Quantification of oil generation and migration in the Malacca Strait region Central Sumatra

2018 ◽  
Author(s):  
D.S. MacGregor
Keyword(s):  
Oil Generation ◽  
And Migration ◽  
Central Sumatra ◽  
Malacca Strait

The Characterization of Stratigraphic Play in Middle Baong Sand for Hydrocarbon Prospecting in Offshore North Sumatera Basin

2021 ◽  
Author(s):  
A. Nurhasan
Keyword(s):  
Depositional Environment ◽  
Hydrocarbon Exploration ◽  
Ratio Distribution ◽  
Basin Floor ◽  
Distinct Character ◽  
Net To Gross ◽  
And Migration ◽  
Sand Bodies ◽  
Malacca Strait

Pertamina EP is operating a small block in Offshore North Sumatera Basin where a couple of the fields are producing gas and condensate from the Belumai Carbonate. However, the wells production is depleting and several delineation wells are unable to find additional reserves, it is important to find a new play within the block. Few discoveries in the Middle Baong Sand (MBS) reservoir suggested a promising stratigraphic play to be explored, but it requires more detailed characterization of the reservoir extent. The Malacca strait-sourced MBS consists of several deposited sand packages during a mega sequence. The term MBS might represent a deltaic environment from a transgressive system tract of some marine shore bar or a basin floor fan. Each system has a distinct character (thickness, net to gross ratio, distribution) that must be evaluated before proposing an exploration well. The depositional environment and reservoir distribution are interpreted and modeled using regional 2D seismic and high-quality 3D seismic. Paleo-bathymetric interpretation from well samples shows a good correlation with the palinspastic reconstruction. The result shows that the Pertamia EP working area is located in the shore bar depositional environment. Seismic attributes are used to delineate reservoir distribution within the working block and well logs are used to constrain prospective sand bodies and water zones identification. Furthermore, source rock maturation and migration path and hydrocarbon occurrence from the discovery wells have been evaluated for hydrocarbon prospecting and risking. This study suggests a promising lead for hydrocarbon exploration in the study area and opens up a new opportunity for an underexplored play.

Petroleum migration in the Bight Basin: a fluid inclusion approach to constraining source, composition and timing

2017 ◽  
Vol 57 (2) ◽  
pp. 762 ◽  
Author(s):  
Richard Kempton ◽  
Julien Bourdet ◽  
Se Gong ◽  
Andrew Ross ◽  
Jacques Pironon
Keyword(s):  
Information Source ◽  
Offshore Area ◽  
Petroleum Migration ◽  
Geochemical Fingerprinting ◽  
Oil Generation ◽  
Unique Method ◽  
And Migration ◽  
The University ◽  
Great Australian Bight ◽  
Oil Gas

The Bight Basin in southern Australia is a vast under-explored offshore area with promise of, but as of yet, limited proof for hydrocarbons. Fluid inclusions (FIs) offer a unique method to test for petroleum migration, composition and timing, which would otherwise remain hidden in the rocks, and more direct evidence to calibrate basin models. A reconnaissance-scale FI study, using CSIRO’s Grain with Oil Inclusion (GOI™) technique, was undertaken to detect liquid hydrocarbons in Jurassic to Cretaceous sandstones. Oil-bearing, and in some cases gas-rich, inclusions were detected at low abundance, and their presence provides proof of oil generation and migration in the Ceduna Sub-basin. Geochemical fingerprinting of FI oil was undertaken using the Molecular Composition of oil Inclusions (MCI) technique on an intra-Coniacian interval in Gnarlyknots-1A and a Cenomanian interval in Greenly-1. The results show differences in the type of organic matter input, with algal co-sourcing significant for the central Ceduna Sub-basin. The timing of oil migration from pressure-temperature (PT) reconstructions was interpreted in Gnarlyknots-1A, Greenly-1, Duntroon-1 and Potoroo-1. The results indicate oil charge during the Late Cretaceous in the basin depocentres, explained by sediment loading of the Upper Cretaceous succession by the Hammerhead Supersequence and oil, gas-condensate and gas charge to the depocentres and basin margins during the Miocene. The Great Australian Bight Research Program is a collaboration between BP, CSIRO, the South Australian Research and Development Institute (SARDI), the University of Adelaide and Flinders University. The Program aims to provide a whole-of-system understanding of the environmental, economic and social values of the region, providing an information source for all to use.

scholarly journals Pemodelan Intensitas Rekahan pada Fractured Basement Reservoir dengan Pendekatan Konsep Geologi Menggunakan Analisis Kualitatif di Cekungan Sumatra Tengah

