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All Journal Jurnal Ilmiah MTG Seminar Nasional Teknik Kimia Kejuangan Jurnal Ilmu Kebumian Teknologi Mineral (JIK TekMin) Journal of Geoscience, Engineering, Environment, and Technology Journal of Petroleum and Geothermal Technology Jurnal Offshore: Oil, Production Facilities, and Renewable Energy
Basuki Rahmad
Department Of Geological Engineering, Faculty Of Technology Mineral, Universitas Pembangunan Nasional ”Veteran” Yogyakarta
Biochemistry, Genetics & Molecular Biology Chemical Engineering, Chemistry & Bioengineering Civil Engineering, Building, Construction & Architecture Earth & Planetary Sciences Energy Engineering Environmental Science Mechanical Engineering Physics

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STRUKTUR GEOLOGI DAN SEDIMENTASI BATUBARA FORMASI BERAU Achmad Rodhi; Basuki Rahmad
Jurnal Ilmiah MTG Vol 2, No 1 (2009)
Publisher : Jurusan Teknik Geologi Fakultas Teknologi Mineral UPN "Veteran" Yogyakarta

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Abstract

Perkembangan Sub-Cekungan Batubara Berau selama Tersier di Kalimantan Timur berada di continental plate margin dalam suatu sistem passive margin, berhubungan dengan regangan (rifting) Selat Makasar. Formasi Berau merupakan formasi pembawa batubara di Sub-Cekungan Berau yang berumur Miosen Tengah. Proses pengendapan batubara Formasi Berau di lingkungan delta melalui sisi flexure bidang sesar normal halfgraben berupa sliding gravity.Pengaruh struktur geologi terhadap lapisan batubara baik vertikal maupun lateral secara langsung berpengaruh terhadap ketebalan lapisan batubara, kualitas dan kelayakan penambangannya. Baik dalam skala besar maupun kecil khususnya karakter internal dan eksternal susunan lapisan batubara atau sedimen pengapitnya. Karakter struktur endapan batubara dapat untuk memecahkan permasalahan korelasi stratigrafi, perhitungan cadangan / sumber daya batubara dan sebaran kualitas batubara sebelum dilakukan rancangan penambangan. Pertimbangan struktur geologi tersebut untuk mengetahui pola sebaran batubara dan sejauh mana pengaruh sebaran batubaranya. Tulisan ini disusun selama penulis mengikuti kegiatan eksplorasi di Binungan Blok 1 – 4, dan pengamatan singkapan di Binungan Blok 1 - 4 PIT K, dan Sambarata PIT Gaharu.
Identifikasi Biomarker Fraksi Aromatik Batubara Muara Wahau, Kalimantan Timur 2016 Basuki Rahmad; Komang Anggayana; Sri Widodo; Agus Haris Widayat
Jurnal Ilmu Kebumian Teknologi Mineral (JIK TekMin) Vol 1, No 2 (2015)
Publisher : Fakultas Teknologi Mineral

