The Relationship of Organic Components to Source Rocks Types Based on Biomarker Data at Central Sumatra Basin

2021 ◽  
Keyword(s):  
Southeast Asia ◽  
Qualitative Analysis ◽  
Source Rock ◽  
Botryococcus Braunii ◽  
Source Rocks ◽  
Organic Components ◽  
Biomarker Analysis ◽  
Central Sumatra ◽  
The Relationship ◽  
Geological Analysis

A biomarker study is used to observe the quality level of a hydrocarbon compound deposited on the source rock. The presence of Botryococcus braunii algae, Pediastrum algae, and other lacustrine algae is thought to be a contributing factor to petroleum in lacustrine basins throughout Southeast Asia. Botryococcus braunii is a group of green algae and belongs to the Trebouxiophyceae class. The purpose of this study is to discuss the relationship between organic compounds and the type of source rock in the Central Sumatra Basin. The Central Sumatra Basin is a back-arc basin that develops along the edge of the Sunda shelf in Southeast Asia. This basin was formed by the moving of the submergence of the Indian Ocean plate relative to the North and infiltrates the Asian Continent plate. The data used in this study is taken from several literatures/references in biomarker analysis where qualitative analysis was carried out, such as: matching the readings of compounds contained in the chromatogram and associate them with classification in some existing literatures where the selection of organic components that had an effect on geological analysis was carried out. An explanation of some of the data obtained along with the chromatogram and geological analysis and interpretation can be seen in this paper. Some conclusions can be drawn from this research in the form of qualitative analysis of organic components to define the maturity of the hydrocarbon and suspect the source organic materials of the hydrocarbon in source rocks. The explanation of the main biomarkers that must be considered when analyzing oil or source rock samples is to know the characteristic of the hydrocarbon and correlate it with reaction during the deposition.

scholarly journals Petroleum system analysis of the Mishrif reservoir in the Ratawi, Zubair, North and South Rumaila oil fields, southern Iraq

GeoArabia ◽  
2009 ◽  
Vol 14 (4) ◽  
pp. 91-108 ◽  
Author(s):  
Thamer K. Al-Ameri ◽  
Amer Jassim Al-Khafaji ◽  
John Zumberge
Keyword(s):  
Source Rock ◽  
Lower Cretaceous ◽  
System Analysis ◽  
Isotopic Analysis ◽  
Upper Jurassic ◽  
Source Rocks ◽  
Core Samples ◽  
Biomarker Analysis ◽  
Sulaiy Formation ◽  
Rock Analysis

ABSTRACT Five oil samples reservoired in the Cretaceous Mishrif Formation from the Ratawi, Zubair, Rumaila North and Rumaila South fields have been analysed using Gas Chromatography – Mass Spectroscopy (GC-MS). In addition, fifteen core samples from the Mishrif Formation and 81 core samples from the Lower Cretaceous and Upper Jurassic have been subjected to source rock analysis and palynological and petrographic description. These observations have been integrated with electric wireline log response. The reservoirs of the Mishrif Formation show measured porosities up to 28% and the oils are interpreted as being sourced from: (1) Type II carbonate rocks interbedded with shales and deposited in a reducing marine environment with low salinity based on biomarkers and isotopic analysis; (2) Upper Jurassic to Lower Cretaceous age based on sterane ratios, analysis of isoprenoids and isotopes, and biomarkers, and (3) Thermally mature source rocks, based on the biomarker analysis. The geochemical analysis suggests that the Mishrif oils may have been sourced from the Upper Jurassic Najma or Sargelu formations or the Lower Cretaceous Sulaiy Formation. Visual kerogen assessment and source rock analysis show the Sulaiy Formation to be a good quality source rock with high total organic carbon (up to 8 wt% TOC) and rich in amorphogen. The Lower Cretaceous source rocks were deposited in a suboxic-anoxic basin and show good hydrogen indices. They are buried at depths in excess of 5,000 m and are likely to have charged Mishrif reservoirs during the Miocene. The migration from the source rock is likely to be largely vertical and possibly along faults before reaching the vuggy, highly permeable reservoirs of the Mishrif Formation. Structural traps in the Mishrif Formation reservoir are likely to have formed in the Late Cretaceous.

