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All Journal Journal of Geoscience Engineering and Energy (JOGEE) LEMBARAN PUBLIKASI MINYAK DAN GAS BUMI Scientific Contributions Oil and Gas
Junita Trivianty Musu
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Chemical Engineering, Chemistry & Bioengineering Civil Engineering, Building, Construction & Architecture Earth & Planetary Sciences Education Energy Environmental Science Industrial & Manufacturing Engineering Materials Science & Nanotechnology Physics

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MEKANISME OVERPRESSURE PADA SUMUR SM-1, CEKUNGAN SUMATRA UTARA Anak Agung Sagung Mayun Yudhyasmara Prabandari; Muhammad Burhannudinnur; Junita Trivianty Musu; Ricky Andrian Tampubolon
Journal of Geoscience Engineering & Energy (JOGEE) VOLUME 2, NOMOR 1, FEBRUARI 2021
Publisher : Universitas trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | Full PDF (1398.904 KB) | DOI: 10.25105/jogee.v2i1.8931

Abstract

Cekungan Sumatra Utara merupakan salah satu cekungan produktif di Indonesia yang diketahui memiliki kondisi overpressure berdasarkan beberapa peneliti terdahulu, seperti Aziz dan Bolt (1984) dan Hutasoit, dkk. (2013). Penelitian dilakukan untuk mengetahui zona overpressure pada sumur pengeboran SM-1 di Lapangan “AAS” dengan berdasarkan perhitungan besarnya nilai tekanan pori, mengetahui kedalaman top overpressure, dan mengetahui mekanisme penyebab overpressure berdasarkan log sonic, log densitas, dan log neutron. Nilai tekanan pori didapatkan berdasarkan perhitungan dengan metode Eaton menggunakan data log sonic. Diketahui top overpressure Sumur SM-1 pada kedalaman 1653 ft, dimana zona overpressure berada pada kedalaman 1653 – 2510 ft, 3195 – 3473 ft, dan 4205 – 4486 ft (Formasi Baong). Mekanisme penyebab overpressure pada Sumur SM-1 adalah mekanisme loading berupa disequilibrium compaction.
Analisis Lingkungan Pengendapan Formasi Batugamping Dayang Distrik Batanta Utara, Kabupaten Raja Ampat, Provinsi Papua Barat Fajar Kurniawan Rohmala; David V. Mamengko; Wiratama Rana; Pribowo A. Kusumo; Junita Trivianty Musu
Lembaran Publikasi Minyak dan Gas Bumi Vol. 54 No. 3 (2020): LPMGB
Publisher : BBPMGB LEMIGAS

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Abstract

Secara geologi, Daerah Yensawai didominasi oleh batuan beku sebagai basement (batuan dasar) dan batuan sedimen (batugamping dan silisiklastik) di mana daerah tersebut menjadi bagian dari Auwewa Volcanic Group. Batugamping Dayang merupakan salah satu formasi yang memiliki karakteristik relatif sama dengan batugamping di kawasan Auwewa Volcanic Group dan memiliki kesamaan dengan Batugamping Maruni dan Batugamping Kais. Penelitian ini menggunakan beberapa pendekatan analisis diantaranya adalah analisis geokimia (X-Ray Fluorescene/XRF), analisis provenance dan analisis microfasies karbonat. Analisis tersebut dimaksud untuk menentukan menetukan jenis litologi, lingkungan pengendapan, komposisi kimia batuan, dan asal material pembentuk batuan. Hasil analisis geokimia menunjukkan bahwa Batugamping Dayang terendapkan pada kondisi laju penguapan air laut (evaporasi) dan paleo salinitas yang rendah, laju reduksi sulfat yang cepat dan memiliki aliran yang tenang serta berenergi rendah. Hasil analisis provenance menunjukkan bahwa sumber Batugamping Dayang berasal dari area dissected arc dan transisional arc. Analisis mikrofasies karbonat daerah penelitian menujukkan daerah penelitian merupakan penciri dari deep shelf. Hasil penelitian ini menunjukan bahwa batugamping Dayang diendapkan pada lingkungan yang berbeda dengan batugamping Kais maupun batugamping Maruni. Hubungan stratigrafi batugamping Dayang kemiripan dengan batugamping Sagewin pada Formasi Gunungapi Dore diendapkan pada lingkungan fore reef environment sebagai island arc.
APPLICATION OF OLEANANE AND STERANE INDEX FOR BIOSTRATIGRAPHIC AGE DETERMINATION: EXAMPLES FROM KANGEAN OILS, NORTHEAST JAVA BASIN Himawan Sutanto; Junita Trivianty Musu
Scientific Contributions Oil and Gas Vol 37 No 1 (2014)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.37.1.618