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Abstract

The research location in Wahau Muara District, East Kutai Regency, East Kalimantan Province. Geological setting of Muara Wahau located in the Kutai Basin Upper included in the Early Miocene Formations Wahau. Coal of Muara Wahau has a unique characteristic that inertinite abundant content with an average value of 20.1% with a low maturity (immature) with Rv (random) 0.40 to 0.44 including lignite rank.Coal samples taken from Seam-1 directly from drill core which drill hole GT-02. Intake of sample done by coring method with the preparation ply by ply based on lithotype appearance. Laboratory analysis of coal samples for organic geochemical analyzes conducted by Soxhlet extraction and then using column chromatography to obtain aromatic fractions.Picene derivatives such as 1,2,4a, 9-tetramethyl-1,2,3,4,4a, 5,6,14b-octahydropicene dominate with the highest concentration of 6509 mg / g TOC than other pentacyclic compounds in the aromatic hydrocarbon fraction Muara Wahau coal.The presence amyrin resulting from microbial degradation or the result of oxidative degradation in tropical climates and several derivatives amyrin typical of Muara Wahau coal one of which is a non-aromatic fraction hopanoid pentacyclic triterpenoids (picene) indicating Angiosperm plant origin. Picene presence implies that the formation of Muara Wahau coal still in the initial transformation during the first stage of diagenesis (early diagenetic) with the maturity level is low (immature). Keywords: picene; amyrin; oxidative degradation; tropis; angiosperm; immature. ABSTRAKLokasi penelitian terletak di Kecamatan Muara Wahau, Kabupaten Kutai Timur, Propinsi Kalimantan Timur. Tatanan geologi daerah Muara Wahau berada di Cekungan Kutai Bagian Atas termasuk dalam Formasi Wahau berumur Miosen Awal. Batubara Muara Wahau memiliki keunikan yang khas yaitu kandungan inertinite yang berlimpah  dengan nilai rata-rata 20,1% dengan kematangan yang rendah (immature) dengan Rv (random) 0,40-0,44 termasuk peringkat lignite.Conto batubara diambil dari Seam-1 langsung dari inti bor yaitu lubang bor GT-02.  Pengambilan conto dilakukan dengan metode coring dengan preparasi ply by ply berdasarkan kenampakan lithotype. Analisa laboratorium conto batubara untuk analisis geokimia organik dilakukan dengan cara ekstraksi soxhlet kemudian menggunakan column chromatography untuk memperoleh fraksi aromatik.Turunan picene seperti 1,2,4a,9-tetramethyl-1,2,3,4,4a,5,6,14b-octahydropicene mendominasi dengan konsentrasi paling tinggi 6509 µg/g TOC dibanding senyawa-senyawa pentasiklik lainnya dalam fraksi hidrokarbon aromatik batubara Muara Wahau.Kehadiran amyrin yang dihasilkan dari microbial degradation atau akibat dari oxidative degradation di iklim tropis dan beberapa turunan amyrin yang khas dari batubara Muara Wahau salah satunya adalah fraksi aromatik non-hopanoid pentacyclic triterpenoid (picene) yang mengindikasikan tumbuhan asal angiosperm. Kehadiran picene mengimplikasikan bahwa pembentukan batubara Muara Wahau masih dalam transformasi awal selama tahap pertama diagenesis (early diagenetic) dengan tingkat kematangan yang masih rendah (immature). Kata kunci: picene; amyrin; oxidative degradation; tropis; angiosperm; immature.
Coal Gasification and Coal Microscopic Characteristics in Tanjung Baru, Lahat Regency, South Sumatera Basuki Rahmad; Sugeng Raharjo; Ediyanto Ediyanto; Gerhana Prasetya Putra
Prosiding Seminar Nasional Teknik Kimia "Kejuangan" 2020: PROSIDING SNTKK 2020
Publisher : Seminar Nasional Teknik Kimia "Kejuangan"

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The location of research is located in the Tanjung Baru Area, Lahat Regency, South Sumatera. The Geological setting of the Tanjung Baru Area in the South Sumatra Basin is included in the Muara Enim Formation the age is Middle Miocene to Late Miocene. Coal in the Tanjung Baru Area, has a calorific value of 5089-5321 Kcal / kg and is rank High in Bituminous Volatile C-High Volatile Bituminous B according to the ASTM classification. Average quality (proximate test) of Muara Enim Formation coal: total sulphur 0.36-1.49% (adb); 1.28-2,5% ash (adb); inherent moisture 9-11% (adb); volatile matter 38.7-42.4% (adb); fixed carbon 45.5-47.9% (adb), total moisture 28.1-28.8% (Ar); relative density 1.28. Coal Charactersitics of Coal Tanjung Baru  the macerals average are vitrinite (92,4% vol.); liptinite (2.9% vol.); inertinite (5,7% vol.). Each macerals or group macerals has different physical and chemical properties. The variation of composition microscopy showed the changes of plant communities or coal facies leading to varies of coal quality, with a average vitrinite reflectance value 0.47-0.58, generally the coal rank is subbituminous-bituminous. Coal gasification is the process of converting coal into synthesis gas. One of the gas produced is a flammable methane gas. Gasification is raw fuel, in this case coal is partially oxidized to produce a product called combustible gas. The main product from the gasification product is synthesis gas or syngas, consisting of Carbon Monoxide (CO), Hydrogen (H2), Methane (CH4), Carbon Dioxide (CO2) and Nitrogen (N2).
Application of Fracture Barrier Analysis in Well Stimulation Planning for Upper Baturaja Limestone Formation Based on Well Log & Drill Cutting Data from OBF-01 and OBF-04 Wells, Offshore Southeast Sumatra Aris Buntoro; Muhammad Nurcholis; Basuki Rahmad; Allen Haryanto Lukmana; Ristiyan Ragil Putradianto
Journal of Petroleum and Geothermal Technology Vol 1, No 2 (2020): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v1i2.3686