The Logging Evaluation of the Relationship between Source Rock and Oil Layer Distribution in Southern Songliao Basin

2014 ◽  
Vol 962-965 ◽  
pp. 574-577
Author(s):  
Li Jun Xiu ◽  
He Ping Pan ◽  
Hao Xiu
Keyword(s):  
Source Rock ◽  
Quality Evaluation ◽  
Songliao Basin ◽  
Source Rocks ◽  
Source Control ◽  
Theory Theory ◽  
High Quality ◽  
The Relationship ◽  
Effective Source

At present, Most of the studies on source rocks is above the effective source rock identification and quality evaluation. But the spatial distribution of the high quality source rocks do not necessarily reflect the position of the layer. So, logging evaluation of the relationship between source rock and layer distributed in a region is necessary. In this paper 70 cores have selected from 4 wells in the first period of Qingshankou (q1), Songliao Basin, then get the experimental TOC value after core analysis. On the basis of source rock geochemical analysis, the author estimated the source rock TOC value with the ∆lgR method. As the distribution of high quality source rocks are clarified,the author draw a conclusion by researching on the relationship between the distribution of source rocks and layers which based on the "Source Control Theory" theory. Finally, it is found that the quality of the source rocks and layer distribution match well in both horizontal and vertical in this paper. This discovery is important for layer prediction and researches.

Biomarker Characteristic of Kelesa Oil Shale As Evidence of The Source of Organic Matter, Depositional Environment, and Maturity Interpretation

2020 ◽  
Author(s):  
B., M. Hartono
Keyword(s):  
Mass Spectrometry ◽  
Gas Chromatography ◽  
Organic Matter ◽  
Source Rock ◽  
Oil Shale ◽  
Depositional Environment ◽  
Petroleum System ◽  
Lacustrine Environment ◽  
Biomarker Analysis ◽  
Central Sumatra

Biomarker analyses can provide information about the source of organic matter, depositional environment, and maturity of source rock that is very useful for basin evaluation and understanding the petroleum system. In this paper, the study focuses on biomarker characterization of the Kelesa Formation that is situated in the Central Sumatra Basin, one of the petroliferous basins in Indonesia. This Eocene formation is equivalent to the Pematang Formation that is well known as acting as source rock in the Central Sumatra Basin. Thirty fresh outcrop samples were taken for biomarker analysis, with specification fourteen samples for gas chromatography and sixteen samples for gas chromatography-mass spectrometry. The gas chromatography analysis was done with a Perkin Elmer Clarus 600 type instrument while the mass spectrometry was done using a Perkin Elmer Clarus SQ 8C instrument. The results show that the organic matter dominantly comes from terrestrial plants with minor input from planktonic algae. Moreover, possible Botryococcus braunii input in the sediment suggests that the Kelesa Formation has been deposited in a lacustrine environment. Since the Kelesa Formation was deposited in a lacustrine environment, this formation is expected to be highly oil-prone source rock. The maturity biomarker indicators suggest that the formation does not reach appropriate maturity to expel hydrocarbon. However, the formation still has very good potential for oil shale resources. This study supports the previous study in the Kelesa Formation, and improves the understanding of the depositional history of the Kelesa Formation and the potential of the Kelesa Formation as oil shale resources. Moreover, the authors hope that this study can support recent basin evaluation and improve the understanding of the petroleum system in the Central Sumatra Basin.

Biogenic and Thermogenic Gas Potential of The Underexplored Southern Kutai Basin, Offshore East Kalimantan: A Case Study from South Sesulu Block

2021 ◽  
Author(s):  
Y. Artha
Keyword(s):  
Source Rock ◽  
Isotope Analysis ◽  
Source Rocks ◽  
Gas Chromatography Mass Spectrometry ◽  
Geochemical Data ◽  
Sedimentation Rates ◽  
East Kalimantan ◽  
Geochemical Evaluation ◽  
Potential Source Rock ◽  
Biomarker Analysis

