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All Journal IJOG : Indonesian Journal on Geoscience Jurnal Geologi dan Sumberdaya Mineral
Hermes Panggabean
Pusat Survei Geologi, Badan Geologi Jl. Diponegoro 57 Bandung
Earth & Planetary Sciences Education Energy Engineering Environmental Science

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An appraisal for the petroleum source rocks on oil seep and rock samples of the Tertiary Seblat and Lemau Formations, Bengkulu Basin Panggabean, Hermes; Heryanto, R.
Indonesian Journal on Geoscience Vol 4, No 1 (2009)
Publisher : Geological Agency

Show Abstract | Download Original | Original Source | Check in Google Scholar | Full PDF (951.237 KB) | DOI: 10.17014/ijog.v4i1.69

Abstract

http://dx.doi.org/10.17014/ijog.vol4no1.20095The Tertiary Bengkulu Basin is known as a typical fore-arc basin, situated in southwest Sumatera. The basin initiated during Eocene-Oligocene times, accumulates the Lahat equivalent formation. The formation is is unconformably overlain by the Oligocene-Miocene Hulusimpang Formation consisting of volcanic rocks. It is then succeeded by siliciclastics and minor carbonates of the Early-Middle Miocene of Seblat Formation. Unconformably overlying the Seblat is siliciclastics of the Middle-Late Miocene Lemau Formation, then overlain by the Late Mio-Pliocene Simpangaur Formation. The basin succession is terminated by the sequence of volcanic rocks named as the Bintunan or Ranau Formation. Geochemistry analyses (i.e. TOC, Rock-Eval and Gas Chromatography-Mass Spectrometry) conducted on selected outcrop and sub-crop samples, and one oil seep sample collected during field work, have given an appraisal to identify the nature of petroleum source rocks within the basin. The result of organic geochemistry and also organic petrology analyses indicates that potential source rocks may occurred in the stratigraphic succession of the basin. The Lahat equivalent formation, Seblat, and Lemau Formations may play an important role to generate oil within the Bengkulu Basin.  
Karakteristik Batubara dan Batuan Sedimen Pembawanya, Formasi Talangakar, di daerah Lampung Tengah Kusnama, Kusnama; Panggabean, Hermes
Indonesian Journal on Geoscience Vol 4, No 2 (2009)
Publisher : Geological Agency

Show Abstract | Download Original | Original Source | Check in Google Scholar | Full PDF (901.357 KB) | DOI: 10.17014/ijog.v4i2.75

Abstract

http://dx.doi.org/10.17014/ijog.vol4no2.20095The rock succession of coal bearing formation, situated in Lampung Tengah, occupies the basinal margin or the western part of South Sumatra Basin. Physiographically, the rock succession lies in the Palembang Zone which directly contacts with the southernmost Barisan Mountain Zone. The rock facies consists of conglomerate, and conglomeratic and quartz sandstones in the lower part, whilst the upper part comprises shale, claystone, mudstone, siltstone, and coal with coally shale and shaly coal intercalations. The rock facies of coal bearing unit is strongly believed to be part of the Oligo - Miocene Talangakar Formation deposited in a fluvial – paralic environment which further up section, it turns to be a sub-littoral deposit. The depositional environment strongly affected the coal characteristics and type. Stratigraphically, the rock unit is conformably overlain by the Early - Middle Miocene limestone unit and is intruded by the Middle – Late Miocene granodiorite. The basement of the Tertiary rock succession is metamorphics of the Gunungkasih Complex and the Cretaceous granitic rock. The normal fault controlling the area studied has a northwest - southeast direction and it caused the dip of coal trending north - east direction of 15º - 23º. The coal of the research area was deposited in wet forest swamp environment within a high to medium subsidence level. The coal is grouped to a high to low volatile bituminuous rank, included to a mature category.    
Hydrocarbon Source Rock Potential of the Sinamar Formation, Muara Bungo, Jambi Zajuli, Moh. Heri Hermiyanto; Panggabean, Hermes
Indonesian Journal on Geoscience Vol 1, No 1 (2014)
Publisher : Geological Agency

Show Abstract | Download Original | Original Source | Check in Google Scholar | Full PDF (690.87 KB) | DOI: 10.17014/ijog.v1i1.175

