstone (Heidari et al 2014), carbonate rocks (Walton et al 2014) and chalk (Megawati et al 2013), granite gneiss is a low-porosity rock. Moreover, the strength of the granite gneiss is high.…”

Section: Materials Characterizationmentioning

confidence: 99%

Permeability Evolution of Granite Gneiss During Triaxial Creep Tests

Liu

Wang

et al. 2016

Rock Mech Rock Eng

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Permeability is an important factor for seepage analysis of rock material, and a key factor in ensuring the safety of underground works. In this study, the permeability evolution of granite gneiss during triaxial creep tests was investigated. In the context of an underground oil storage cavern in China, a series of hydro-mechanical coupling creep tests were conducted on rock cores of granite gneiss at three different pore pressures to reveal the effect of pore pressure on the permeability evolution and to investigate the correlation between the permeability and volumetric strain during the creep process. During the creep tests, the permeability decreases in the initial loading phase. At all deviatoric stress levels, the permeability remains stable in the steady creep stage and increases rapidly in the accelerated creep stage. Based on the test data, the initial permeability, steady permeability and peak permeability at various stress levels are defined. The effect of pore pressure on the permeability is captured by a linear model. In addition, the relationship between permeability and volumetric strain can be described as a process divided into three phases, with different functions in each phase.

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Section: Materials Characterizationmentioning

confidence: 99%

Permeability Evolution of Granite Gneiss During Triaxial Creep Tests

Liu

Wang

et al. 2016

Rock Mech Rock Eng

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“…Hal ini dikarenakan shale volume diperoleh dari kelimpahan mineral clay didalam batuan yang mana semakin banyak mineral clay tersebut maka akan semakin tinggi shale volume-nya, ini kemudian akan membuat batuan tersebut semakin halus. Batuan yang lebih halus memiliki strain yang lebih tinggi untuk dapat mencapai failure dan dapat menyebabkan batuan berada diatas elastic limit-nya sehingga berakibat berkurangnya brittleness pada batuan tersebut (Heidari et al, 2013) [4]. Pada porositas total dan efektif dengan BI memiliki hubungan yang berbandung terbalik dimana semakin tinggi porositas maka nilai BI akan semakin rendah.…”

Section: Latar Belakangunclassified

Petrofisika Untuk Organic Shale, Cekungan Kutai Bagian Atas, Formasi Batu Ayau

et al. 2019

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Menipisnya jumlah cadangan minyak dan gas bumi konvensional menjadi landasan atas studi sumberdaya migas non-konvensional, salah satunya adalah organic shale sebagai alternatif untuk memenuhi kebutuhan energi fosil yang masih sangat tinggi di Indonesia. Cekungan Kutai Bagian Atas merupakan salah satu cekungan yang cukup tua dan satu dekade terakhir dilirik sebagai target organic shale. Formasi Batu Ayau yang berada di Cekungan Kutai Bagian Atas merupakan target utama sebagai potensi sumber daya organic shale dibuktikan dengan hasil analisa geokimia serta perannya sebagai batuan induk dalam sistem petroleum konvensional di Cekungan Kutai Bagian Atas. Interval organic shale dari Formasi Batu Ayau berada pada asosiasi fasies delta plain dan delta front dengan terdapat dua interval prospek didalamnya (BA3 & BA2). Analisa dilakukan menggunakan data dua sumur MAAU-1 dan TENGKAWANG-1 di Blok B Cekungan Kutai Bagian Atas. Analisa petrofisika secara umum untuk memperoleh nilai shale volume sebesar 50 − 60 %, porositas 8 − 30%, dan water saturation 60 − 70 %, hal ini kemudian diterapkan untuk identifikasi organic shale dengan mengoptimalkan penggunaan dari standard triple combo log. Pada organic shale petrofisika dilakukan untuk memperoleh hasil akhir besaran nilai TOC dan Brittleness Index (BI). Nilai TOC diperoleh dengan menggunakan metode Passey dengan diperoleh nilai 0.7 − 3.2 wt% dan nilai BI menggunakan metode Anderson yang diperoleh nilai 51 − 58 %. Dengan analisa tersebut diharapkan agar diperoleh hasil representatif dari kualitas organic shale berdasarkan metode petrofisika di Formasi Batu Ayau. AbstractAs the oil and gas conventional reserves are thinning thus becoming the stand reason for the study of non conventional hydrocarbons, one of them is organic shale as an alternative to fill the needs of fossil energy which still in high demands in Indonesia. Upper Kutai Basin is one of the oldest basin and in the last decade being proposed as organic shale target. Batu Ayau Formation located within this basin is the main target as organic shale resource which proven by geochemical analysis from laboratories and it is role as source rocks in conventional petroleum system in Upper Kutai Basin. Batu Ayau Formation interval of organic shale exist in facies association of delta plain and delta front with two prospect interval within (BA3 & BA2). Analysis using wells MAAU-1 and TENGKAWANG-1 in block B of Upper Kutai Basin. Petrophysical analysis normally being used to obtain the value of shale volume which 50 − 60 %, porosity which 8 − 30 %, and water saturation which 60 − 70 %, and then applied to identify the organic shale with optimizing the use of standart triple combo log. In organic shale the petrophysics is used to obtain final results of Total Organic Carbon (TOC) and Brittleness Index (BI). TOC value analyzed using Passey's with value achieves 0.7 − 3.2 wt% and BI using Anderson's with value achieves 51 − 58 %. From the analysis so hopefully can achieves a representative results of organic shale in Batu Ayau Forma...

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“…The results were more promising for predicted brittleness than only using neutron porosity. Previous study indicates some good relationships between mineralogical brittleness and the ratio of gamma rays to the photoelectric absorption cross section index, porosity, compressional slowness et al (Heidari et al, 2014;Lai et al, 2015). But these relationships are derived from local data whereas these empirical relationships are random and virtually non-existent in the other shales.…”

Section: Introductionmentioning

confidence: 96%