Petroleum system modeling and assessment of the remaining hydrocarbon potential in the eastern part of Drava Depression

2018 ◽  
Vol 6 (1) ◽  
pp. SB11-SB21 ◽  
Author(s):  
Marko Cvetković ◽  
Ivona Emanović ◽  
Andrej Stopar ◽  
Petra Slavinić
Keyword(s):  
Source Rock ◽  
Pannonian Basin ◽  
System Modeling ◽  
Organic Content ◽  
Petroleum System ◽  
Rock Properties ◽  
Hydrocarbon Potential ◽  
Levels Of Detail ◽  
Petroleum System Modeling

The eastern part of the Drava Depression presents a relatively small part within the Croatian part of the Pannonian Basin. A confined part within the eastern part of the Drava Depression with a working petroleum system but few hydrocarbon accumulations was selected for the evaluation of the remaining hydrocarbon potential. Four subsurface models were built with different levels of detail on which determination of source rock maturity, assessment of potential, and finally, volumes of the potentially accumulated hydrocarbons were estimated. In addition, several case scenarios, regarding source rock properties and boundary conditions were addressed to present the risk points in the model. Results proved that the amounts of hydrocarbons generated ([Formula: see text] of oil and [Formula: see text] of gas) and accumulated ([Formula: see text] of oil and [Formula: see text] of gas) in the subsurface strongly support further exploration efforts even for the conservative modeling parameters (low heat flow [HF] and moderate total organic carbon values). A set of scenarios was also modeled including different HF, total organic content, and kinetic values each with significant impact for the final model result.

scholarly journals Thermal structure and source rock maturity of the North Peruvian forearc system: Insights from a subduction-sedimentation integrated petroleum system modeling

2020 ◽  
Vol 122 ◽  
pp. 104664
Author(s):  
Adriana Lemgruber-Traby ◽  
Nicolas Espurt ◽  
Christine Souque ◽  
Pierre Henry ◽  
Ysabel Calderon ◽  
...  
Keyword(s):  
Source Rock ◽  
Thermal Structure ◽  
System Modeling ◽  
Petroleum System ◽  
The North ◽  
Petroleum System Modeling

Petroleum system of Miocene troughs of the Pannonian Basin in southern Hungary, based on 3D basin modeling

2018 ◽  
Vol 6 (1) ◽  
pp. SB37-SB50 ◽  
Author(s):  
Viktor Lemberkovics ◽  
Edina Kissné Pável ◽  
Balázs Badics ◽  
Katalin Lőrincz ◽  
Alexander Rodionov ◽  
...  
Keyword(s):  
Source Rock ◽  
Pannonian Basin ◽  
System Modeling ◽  
Petroleum System ◽  
Source Rocks ◽  
Small Scale ◽  
Basin Modeling ◽  
Petroleum Systems ◽  
Wet Gas ◽  
Late Neogene

The role of the Middle-Upper Miocene source rocks in the Late Neogene petroleum system of the Pannonian Basin is undoubtedly significant, but it is not entirely understood. Only a few general publications exist that describe these sediments and their importance. We have focused on understanding the Neogene tectono-stratigraphic development and petroleum systems of these relatively small syn-rift grabens in southern Hungary. We have developed a workflow for organic geochemical, seismic, and facies interpretation; basin subsidence; and 3D basin modeling to better understand the Miocene-Pliocene-age petroleum system in a [Formula: see text] study area. This area fully covers two small-scale (less than [Formula: see text] size each) troughs filled by syn-rift and postrift deposits in large thickness with significantly different structural histories. During our investigation, six source rock beds were identified and built into the model. Thousands of meters of Lower Miocene, (Karpatian age) sediment accumulated in a “pull-apart,” but later structurally inverted Kiskunhalas Trough in the south, where four moderate- to good-quality (2 wt% estimated original total organic carbon [TOC], 200 HI), dominantly gas-prone, immature to wet gas mature source rock beds were identified. In the overlying Middle Miocene (Badenian age) sediments, generally good quality (2 wt% estimated original [TOC], 300–500 HI, type II and II-S), oil-prone, dominantly oil mature source bed was identified. This layer, as the regional Miocene source rock, is mainly responsible for the known hydrocarbon (HC) accumulations. The 3D basin and petroleum system modeling helped us understand the HC migration into the already-discovered fields as well as identify possible future exploration objects.

Basin and Petroleum System Modeling

2017 ◽  
pp. 381-417 ◽  
Author(s):  
Kenneth E. Peters ◽  
Oliver Schenk ◽  
Allegra Hosford Scheirer ◽  
Björn Wygrala ◽  
Thomas Hantschel
Keyword(s):  
System Modeling ◽  
Petroleum System ◽  
Petroleum System Modeling

Automated IR-analysis for the determination of reservoir qualities and source rock properties

1993 ◽  
Author(s):  
F. Oner ◽  
S. N. Ganz ◽  
W. Kalkreuth ◽  
M. J. Pearson ◽  
H. Wehner
Keyword(s):  
Source Rock ◽  
Rock Properties ◽  
Ir Analysis

scholarly journals Organic content and maturation effects on elastic properties of source rock shales in the Central North Sea

2019 ◽  
Vol 7 (2) ◽  
pp. T477-T497 ◽  
Author(s):  
Jørgen André Hansen ◽  
Nazmul Haque Mondol ◽  
Manzar Fawad
Keyword(s):  
Elastic Properties ◽  
Source Rock ◽  
North Sea ◽  
Empirical Relation ◽  
Organic Content ◽  
Rock Properties ◽  
Geochemical Data ◽  
Well Log ◽  
Seismic Properties ◽  
Central North Sea

We have investigated the effects of organic content and maturation on the elastic properties of source rock shales, mainly through integration of a well-log database from the Central North Sea and associated geochemical data. Our aim is to improve the understanding of how seismic properties change in source rock shales due to geologic variations and how these might manifest on seismic data in deeper, undrilled parts of basins in the area. The Tau and Draupne Formations (Kimmeridge shale equivalents) in immature to early mature stages exhibit variation mainly related to compaction and total organic carbon (TOC) content. We assess the link between depth, acoustic impedance (AI), and TOC in this setting, and we express it as an empirical relation for TOC prediction. In addition, where S-wave information is available, we combine two seismic properties and infer rock-physics trends for semiquantitative prediction of TOC from [Formula: see text] and AI. Furthermore, data from one reference well penetrating mature source rock in the southern Viking Graben indicate that a notable hydrocarbon effect can be observed as an addition to the inherently low kerogen-related velocity and density. Published Kimmeridge shale ultrasonic measurements from 3.85 to 4.02 km depth closely coincide with well-log measurements in the mature shale, indicating that upscaled log data are reasonably capturing variations in the actual rock properties. Amplitude variation with offset inversion attributes should in theory be interpreted successively in terms of compaction, TOC, and maturation with associated generation of hydrocarbons. Our compaction-consistent decomposition of these effects can be of aid in such interpretations.

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