The Southern Kutai Basin is currently less explored than the Mahakam area and others in the northern part of this Basin. Therefore, this research focuses on knowing the potential of active source rocks that can produce hydrocarbons, the volume that can be produced and its migration that can encourage exploration activities in this area. The method of this research is to conduct a geochemical evaluation as a screening of source rock which has the potential to generate biogenic and thermogenic hydrocarbons. Rock - Eval Pyrolysis, biomarker analysis in the form of Gas Chromatography - Mass Spectrometry (GC-MS) evaluated from eight exploration wells was used to determine the quantity, quality, maturity and environment of organic material deposition. 1D and 3D basin modelling using geochemical and geological evaluations to determine the presence of thermogenic hydrocarbon shows accumulations around the study area through migration analysis. Isotope analysis, thermal gradient and sedimentation rates are used to determine the environment and activity of anaerobic micro-organisms in generating biogenic gases. Geophysical analysis including interpretation and mapping of subsurface structures using 2D and 3D seismic are used to determine the distribution of potential source rock and its migration history. Geochemical data indicate that biogenic gas have been generated from within the Late Miocene tol recent sedimentary section where the quantity of organic matter is fair to excellent (0.51 – 7.31 %wt TOC) which represents the results of micro-organism activities where sedimentation rates avg 6,2 x 107 ton/year. Thermogenic gas; however, is estimated from the Late Oligocene to Early Miocene series of post rift sediment throughout the Kutai Basin.

The 35/9-7 Skarfjell discovery: a genuine stratigraphic trap, NE North Sea, Norway

2017 ◽  
Vol 8 (1) ◽  
pp. 339-354 ◽  
Author(s):  
Jens-Ole Koch ◽  
Andreas Frischbutter ◽  
Kjell Øygard ◽  
John Cater
Keyword(s):  
Source Rock ◽  
North Sea ◽  
Oil And Gas ◽  
Submarine Canyon ◽  
Upper Jurassic ◽  
Source Rocks ◽  
Gas Reservoirs ◽  
Biomarker Analysis ◽  
Recoverable Resources ◽  
Oil Source

AbstractThe Skarfjell oil and gas discovery, situated 50 km north of the Troll Field in the NE North Sea, was discovered by well 35/9-7 and was appraised by three additional wells operated by Wintershall, in the period 2012–14.The Skarfjell discovery is an example of a combined structural/stratigraphic trap. The trap formed along the northern edge of a deep WNW–ESE-trending submarine canyon, which was created by Volgian erosion of intra-Heather, Oxfordian-aged sandstones and then infilled with Draupne Formation shales. This mud-filled canyon forms the top and side seal, with the bottom seal provided by Heather shales. The reservoir comprises mid-Oxfordian deep-water turbidites and sediment gravity flows, which formed in response to tectonic hinterland uplift and erosion of the basin margin, 10–20 km to the east.The Skarfjell discovery contains light oil and gas, and may be subdivided into Skarfjell West, in which the main oil reservoir and gas cap have known contacts, and Skarfjell Southeast, which comprises thinner oil and gas reservoirs with slightly lower pressure and unknown hydrocarbon contacts.The Upper Jurassic Draupne and Heather formations are excellent source rocks in the study area. They have generated large volumes of oil and gas reservoired in fields, and discoveries for which the dominant source rock and its maturity have been established by oil to source rock correlation and geochemical biomarker analysis. The Skarfjell fluids were expelled from mid-mature oil source rocks of mixed Heather and Draupne Formation origin.The recoverable resources are estimated at between 9 and 16 million standard cubic metres (Sm3) of recoverable oil and condensate, and 4–6 billion Sm3 of recoverable gas. The Skarfjell discovery is currently in the pre-development phase and is expected to come on stream in 2021.

Oil to Source Rock Correlation Using Biomarker Data Through Pattern Matching and Fingerprinting Analysis in “Kitkat” Field, Jabung Block, South Sumatra Basin

2020 ◽  
Author(s):  
S., R. Muthasyabiha
Keyword(s):  
Pattern Matching ◽  
Source Rock ◽  
Vitrinite Reflectance ◽  
Hydrocarbon Exploration ◽  
Source Rocks ◽  
Maturity Level ◽  
Fingerprinting Analysis ◽  
Kerogen Type ◽  
Oil Characteristics ◽  
Biomarker Data