Abstract

Northeast Java Basin is known as mature Cenozoic basin, yet this understanding override possibility ofsediment older than Cenozoic. This thoughthas brought current exploration strategy of this basin concerningwithin only Cenozoic sediments. Therefore, it is believed that the source rock in this basin was also derivedfrom Cenozoic sediments, especially the Ngimbang Formation, which was formed during Late Eoceneto Early Oligocene in the stage of Early Synrift. On the other hand, the occurrence of Alisporites sp haspointed Cretaceous sediments is a potential source rock. However, it is still debatable due to the presence ofAlisporites similis in Serawak Basin of Malaysia, which is present until Paleocene. Three crude oils from theKangean oil fi eldNortheast Java Basin, namely NEJB-748, NEJB-749 and NEJB-750have been investigatedusing gas chromatography (GC) and gas chromatography/mass spectrometry (GC/MS).Kangean oils areclassifi ed as mixed oil with organic matter originated from marine and terrestrial deposited under oxidizingand reducing conditions. Moreover, Kangean oils show very low oleanane and steraneindexthat may leadus to the conclusion that the oils were originated from Cretaceous source rock.
RESERVOIR QUALITY REDUCTION CAUSED BY CLAY INDUCED DUCTILITY Junita Trivianty Musu; Bambang Widarsono
Scientific Contributions Oil and Gas Vol 33 No 1 (2010)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.33.1.659

Abstract

Ductile components including rock fragments, clay, and matrix material are often consideredas the most important factors that control quality of shaly sandstones, which are usually characterized by low porosity and permeability. In presence of ductile components, the degree of quality reduction is affected mainly by distribution, occurences, and amounts of the ductile components. Therefore, the presence of ductile components affects rock petrophysics, and consequently has effect on fluid movements in reservoir during production. This paper presents results of the study on plug samples taken from five wells from various fields in Cooper Basin (Tirrawarra Sand), South Australia. The samples were studied petrographically using x-ray diffraction, optical petrography, and scanning electrone microscope. The results were integrated with routine and special core analysis data. The overall results show that the distribution and the amount of ductile components have significantly reduced porosity, hence the quality of the reservoir. However, the effect is different for different types of porosity, and this certainly is valuable addition to our understanding over permeability behavior of shaly sandstones.
The Effect Of Biocides Addition Against Morphology And Size Distribution Of Bacteria Cells In Injection Water Zulkifliani Zulkifliani; Junita Trivianty Musu
Scientific Contributions Oil and Gas Vol 34 No 1 (2011)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.34.1.792

Abstract

Produced water is the water produced along with oil and gas. Produced water contains small to large quantities of suspended solids, such as corrosion material, scale, clay, wax, oil residues, and also bacteria and their metabolites. Produced water which is re-injected into the reservoir without having proper water treatment can lead to rock plugging and reservoir damage. One of the causes of reservoir damage is the occurrence of bacteria cells and their metabolites. Biocides are used to reduce the viability of bacteria cells in produced water to be applied as water injection. The aim of this study is to understand the effect of biocides on morphology and the size distribution of bacteria cells in injected water. Observations with scanning electron microscope (SEM) and laboratory tests showed that provision of biocides can cause damage of cytoplasmic membrane on bacteria cells or cells lyses and significantly reduced size distribution of bacteria cells.
Integrating Petrography With Core-Log-Well Test Data For Low Permeability Sandstone Reservoir Characterization: Preliminary Recommendation For Production Optimization Junita Trivianty Musu; Hadi Prasetyo; Bambang Widarsono
Scientific Contributions Oil and Gas Vol 33 No 3 (2010)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.33.3.823

Abstract

Integrating petrographic core information into combined core petrophysics, log, and well test data for understanding facies and environmental deposition in rock characterization has proved itself useful to improving quality and reliability of the required conclusions. This integrated approach has specifically shown its use in the cases of complex reservoirs such ones characterized as low-permeability sandstone reservoirs. It is in this spirit that this paper demonstrates how this virtually cost efficient analysis provides preliminary recommendations for the exploitation of such reservoirs. As case study, two types of producing reservoirs (Bekasap, Bangko, Pematang, and Tanjung Formations) have been taken in 2009. The first type is strongly controlled by depositional environment. It is found in the upper part of Bekasap and Bangko formations (1900 - 2300 ft-ss), deposited in estuarine system, and made of very fine to fine grained sand with low to moderate bioturbation. This mostly feldspathic and lithic greywackes have permeability of up to 200 mD. The second type is strongly dominated by diagenesis process and is mainly found in the Upper Pematang and Tanjung Formations (6200 - 7400 ft-ss). This reservoir type is characterized by its coarse-grained and conglomeratic sandstones resulted from fan- elta and braided channel depositional system. Diagenetic events such as compaction, recrystallization of matrix into microcrystalline clay minerals, precipitation of authigenic minerals in pore system are also well identified from the performed petrographic analysis. This is dominated by sublitharenite and litharenite sandstones exhibit horizontal permeability of up to several dozens mD. The two producing reservoir types have undergone carefully planned exploitation and stimulation operations, and the horizontal drilling and fracturing
DETERMINATION OF SHALE GAS POTENTIAL OF NORTH SUMATRA BASIN: AN INTEGRATION OF GEOLOGY, GEOCHEMISTRY, PETROPHYSICS AND GEOPHYSICS ANALYSIS Junita Trivianty Musu; Bambang Widarsono; Andi Ruswandi; Himawan Sutanto; Humbang Purba
Scientific Contributions Oil and Gas Vol 38 No 3 (2015)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.38.3.946

