Organic Geochemistry of Crude Oils and Source Rocks, Békés Basin

1994 ◽  
pp. 161-185 ◽  
Author(s):  
J. L. Clayton ◽  
I. Koncz ◽  
J. D. King ◽  
E. Tatár
Keyword(s):  
Organic Geochemistry ◽  
Source Rocks ◽  
Crude Oils

ORGANIC GEOCHEMISTRY OF CRUDE OILS AND UPPER CRETACEOUS SOURCE ROCKS FROM CONCESSION 11, WEST SIRTE BASIN, LIBYA

2016 ◽  
Vol 39 (4) ◽  
pp. 393-413 ◽  
Author(s):  
W. Sh. El Diasty ◽  
S. Y. El Beialy ◽  
K. E. Peters ◽  
H. El Atfy ◽  
A. M. Gheith ◽  
...  
Keyword(s):  
Upper Cretaceous ◽  
Organic Geochemistry ◽  
Source Rocks ◽  
Crude Oils ◽  
Sirte Basin

scholarly journals Source rock characterization and oil grouping in the NW Java, Central Java and NE Java Basins, Indonesia

2021 ◽  
Vol 47 (2) ◽  
pp. 48-66
Author(s):  
Ragil Pratiwi
Keyword(s):  
Organic Geochemistry ◽  
Hierarchical Cluster ◽  
Source Rocks ◽  
Geochemical Data ◽  
Crude Oils ◽  
Central Java ◽  
Agglomerative Hierarchical Cluster Analysis ◽  
Marine Source ◽  
Group 5 ◽  
Rock Characterization

This study reveals the detailed organic geochemistry from crude oils (acquired from wells and seepages) and rock extracts from NW Java and NE Java Basin that have been gathered and compiled from previous publications. The interpretation was conducted from geochemical data value and plot, GC-MS fingerprints, and agglomerative-hierarchical cluster analysis using the Euclidean algorithm. Various source rocks from those basins were deposited under fluvio-lacustrine to the marine environment. Six groups of crude oils are also distinguished. Groups 1, 2, and 6 are oils from deltaic source rocks, Groups 3 and 4 are oils from marine source rocks, and Group 5 is from lacustrine and/or fluvio-lacustrine source rocks. Groups 1, 2, and 6 could be distinguished from the pristane/phytane (Pr/Ph) ratio and C29 sterane composition, while Groups 3 and 4 differ from the distribution of C27 sterane. The schematic depositional environment of source rocks is also generated from this study and suggests that Group 5 is deposited during early syn-rift non-marine settings, while the remaining groups are deposited in the deltaic (Group 1,2 and 6) and marine settings (Groups 3 and 4). The main differences between those groups are including the distributions of C27-C28-C29 steranes.

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.

Organic geochemistry of possible middle Miocene–Pliocene source rocks in the west and northwest Nile Delta, Egypt

2021 ◽  
pp. 109357
Author(s):  
W. Sh. El Diasty ◽  
J.M. Moldowan ◽  
K.E. Peters ◽  
M.M. Hammad ◽  
G.I. Essa
Keyword(s):  
Middle Miocene ◽  
Nile Delta ◽  
Organic Geochemistry ◽  
Source Rocks ◽  
The West

Organic geochemistry of Miocene source rocks from the Banat Depression (SE Pannonian Basin, Serbia)

2011 ◽  
Vol 42 (6) ◽  
pp. 655-677 ◽  
Author(s):  
Sanja Mrkić ◽  
Ksenija Stojanović ◽  
Aleksandar Kostić ◽  
Hans Peter Nytoft ◽  
Aleksandra Šajnović
Keyword(s):  
Organic Geochemistry ◽  
Pannonian Basin ◽  
Source Rocks

scholarly journals The Cogollo Group and the oceanic anoxic events 1a and 1b, Maracaibo basin, Venezuela

2015 ◽  
Vol 45 (suppl 1) ◽  
pp. 41-61 ◽  
Author(s):  
José Alejandro Méndez Dot ◽  
José Méndez Baamonde ◽  
Dayana Reyes ◽  
Rommel Whilchy
Keyword(s):  
Source Rock ◽  
Organic Geochemistry ◽  
Sedimentary Facies ◽  
Source Rocks ◽  
Maracaibo Basin ◽  
Pelagic Environment ◽  
Anoxic Events ◽  
Anoxic Environment ◽  
Platform System ◽  
La Luna

ABSTRACTCarbonates of Cogollo Group (Apón, Lisure and Maraca formations) constitute the broader calcareous platform system originated during Aptian and Albian of Cretaceous in north-western South America, Maracaibo Basin, Venezuela. On the shallow shelf, a variety of calcareous sedimentary facies were deposited during marine transgressive and regressive cycles. Some of them developed porosity and constitute important hydrocarbon reservoirs. Due to some major marine transgressions, from early Aptian, the anoxic environment and characteristic facies of a pelagic environment moved from the outer slope and basin to the shallow shelf, during specific time intervals, favouring the sedimentation of organic matter-rich facies, which correspond to the oceanic anoxic events (OAEs) 1a and 1b. The source rock of Machiques Member (Apón Formation) was deposited during early Aptian OAE 1a (~ 120 Ma). The source rock of Piché Member, located at the top of the Apón Formation, was deposited during late Aptian OAE 1b (~ 113 Ma). Finally, La Luna Formation, from Cenomanian, that covers the OAE 2 (~ 93 Ma), represents the most important source rock in the Maracaibo Basin. In this way and based on sedimentological and organic geochemistry results from the determinations performed on 247 samples belonging to six cores in the Maracaibo Basin, we propose these two organic-rich levels, deposited on the shallow shelf of the Cogollo Group, as "effective source rocks", additional to La Luna Formation, with oil migration in relatively small distances to the porosity facies.

scholarly journals Thermal Maturation Regime Revisited in the Dongying Depression, Bohai Bay Basin, East China

Geofluids ◽  
2021 ◽  
Vol 2021 ◽  
pp. 1-17
Author(s):  
Haiping Huang ◽  
Hong Zhang ◽  
Zheng Li ◽  
Mei Liu
Keyword(s):  
Organic Geochemistry ◽  
Vitrinite Reflectance ◽  
Source Rocks ◽  
East China ◽  
Burial Depth ◽  
Bohai Bay ◽  
Hydrocarbon Generation ◽  
Bohai Bay Basin ◽  
Dongying Depression ◽  
Hydrocarbon Maturation

To the accurate reconstruction of the hydrocarbon generation history in the Dongying Depression, Bohai Bay Basin, East China, core samples of the Eocene Shahejie Formation from 3 shale oil boreholes were analyzed using organic petrology and organic geochemistry methods. The shales are enriched in organic matter with good to excellent hydrocarbon generation potential. The maturity indicated by measured vitrinite reflectance (%Ro) falls in the range of 0.5–0.9% and increases with burial depth in each well. Changes in biomarker and aromatic hydrocarbon isomer distributions and biomarker concentrations are also unequivocally correlated with the thermal maturity of the source rocks. Maturity/depth relationships for hopanes, steranes, and aromatic hydrocarbons, constructed from core data indicate different well locations, have different thermal regimes. A systematic variability of maturity with geographical position along the depression has been illustrated, which is a dependence on the distance to the Tanlu Fault. Higher thermal gradient at the southern side of the Dongying Depression results in the same maturity level at shallower depth compared to the northern side. The significant regional thermal regime change from south to north in the Dongying Depression may exert an important impact on the timing of hydrocarbon maturation and expulsion at different locations. Different exploration strategies should be employed accordingly.

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