Abstract

In general, the South Sumatra Regional Stratigraphy of the Baturaja Limestone Formation facies is deposited on the Buildup Carbonate (Reef) and the Limestone Clastic Carbonate of the Baturaja Formation which grows as a buildup reef on the platform in the Basement High (Horst) underneath is the Lemat Formation volcanic deposits. Referring to the facies model in general, the Baturaja Limestone Formation, the depositional environment starts from Shelf Lagoon Open Circulation - Winnowed Edge Sand - Organic Buildup - Fore Slope - Deep Shelf Margin - Open Sea Shelf - Basin, meaning that carbonate is formed starting from pure organic Cabonate Buildup Reef without / a little sludge / mud to the Carbonate Basin where more muddy / mud is present, this condition causes clay minerals to also more and more mix with Terigenous Clastics (Quartz, feldpar). The complexity of the Baturaja Limestone Formation requires fracture barrier analysis associated with well stimulation planning in order to increase oil productivity with the appropriate method.   Fracture barrier fracture analysis is an approach method to determine the depth interval that becomes a barrier in hydraulic fracturing by correlating the results of geomechanical analysis from well log data and mineralogical analysis from drill cuttings data, so that a commonly used well stimulation method can be selected, namely hydraulic fracturing, acidizing, and acid-fracturing.From the ternary diagram plot the XRD (bulk) analysis results show that the distribution of the main minerals (Quartz, Clay, Calcite) is more dominant in the ductile zone, hard to frac category. This shows that all the depth intervals in the OBF-01 and OBF-04 wells are more ductile, and are not recommended for hydraulic fracturing. From the XRD (bulk) analysis, Calcite mineral is more dominant, so for well stimulation work it is recommended to use acidizing or acid-fracturing.
Rencana Pengembangan Lapangan Gas Metana Batubara Dangkal (Shallow CBM) di Daerah Ida Manggala, Rantau, Kabupaten Hulu Sungai Selatan Kalimantan Selatan Basuki Rahmad; Sugeng Raharjo; Eko Widi Pramudiohadi; Ediyanto Ediyanto
Jurnal Offshore: Oil, Production Facilities and Renewable Energy Vol 2, No 1 (2018): Jurnal Offshore : Oil, Production Facilities and Renewable Energy
Publisher : Proklamasi 45 University

Show Abstract | Download Original | Original Source | Check in Google Scholar | Full PDF (1058.585 KB) | DOI: 10.30588/jo.v2i1.351

Abstract

Potensi kandungan gas batubara (Gas Content) Idamanggala, Rantau, Kalimantan Selatan berkisar 6,72 m3/ton. Sumberdaya gas batubara (Gas in Place/GIP) Rantau, Kalimantan Selatan 0,002 tcf (saturasi gas 90%), kisaran kedalaman 50-150 meter. Gas Metana Batubara (GMB) diproduksi dengan cara terlebih dahulu merekayasa batubara sebagai reservoir agar diperoleh cukup ruang sebagai jalan keluarnya gas metana. Proses rekayasa diawali dengan memproduksi air (dewatering) agar terjadi perubahan keseimbangan mekanika. Setelah tekanan turun, gas batubara akan keluar dari matrik batubara. Gas metana kemudian mengalir melalui rekahan batubara dan akhirnya keluar menuju lubang sumur. Puncak produksi Gas Metana Batubara (GMB) bervariasi antara dua minggu sampai dengan tiga tahun. Rencana pengembangan lapangan dimulai dari tiga tahun pertama dengan melakukan lima sumur pilot (pilot well). Pemboran pilot dilakukan untuk mengenal dimensi seam dan kualitasnya, baik secara lateral maupun vertikal. Apabila regulasi pemerintah sesuai  dan memungkinkan untuk memulai pengembangan, maka pengembangan sumur produksi dapat dimulai pada tahun 2021. Pengembangan Lapangan Gas Batubara Daerah Rantau Kalimantan Selatan diprioritaskan untuk kebutuhan pasar lokal yaitu kebutuhan tenaga listrik setempat baik industri maupun rumah tangga dan jika memungkinan dapat dialirkan melalui pipa untuk perusahaan gas negara.Coal gas content potential  (Gas Content) Idamanggala, Rantau, South Kalimantan is around 6.72 m3/ton. Rantau coal gas resources (Gas in Place/GIP), South Kalimantan 0.002 tcf (90% gas saturation), range of depths from 50-150 meters. Coal Methane Gas (GMB) is produced by first engineering coal as a reservoir in order to obtain enough space as a way out of methane gas. The engineering process begins with producing water (dewatering) so that there is a change in mechanical balance. After the pressure drops, coal gas will come out of the coal matrix. Methane gas then flows through the coal fractures and finally exits into the wellbore. The peak production of Coal Methane Gas (GMB) varies between two weeks to three years. The field development plan starts from the first three years by conducting five pilot wells. Pilot drilling is carried out to recognize the dimensions of seam and its quality, both laterally and vertically. If government regulations are appropriate and allow to start development, the development of production wells can begin in 2021. The development of the South Kalimantan Overseas Coal Coal Field Development is prioritized for the needs of the local market, namely the needs of local electricity both industrial and household and if possible can be channeled through pipes for the state gas company.
Potensi Batuan Induk Hidrokarbon Serpih Gumai di Talang Padang, Kabupaten Tanggamus Propinsi Lampung Listriyanto Listriyanto; Sugeng Widada; Basuki Rahmad; Salatun Said; Hendaryono Hendaryono
Jurnal Offshore: Oil, Production Facilities and Renewable Energy Vol 1, No 1 (2017): Jurnal Offshore : Oil, Production Facilities and Renewable Energy
Publisher : Proklamasi 45 University