Geochemical analysis is necessary to enable the optimization of hydrocarbon exploration. In this research, it is used to determine the oil characteristics and the type of source rock candidates that produces hydrocarbon in the “KITKAT” Field and also to understand the quality, quantity and maturity of proven source rocks. The evaluation of source rock was obtained from Rock-Eval Pyrolysis (REP) to determine the hydrocarbon type and analysis of the value of Total Organic Carbon (TOC) was performed to know the quantity of its organic content. Analysis of Tmax value and Vitrinite Reflectance (Ro) was also performed to know the maturity level of the source rock samples. Then the oil characteristics such as the depositional environment of source rock candidate and where the oil sample develops were obtained from pattern matching and fingerprinting analysis of Biomarker data GC/GCMS. Moreover, these data are used to know the correlation of oil to source rock. The result of source rock evaluation shows that the Talangakar Formation (TAF) has all these parameters as a source rock. Organic material from Upper Talangakar Formation (UTAF) comes from kerogen type II/III that is capable of producing oil and gas (Espitalie, 1985) and Lower Talangakar Formation (LTAF) comes from kerogen type III that is capable of producing gas. All intervals of TAF have a quantity value from very good–excellent considerable from the amount of TOC > 1% (Peters and Cassa, 1994). Source rock maturity level (Ro > 0.6) in UTAF is mature–late mature and LTAF is late mature–over mature (Peters and Cassa, 1994). Source rock from UTAF has deposited in the transition environment, and source rock from LTAF has deposited in the terrestrial environment. The correlation of oil to source rock shows that oil sample is positively correlated with the UTAF.

scholarly journals Effective source rock selection and oil–source correlation in the Western Slope of the northern Songliao Basin, China

2021 ◽  
Vol 18 (2) ◽  
pp. 398-415
Author(s):  
He Bi ◽  
Peng Li ◽  
Yun Jiang ◽  
Jing-Jing Fan ◽  
Xiao-Yue Chen
Keyword(s):  
Organic Matter ◽  
Source Rock ◽  
Thermal Evolution ◽  
Songliao Basin ◽  
Source Rocks ◽  
Crude Oils ◽  
Western Slope ◽  
Geochemical Parameters ◽  
Group I ◽  
Oil Source

AbstractThis study considers the Upper Cretaceous Qingshankou Formation, Yaojia Formation, and the first member of the Nenjiang Formation in the Western Slope of the northern Songliao Basin. Dark mudstone with high abundances of organic matter of Gulong and Qijia sags are considered to be significant source rocks in the study area. To evaluate their development characteristics, differences and effectiveness, geochemical parameters are analyzed. One-dimensional basin modeling and hydrocarbon evolution are also applied to discuss the effectiveness of source rocks. Through the biomarker characteristics, the source–source, oil–oil, and oil–source correlations are assessed and the sources of crude oils in different rock units are determined. Based on the results, Gulong and Qijia source rocks have different organic matter primarily detrived from mixed sources and plankton, respectively. Gulong source rock has higher thermal evolution degree than Qijia source rock. The biomarker parameters of the source rocks are compared with 31 crude oil samples. The studied crude oils can be divided into two groups. The oil–source correlations show that group I oils from Qing II–III, Yao I, and Yao II–III members were probably derived from Gulong source rock and that only group II oils from Nen I member were derived from Qijia source rock.

Anthropological communities of interpretation for Burma: An overview

2008 ◽  
Vol 39 (2) ◽  
pp. 239-254 ◽  
Author(s):  
U Chit Hlaing
Keyword(s):  
Southeast Asia ◽  
Ethnic Groups ◽  
Field Of Study ◽  
Anthropological Theory ◽  
History Of ◽  
Relationship Of ◽  
The Relationship ◽  
The Way

AbstractThis paper surveys the history of anthropological work on Burma, dealing both with Burman and other ethnic groups. It focuses upon the relations between anthropology and other disciplines, and upon the relationship of such work to the development of anthropological theory. It tries to show how anthropology has contributed to an overall understanding of Burma as a field of study and, conversely, how work on Burma has influenced the development of anthropology as a subject. It also tries to relate the way in which anthropology helps place Burma in the broader context of Southeast Asia.

Sign in / Sign up

Export Citation Format

Share Document