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All Journal Journal of Geoscience, Engineering, Environment, and Technology Petro : Jurnal Ilmiah Teknik Perminyakan
Widi Atmoko
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Earth & Planetary Sciences Economics, Econometrics & Finance Energy Engineering Environmental Science Physics

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EVALUASI PROPERTI RESERVOIR MENGGUNAKAN ANALISIS PETROFISIKA PADA FORMASI GABUS, CEKUNGAN NATUNA BARAT, LAPANGAN “LEUSER” Rian Cahya Rohmana; Al Zam Zam; Widi Atmoko; Mahdani Mahardika Sastra; Rezandy Purnomo Setyo
PETRO:Jurnal Ilmiah Teknik Perminyakan Vol. 11 No. 3 (2022): SEPTEMBER
Publisher : Jurusan Teknik Perminyakan Fakultas Teknologi Kebumian dan Energi Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/petro.v11i`3.15244

Abstract

Formasi Gabus merupakan salah satu formasi dengan litologi batupasir dari Cekungan Natuna Barat yang memiliki prospek hidrokarbon. Penelitian ini berlokasi di Lapangan “Leuser”, Cekungan Natuna Barat. Tujuan penelitian ini adalah mencari zona potensial hidrokarbon baru dan mengevaluasi properti batuan meliputi volume shale, porositas, permeabilitas, dan saturasi air. penelitian ini menggunakan 7 data well log serta didukung oleh data mudlog, analisis core, dan drill stem test. Data tersebut di interpretasi untuk mencari zona potensial hidrokarbon. Setelah itu, dilakukan analisis petrofisika pada setiap sumur untuk mengetahui properti batuan pada zona potensial. Berdasarkan hasil interpretasi, ditemukan 25 zona potensial hidrokarbon di ketujuh sumur penelitian ini, dengan zona potensial terbanyak (7 zona) terdapat di sumur AZZ-5. Berdasarkan hasil analisis petrofisika pada setiap zona potensial yang ditemukan di 7 sumur, didapatkan nilai volume lempung rata – rata berkisar antara 8.52% - 28.32%, nilai porositas efektif rata – rata berkisar antara 12.44% - 21.74%, nilai permeabilitas rata - rata berkisar antara 18.12 mD - 824.64 mD. Klasifikasi nilai porositas efektif yang didapatkan berkisar antara cukup – sangat baik, sedangkan klasifikasi nilai permeabilitas berkisar antara cukup – baik sekali. Untuk melihat kejenuhan fluida pada zona potensial, dilakukan perhitungan saturasi air dan didapatkan nilai saturasi air rata – rata berkisar antara 56.97% - 64.15%. Hasil interpretasi dan analisis pada penelitian ini dapat menjadi dasar untuk terus melakukan eksplorasi, khususnya pada daerah penelitian karena masih terdapat hidrokarbon di dalam batuan yang memiliki properti yang baik, terutama porositas dan permeabilitas.
ANALISIS PENYEBAB RESERVOIR RESISTIVITAS RENDAH PADA LAPISAN BATUPASIR FORMASI TALANG AKAR CEKUNGAN SUNDA ASRI DAN SUMATERA SELATAN Octavia, Dea; Rian Cahya Rohmana; Widi Atmoko
Petro : Jurnal Ilmiah Teknik Perminyakan Vol. 13 No. 2 (2024): Juni 2024
Publisher : Jurusan Teknik Perminyakan Fakultas Teknologi Kebumian dan Energi Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/petro.v13i2.19686

Abstract

This research area is an oil and gas field characterized by low-resistivity zones in the Talang Akar Formation of the Sunda Asri and South Sumatra basins. The formation's lithology comprises sandstone, claystone, shale, and interspersed limestone, all deposited in a shallow marine environment. The objective of conducting petrophysical analysis is to identify the potential of the formation, particularly its low-resistivity reservoirs. The research utilizes well log, core, mud log, petrography, X-ray diffraction (XRD), and biostratigraphy data. Analysis of these data yields Gamma Ray logs, Resistivity logs, and Porosity logs, which include neutron log porosity (NPHI) and density porosity (RHOB). Several factors contribute to the low resistivity of reservoirs in this area, including the presence of clay minerals like kaolinite, chlorite, and illite in the Talang Akar formation, which interfere with low resistivity readings. The occurrence of conductive minerals such as pyrite, biotite, and tourmaline, the high salinity of formation water (>10,000 ppm), classified as High Saline Water, the fine to medium grain size of the sand (0.063 – 0.5 mm) which can retain formation water (irreducible water), leading to low resistivity readings, and the thickness of the rock layers, as evidenced by the depositional environment of the Talang Akar Formation, ranging from the upper delta plains to the lower delta plains, are also influential factors.
The Influence of Pore Porosity on Overpressure Formation: A Case Study of Field X, Kutai Basin Dhiau Rahman Fikri; Abdul Haris; Rinaldo; Widi Atmoko
Journal of Geoscience, Engineering, Environment, and Technology Vol. 10 No. 4 (2025): JGEET Vol 10 No 04 : December (2025)
Publisher : UIR PRESS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25299/jgeet.2025.10.4.22308

Abstract

The Kutai Basin is a region with complex geological characteristics, which complicate formation pressure prediction and pose drilling risks such as overpressure. This study aims to analyze the relationship between porosity and overpressure using well log data, including sonic (DT), resistivity (ILD), neutron porosity (NPHI), and density (RHOB) logs. Overpressure is calculated based on the difference between actual pore pressure and normal hydrostatic pressure, supported by vertical stress estimation. The analysis results indicate that overpressure zones occur within specific intervals, particularly in the Pulau Balang Formation, which is dominated by impermeable shale lithology. These overpressure zones are characterized by high DT values, low ILD readings, and sustained high porosity despite increasing depth. This suggests that the overpressure is caused by undercompaction (Disequilibrium compaction), where rapid sedimentation rates hinder the expulsion of pore fluids. A Dutta crossplot confirms the dominance of smectite minerals that have not yet transformed into illite, reinforcing the indication that the rocks have not undergone significant chemical compaction. The correlation between preserved porosity and overpressure zones provides critical information for mitigating drilling risks and optimizing reservoir development.
Co-Authors Abdul Haris Al Zam Zam Dhea Adisty Pratami Dhiau Rahman Fikri Fiqya Fairuz Zaemi Mahdani Mahardika Sastra Octavia, Dea Rezandy Purnomo Setyo Rian Cahya Rohmana Rian Cahya Rohmana Rinaldo Sarju Winardi Sugeng Sapto Surjono