Abstract

DOI: 10.17014/ijog.v1i1.175The Oligocene Sinamar Formation consists of shale, claystone, mudstone, sandstone, conglomeratic sandstone, and intercalation of coal seams. The objective of study was to identify the hydrocarbon source rock potential of the Sinamar Formation based on geochemichal characteristics. The analyses were focused on fine sediments of the Sinamar Formation comprising shale, claystone, and mudstone. Primary data collected from the Sinamar Formation well and outcrops were analyzed according to TOC, pyrolisis analysis, and gas chromatography - mass spectometry of normal alkanes that include isoprenoids and sterane. The TOC value indicates a very well category. Based on TOC versus Pyrolysis Yields (PY) diagram, the shales of Sinamar Formation are included into oil prone source rock potential with good to excellent categories. Fine sediments of the Sinamar Formation tend to produce oil and gas originated from kerogen types I and III. The shales tend to generate oil than claystone and mudstone and therefore they are included into a potential source rock. 
The Potential of Ketungau and Silat Shales in Ketungau and Melawi Basins, West Kalimantan: For Oil Shale and Shale Gas Exploration Santy, Lauti Dwita; Panggabean, Hermes
Indonesian Journal on Geoscience Vol 8, No 1 (2013)
Publisher : Geological Agency

Show Abstract | Download Original | Original Source | Check in Google Scholar | Full PDF (1087.509 KB) | DOI: 10.17014/ijog.v8i1.154

Abstract

DOI: 10.17014/ijog.v8i1.154The Ketungau and Melawi Basins, in West Kalimantan, are Tertiary intramontane basins of which the potential for economic conventional oil and gas discoveries have not previously been confirmed. The Ketungau Basin is bordered by the Melawi Basin in the south. Besides non-ideal trapping mechanisms, another major problem in these basins is source rock maturation. Nevertheless, both basins are promising to be explored for oil shale and shale gas energy resources. Therefore, the aim of this paper is to give some perspectives on their source rocks, as an input for the evaluation of the potential of unconventional oil and gas. About twenty samples collected from the Ketungau and Melawi Basins were analyzed using pyrolysis and organic petrographic methods. The results show a poor to good quality of source rock potential. The Ketungau shale, which is the main source rock in the Ketungau Basin, is dominated by type III, immature, and gas prone kerogen. The Silat shale, which is the main source rock in the Melawi Basin, is dominated by type II, immature to early mature, mixed gas, and oil prone kerogen. In the field, Ketungau and Silat Formations have a widespread distribution, and are typically 900 m to 1000 m thick. Both the Ketungau and Silat shales occur within synclinal structures, which have a poor trapping mechanism for conventional oil or gas targets, but are suitable for oil shale and shale gas exploration. This early stage of research clearly shows good potential for the future development of unconventional energy within the Ketungau and Melawi Basins.
DEPOSITIONAL ENVIRONMENT OF THE SAROLANGUN COALS, SOUTH SUMATRA BASIN Permana, Asep Kurnia; Panggabean, Hermes
Jurnal Geologi dan Sumberdaya Mineral Vol 21, No 4 (2011): Jurnal Sumber Daya Geologi
Publisher : Pusat Survei Geologi

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Abstract

The Muaraenim Formation, a Late Miocene unit within the South Sumatera Basin, is included in some of the most significant coal resources in Indonesia. The upper part of the unit exposed in the Sarolangun Region, where it consists mainly of sandstone and shale, with relatively thin (< 1.5 m) coal beds. Lithofacies analysis of the outcropping strata indicates that deposition took place in a terrestrial to marine environment. Microscopic analysis shows that the coal consists mainly of vitrinite maceral group (telovitrinite and detrovitrinite), with having a rare to sparse inertinite and minor liptinite and mineral matter. Palynological studies show abundant pollens, derived from mangrove vegetation that grew in a fresh water environment. The GI and TPI values, calculated from detailed maceral analysis, when plotted on similar diagrams to those developed by Diessel (1992) show the coals to have two different facies characteristics. Some of the coals, especially those having a high vitrinite content, show high TPI and relatively high GI values, suggesting that deposition was in upper delta plain and fluvial environments (wet forest swamp) with a relatively high rate of subsidence. Other coals have much lower TPI but higher GI values, indicating that peat was possibly developed in in a lower delta plain, with relatively slow subsidence conditions. Some coal samples also have high proportions of pyrite and other mineral matter, and thus it might have been deposited in more brackish environments. The change reflects the onset of marine transgression near the top of the Muara Enim sequence. Palynological analysis indicates the occurrence of fresh water and mangrove vegetation, supporting deposition in wet and possibly partly brackish conditions.Keywords: Depositional environment, Sarolangun coals, South Sumatera Basin, Indonesia
KARAKTERISTIK MINERAL LEMPUNG PADA SEDIMEN RESEN PERMUKAAN DASAR LAUT DI PERAIRAN KOTA SEMARANG Budiono, K.; Panggabean, Hermes
Jurnal Geologi dan Sumberdaya Mineral Vol 18, No 4 (2008): Jurnal Sumber Daya Geologi
Publisher : Pusat Survei Geologi