2018 ◽  
Vol 2 (1) ◽  
pp. 1
Author(s):  
Muchamad Ocky Bayu Nugroho ◽  
Carolus Prasetyadi ◽  
Teguh Jatmiko
Keyword(s):  
Fault Plane ◽  
Rock Surface ◽  
Hydrocarbon Migration ◽  
Drilling Data ◽  
Fracture Intensity ◽  
Half Graben ◽  
Regional Tectonic ◽  
Central Sumatra ◽  
Parameter Approach ◽  
Malacca Strait

<p>Lokasi Penelitian terletak di Selat Malaka dan termasuk dalam Cekungan Sumatra Tengah. Secara stratigrafi, Batuan Dasar Cekungan Sumatra Tengah berumur Pra Tersier dengan litologi batuan sedimen yang termalihkan atau metasedimen. Berdasarkan data sumur pemboran, batuan dasar di lokasi penelitian secara umum berupa kuarsit dan filit. Rekahan pada batuan dasar dikontrol oleh periode tektonik regional yang mempengaruhi Sumatra. Sesar-sesar yang terbentuk berarah umum Utara Barat Laut – Selatan Tenggara (NNW – SSE), hasil dari fase tektonik selama Paleogen hingga Neogen yang menghasilkan morfologi batuan dasar beragam akibat adanya horst graben dan half graben. Morfologi tinggian adalah yang berpotensi menjadi reservoir karena batuan induk yang terletak lebih rendah akan memungkinkan migrasi hidrokarbon. Identifikasi rekahan batuan dasar dianalisa berdasarkan data pemboran sumur dan seismik. Intensitas rekahan dibangun berdasarkan model dengan pendekatan 4 parameter geologi yaitu intensitas rekahan dengan jarak dari bidang sesar, intensitas rekahan dengan pucak antiklin, intensitas rekahan dengan jarak dari permukaan batuan dan dibantu dengan atribut seismik. Nilai intensitas yang memungkinkan terbentuk rekahan adalah 0,3-1.</p><p><em>The research site is located in the Malacca Strait and is included in the Central Sumatra Basin. Stratigraphically, the basement of the Central Sumatra Basin is Pre-Tertiary with thermal sedimentary or metasediment lithology. Based on data from drilling wells, bedrock in the study site generally consists of quartzite and filite. Fractures in bedrock are controlled by regional tectonic periods affecting Sumatra. Faults that form are generally north-north-south-south (NNW-SSE), resulting from tectonic phases during Paleogene to Neogene which produce various bedrock morphologies due to horst graben and half graben. Height morphology is the potential to be a reservoir because the source rock which is located lower will allow hydrocarbon migration. Identification of basement fractures was analyzed based on well and seismic drilling data. The fracture intensity was built based on the model with a 4 geological parameter approach, namely fracture intensity with distance from the fault plane, fracture intensity with anticline peaks, fracture intensity with distance from the rock surface and assisted with seismic attributes. The intensity value that allows the fracture to form is 0.3-1.</em></p>

Hydrocarbon charge history of the Gippsland Basin

2010 ◽  
Vol 50 (2) ◽  
pp. 729
Author(s):  
Keyu Liu ◽  
Peter Eadington ◽  
David Mills ◽  
Richard Kempton ◽  
Herbert Volk ◽  
...  
Keyword(s):  
System Analysis ◽  
Evaluation Research ◽  
Petroleum System ◽  
Additional Information ◽  
Oil Generation ◽  
History Of ◽  
And Migration ◽  
Hydrocarbon Charge ◽  
Gas Fields ◽  
Gippsland Basin

As part of a larger petroleum system analysis and resource re-evaluation research program in the Gippsland Basin, over 400 samples from 29 selected wells in the Gippsland Basin were investigated using quantitative fluorescence techniques developed by CSIRO Petroleum, including the quantitative grain fluorescence (QGF) and QGF on extracts (QGF-E) and the total scanning fluorescence (TSF) techniques. Preliminary results have provided new insight into the hydrocarbon migration and charge history of the Gippsland Basin. The investigation has revealed: widespread occurrence of palaeo oil columns in some of the major gas fields, indicating that a significant amount of oil was charged into these reservoirs prior to a subsequent gas accumulation; that some of the current oil intervals appear to have received a relatively late oil charge, either through new charge or through palaeo oil re-distribution due to adjustments within the petroleum system; palaeo oil columns appear to be restricted to a certain distance range from the major source kitchens; and, evidence of a sequential oil migration and displacement along structural highs where reservoirs distal to the source kitchens received progressively lighter and more mature palaeo oils. These findings are consistent with the oil generation and migration model proposed by O’Brien et al (2008). Fluid inclusion petrographic investigations and molecular composition of inclusions (MCI) analysis are currently underway that will provide additional information on the hydrocarbon charge history in the Gippsland Basin.

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