Show Abstract | Download Original | Original Source | Check in Google Scholar | Full PDF (883.38 KB) | DOI: 10.30588/jo.v1i1.237

Abstract

Identifikasi interval batuan yang mungkin berpotensi sebagai batuan induk merupakan langkah awal eksplorasi yang penting, oleh sebab itu perlu dilakukan penelitian tentang potensi batuan sedimen yang mengandung bahan organik dengan kadar tertentu, yang oleh panas dan waktu dapat menghasilkan hidrokarbon dalam bentuk minyak atau gas secara tepat. Penelitian ini bertujuan untuk mengidentifikasi fasies dan potensi batuan induk hidrokarbon Formasi Gumai di Talang Padang, Cekungan Sumatra Selatan. Analisis geokimia guna mengetahui potensi dan kualitas batuan induk dilakukan pada serpih penyusun Formasi Gumai. Hasil analisis potensi dan kualitas Batuan Induk menunjukkan kandungan TOC 3,55 termasuk “sangat baik”. Rock-Eval menunjukkan bahwa serpih berpotensi “sedang” sebagai batuan induk hidrokarbon (S2 = 4,32 kg/ton). Angka Ro (<0,6) menunjukkan tingkat pematangan hidrokarbon belum tercapai. Nilai HI yang relatif tinggi mencerminkan bahwa batuan ini jika mencapai kematangan akan cenderung menghasilkan minyak. Nilai HI antara 456 mgHC/g umumnya berasal dari kerogen tipe II yang secara dominan mengandung unsur organisme laut dan darat.Rock Identification intervals that might be as potential source rocks is an important initial exploration step, therefore it is necessary to conduct research on the potential of sedimentary rocks containing certain levels of organic material, which by heat and time can produce hydrocarbons in the form of oil or gas appropriately. This study aims to identify the facies and potentials of the Gumai Formation hydrocarbon source rock in Talang Padang, South Sumatra Basin. Geochemical analysis to determine the potential and quality of the source rock is carried out on the Gumai Formation shale. The results of the analysis of the potential and quality of the Parent Rock showed that the TOC content of 3.55 was "very good". Rock-Eval shows that shale has the potential to be "medium" as a hydrocarbon source rock (S2 = 4.32 kg/ton). Ro (<0.6) indicates the level of hydrocarbon maturation has not been reached. The relatively high HI value reflects that if these rocks reach maturity they will tend to produce oil. HI values between 456 mgHC/g are generally derived from type II kerogen which predominantly contains marine and terrestrial organisms.
The Role of Fractal Micro-Pore to Absorption of Methane Gas, Case Study: Coal of Tanjung Formation, Arang Alus Area, Banjar District, South Kalimantan, Indonesia Sugeng Raharjo; Basuki Rahmad; Ketut Gunawan; Budi Prayitno
Journal of Geoscience, Engineering, Environment, and Technology Vol. 7 No. 4 (2022): JGEET Vol 07 No 04 : December (2022)
Publisher : UIR PRESS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25299/jgeet.2022.7.4.10565

Abstract

The Tanjung Formation is one of the coal bearing formations in the Barito Basin, South Kalimantan. The coal seams in the Tanjung Formation in the Arang Alus area have 4 (four) seams,there are seam A, B, C, and D. The age of these coal seams are Eocene - Oligocene with a thickness between 0.5 - 2 meters. This study aims to determine the characteristics of micropore fractal and methane gas absorption from coal samples taken by channel sampling on exposed coal in the open pit. The method used is SEM analysis, vitrinite reflectance (Ro,max), adsorption isotherm, and fractal calculation. The four coal seams based on vitrinite reflectance values (0.52 %- 0.62 belong to the sub-bituminous rank. Based on the methane gas absorption capacity for coal seam C of 450 SCF/ton while coal seams A, B and D of 308 SCF/ton, 336 SCF/ton and 407 SCF/ton, the fractal pore dimension value in seam coal C = 1.963 is higher than seam coal A = 1.933, B = 1.940 , and D = 1.943. The small size of the fractal pore dimension value caused by the degree of regularity of the micropore distribution in each coal seam methane differences.
Co-Authors Achmad Rodhi Agus Haris Widayat Allen Haryanto Lukmana Aris Buntoro Budi Prayitno Ediyanto Ediyanto Ediyanto Ediyanto Eko Widi Pramudiohadi Gerhana Prasetya Putra Hendaryono Hendaryono Ketut Gunawan Komang Anggayana Listriyanto Listriyanto Muhammad Nurcholis Ristiyan Ragil Putradianto Salatun Said Sri Widodo Sugeng Raharjo Sugeng Raharjo Sugeng Raharjo Sugeng Widada