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Abstract

Clay mineral is a group of mineral which suplay more than 16% of sediments distribution in the earth surface. The clay mineral can be occurred both on the land and sea bottom. The clay mineral which is deposited in the coastal and sea bottom have a unique mechanism, and consequently creates many kind of clay mineral where this conditions is influenced by the deph, temperature, light, topography and organism.The study of clay mineral distribution in the coastal and  marine sediments enables to analysis the sedimentation processes, where the occurrence of this mineral is influenced by the origin of the sediments. Generally, the surficial sediments of Semarang offshore is consists of clay and silt.Based on the SEM analysis the clay mineral in Semarang offshore is dominated by caolinite, illite and mixed layer of montmorilonite and illite.Keywords: offshore surficial sediments, clay mineral, sedimentation process
Hubungan Kelompok Maseral Liptinit dan Vitrinit dengan Tipe Kerogen Batuan Sumber Hidrokarbon pada Serpih Formasi Kelesa Bagian Atas, Kuburan Panjang, Riau Zajuli, Moh. Heri Hermiyanto; Panggabean, Hermes; Hendarmawan, Hendarmawan; Syafri, Ildrem
Jurnal Geologi dan Sumberdaya Mineral Vol 18, No 1 (2017): Jurnal Geologi dan Sumberdaya Mineral
Publisher : Pusat Survei Geologi

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Abstract

This study focuses on correlation of liptinite and vitrinite maceral to kerogen type of shale from Kelesa Formation in Kuburan Panjang areas, Sumai sub-basin, Central Sumatra Basin. The composition of the organic material consists of vitrinite maceral ranged from 0.2 to 5%, liptinite from 0.6 to 4.7%, the type of minerals in the form of pyrite from 0.2 to 16%, and 0.2 -24.2% of carbonate, as well as clay minerals are the most dominant component ranged between 71.6 -98%. TOC values of the shale range from 1.18% to 7.17%, which indicate ability of the shale as a good source rock. Kerogen type analysis of theshale in the research area tends to indicate I, II and III kerogen types. There is an influence of the liptinite and vitrinite maceral groups abundance to the type of kerogen, where liptinit maceral group tends to produce type I and II kerogen. Key word : Kelesa Formation, Eocene-Oligocene, Central Sumatera Basin, Vitrinite, Liptinite
Geokimia Batuan Gunungapi di Pulau Timor Bagian Barat dan Impikasi Tektoniknya Wahyudiono, Joko; Safri, Ildrem; Panggabean, Hermes
Jurnal Geologi dan Sumberdaya Mineral Vol 17, No 4 (2016): Jurnal Geologi dan Sumberdaya Mineral
Publisher : Pusat Survei Geologi

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Abstract

Geologi wilayah Timor bagian barat berasal dari tiga mintakat yaitu Mintakat Benua Australia, Mintakat Busur Banda dan batuan yang terendapkan setempat. Pengambilan dan analisis conto batuan di Sungai Fatu dan Kompleks Mutis serta tambahan data sekunder dari Sungai Metan, Pulau Atauro dan batuan hasil Deep Sea Drilling Project (DSDP) bertujuan untuk mengetahui batuan asal wilayah Timor berdasarkan data geokimia batuan gunungapi dan implikasi tektoniknya. Metodologi analisis geokimia yang digunakan adalah X-ray fluorescence (XRF) dan Inductively Coupled Plasma–Mass Spectrometry (ICP-MS) untuk mengetahui unsur utama, unsur jejak dan unsur tanah langka dari batuan gunungapi. Unsur-unsur ini digunakan untuk klasifikasi batuan dan lingkungan tektoniknya.Hasil analisis geokimia conto batuan gunungapi dari Sungai Fatu dan DSDP berasal dari Benua Australia, sementara conto batuan dari Kompleks Mutis dan Sungai Metan menunjukkan Benua Asia atau Busur Banda seperti pada Pulau Atauro. Batuan basal dari Sungai Fatu terendapkan menjemari dengan batugamping Formasi Maubise berumur Perem dan merupakan Oceanic Island Basalt. Batuan basal dari Deep Sea Drilling Project (DSDP) secara geokimia termasuk subalkalin yang berasal dari pematang tengah samudera (Normal Mid Oceanic Ridge Basalt) berumur Jura.Kompleks Mutis pada Oligosen Miosen mengawali kolisi antara Benua Asia dengan Benua Australia. Batuan metabasal Kompleks Mutis menunjukkan komposisi kalk-alkalin yang mencirikan busur kepulauan. Conto batuan dari Sungai Metan dan Pulau Atauro terutama menunjukkan komposisinya subalkaline. Puncak kegiatan kolisi terjadi pada Akhir Miosen – Awal Pliosen dan berlanjut hingga sekarang. Busur Banda bagian dalam sebagian gunungapinya sudah tidak aktif lagi seperti yang terjadi pada Pulau Atauro.Kata kunci : geokimia, batuan gunungapi, mintakat, tektonik, kolisi, Timor
Karakteristik dan Diagenesis beberapa Percontoh Batuan Oil Shale Formasi Kasiro Terpilih, di Jambi dan Sumatera Selatan berdasarkan Scanning Electron Microscope (SEM) Hermiyanto, Mohammad Heri; Panggabean, Hermes
Jurnal Geologi dan Sumberdaya Mineral Vol 16, No 6 (2006): Jurnal Sumber Daya Geologi
Publisher : Pusat Survei Geologi