Abstract

A detailed combined geological and geophysical study in North Sumatra basin has shown thatprospective formations for shale play containing gas sweet spots are found to be in shales from Bampo,Belumai, and Baong Formations. Bampo Formation exhibits low shale gas potential with very low tomedium in organic material contents, maturity index of immature to mature, and moderate brittleness. Rockswithin the formation tend to be reactive to highly reactive to water, with a moderate degree of swellingcapacity. Porosity varies within 5.8 - 7.4 % with permeability ranging from 0.37 to 3.2 mD. Sweet spots inthe formation found around Basilam-1 and Securai-1wells occupy about 21% of the formation. On the otherhand, Belumai Formation shows moderate to good shale gas potential, with low to high organic materialcontents, immature to mature levels of maturity, and moderately brittle to brittle. Sweet spot areas in theformation found around the two wells are about 29% of the formation. For Baong Formation, analysisreveals moderate to good shale gas potential, with low to medium contents of organic material, immatureto mature in maturity index, moderately brittle to brittle in brittleness, and tendency of being reactiveto highly reactive to water but with low degree of swelling capacity. Sweet spots in the formation foundaround the two wells occupies are roughly 11% of the total formation volume in the area. Basin modelingleading to gas resources estimation for Baong, Belumai and Bampo Formations has led to estimatedvolumes of 6,379 TCF, 16,994 TCF, and 25,024 TCF, respectively, with a total amount of 48,397 TCF.The resources figures are speculative in nature and do not incorporate any certainty and efficiency factors.
NMR T2 CUT OFF: WHICH ONE IS TO BE USED FOR APPLICATION? Bambang Widarsono; Junita Trivianty Musu
Scientific Contributions Oil and Gas Vol 30 No 3 (2007)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.30.3.977

Abstract

Recent developments in petroleum industry have been witnessing the surge of the use of nuclear magnetic resonance (NMR) log. Despite some remaining problems the NMR technology appears to gain more acceptance as petrophysical tool for evaluating reservoir quality. Comprehensive formation evaluation requires determination of irreducible fluids, movable fluids, and permeability. However, rock heterogeneity introduces complexity in any formation evaluation activities. This can also cause problem for NMR log interpretation. In the presence of clays the most commonly used T2 cut off values, a constant value throughout a formation, seem to eventually yield inaccurate irreducible water saturation estimates, as well as other output such as permeability. This study focuses at finding a solution for finding the best way of choosing the most representative T2 cut off value to be used in NMR log interpretation. This is indeed a common pressing problem for heterogeneous formation rocks such as in the case of Tirrawarra sandstones used in this study. The main part of the study is devoted to comparison between the use of single averaged T2c value and establishment of empirical correlations enabling the provision of T2c for any level of heterogeneity (i.e. various levels of shaliness). The study however surprisingly shows that, in spite of the theoretical soundness of the empirical correlations established, simple averaging of T2c values yielded by a reliable method proves itself adequate. This conclusion therefore helps considerably in reducing complexity in NMR log interpretation.
TO EXPLAIN THE NATURE OF CORE POROSITY USING RESULTS OF PETROGRAPHY ANALYSIS Junita Trivianty Musu
Scientific Contributions Oil and Gas Vol 30 No 3 (2007)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.30.3.979

Abstract

The Permian to Triassic Tirrawarra Sandstone succession in the Cooper Basin of CentralAustralia is characterized by its low permeability. Ambient core porosity averages8.96% and ambient permeability 0.9 mD. Most samples studied have permeabilities lessthan 3mD. Despite its overall poor reservoir characteristics, the Tirrawarra Sandstone isone of the major oil and gas targets in Australia. A total of 17 core plugs from 6 wellswere studied petrographically using optical petrography, SEM and XRD. These resultswere integrated with core analysis data.Petrographic study revealed the diagenetic events, mainly mechanical and chemicalcompaction, cementation and alteration have modified the reservoir quality. Ductile componentssuch as rock fragments, clay and matrix influence mechanical compaction, whichare the main cause of reservoir quality reduction. Quartz cementation and clay distributionalso affected the porosity, but particularly permeability. Mechanical compaction aswell as quartz cementation have reduced and blocked pore-throats to isolate intergranularpores. The alteration of feldspar to kaolin has changed intergranular porosity tomicroporosity. Illite occurs as either cement, alteration of rock fragments or kaolinite. Allof these diagenetic events also affect fluid movement in the reservoir.This paper presents the evaluation of the determination of effectiveness of porosity inthe delivery of gas from sandstone reservoir in the Cooper Basin using integrated petrographyanalysis and core measurements.
Co-Authors Anak Agung Sagung Mayun Yudhyasmara Prabandari Andi Ruswandi Bambang Widarsono David V. Mamengko Fajar Kurniawan Rohmala Himawan Sutanto Humbang Purba Muhammad Burhannudinnur Pribowo A. Kusumo Ricky Andrian Tampubolon Wiratama Rana Zulkifliani Zulkifliani