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Abstract

Oil shale, as one of alternative energy resources, is recognized in the Late Eosen - Oligocene Kasiro Formation, located in the Rawas Ulu and Batang Asai areas. Based on SEM analysis, the shale  consists of smektite-illite, illite,  kaolinite, organic matter as liptinite (sporinite,and alginite) and contains oil droplet.The oil shale is composed of smectite-illite and illite characterised by wavy parallel fissile,while kaolinite clays show irregular shape characters. The shale has undergone a diagenetic process within an early mesodiagenetic level. Organic matter maturity level of the oil shale, in general, is the immature up to early mature. Keywords : oil shale,clay minerals,smectite-illite,  organic matter
SEJARAH PENIMBUNAN CEKUNGAN SUMATERA SELATAN DAN IMPLIKASINYA TERHADAP WAKTU GENERASI HIDROKARBON Panggabean, Hermes; Santy, Lauti Dwita
Jurnal Geologi dan Sumberdaya Mineral Vol 22, No 4 (2012): Jurnal Sumber Daya Geologi
Publisher : Pusat Survei Geologi

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Abstract

South Sumatra Basin is divided into four subbasins, that are Jambi Subbasin, Central Palembang Subbasin, North Palembang Subbasin, and South Palembang Subbasin. Clastic and carbonate sediments had filled the South Sumatra Basin during Eocene up to Quaternary times by various thickness of all rock units in each subbasin ranging from 2100 m to 3500 m. Those four subbasins have shown almost different maximum deep of burial history, that was started from 2900 m up to 5200 m. From burial of maximum depth by over 2000 m, several rock outcrop samples of the Talangakar Formation have evidently compacted, and grain particles as well as minerals of matrix have been proccessed by diagenesis realm. The lowest depth oil generation of the Lahat Formation is 1560 m in the Central Palembang Subbasin, while the deepest in the Talangakar Formation is 2700 in Jambi Subbasin and 2800 m in the South Palembang Subbasin. The timing of hydrocarbon generation has occurred between 20.6 mya (Early Miocene) and 3.38 mya (Late Pliocene). By studying detailed characters of sedimentary rocks filling each subbasin, thus the time of hydrocarbon generation can be known.Keyword : South Sumatra basin, burial history, hydrocarbon generation, Lahat Formation, and Talangakar Formation
Co-Authors Ali Djamhuri Asep Kurnia Permana B.Sendjadja, Yoga David Victor Mamengko Edi Slameto, Edi Eko Budi Lelono, Eko Budi Fauzely, Lili Hendarmawan Hendarmawan, Hendarmawan Heri Hermiyanto Zajuli, Heri Hermiyanto Ildrem Safri, Ildrem Ildrem Syafri Imam Setiadi, Imam Iyan Haryanto, Iyan Joko Wahyudiono K. Budiono Kusnama Kusnama Lauti Dwita Santy Lauty Dwita Santi, Lauty Dwita M. Heri Hermiyanto Zajuli Moh. Heri Hermiyanto Zajuli Mohammad Heri Hermiyanto, Mohammad Heri Muhammad Heri Hermiyanto, Muhammad Heri Musu, Juwita Trivianty Panuju Panuju Permana, ST.,M.Sc., Asep Kurnia R. Heryanto Surono Surono Syaiful Bachri Yoga Andriana Sendjaja, Yoga Andriana