3D basin and petroleum system modelling in the North Sea Central Graben - a Dutch, German, Danish cross-border study

2020 ◽  
Author(s):  
Rüdiger Lutz ◽  
Jashar Arfai ◽  
Susanne Nelskamp ◽  
Anders Mathiesen ◽  
Niels Hemmingsen Schovsbo ◽  
...  
Keyword(s):  
Pilot Study ◽  
North Sea ◽  
Large Scale ◽  
Petroleum System ◽  
Source Rocks ◽  
System Model ◽  
Geochemical Data ◽  
System Modelling ◽  
Horizon 2020 ◽  
Cross Border

<p>A Geological Analysis and Resource Assessment of selected Hydrocarbon Systems (GARAH) is carried out as part of the overarching GeoERA project. Here, we report first results of a 3D basin and petroleum system model developed in a cross-border area of the Dutch, Danish and German North Sea Central Graben area. This pilot study reconstructs the thermal history, maturity and petroleum generation of potential Lower, Middle and Upper Jurassic source rocks. The 3D pilot study incorporates new aggregated and combined layers from the three countries. Results of the study feed back into the 3DGEO-EU project of GeoERA.</p><p>Eight key horizons covering the whole German Central Graben and parts of the Dutch and Danish North Sea Central Graben were selected for building the stratigraphic and geological framework of the 3D basin and petroleum system model. The model includes depth and thickness maps of important stratigraphic units as well as the main salt structures. Petrophysical parameters, generalized facies information and organic geochemical data from well reports are assigned to the different key geological layers. The model is further calibrated with temperature and maturity data from wells of the three countries and from publications. The time span from the Late Permian to the Present is represented by the model including the most important erosional phases related to large-scale tectonic events during the Late Jurassic to Late Cretaceous. Additionally, salt movement through time expressed as diapirs and pillows is considered within the 3D basin and petroleum system model.</p><p>This is a part of an ongoing EU Horizon 2020 GeoERA project (The GARAH, H2020 grant #731166 lead by GEUS).</p>

3D basin and petroleum system modelling in the North Sea Central Graben - a Dutch, German, Danish cross-border study

2021 ◽  
Author(s):  
Rüdiger Lutz ◽  
Susanne Nelskamp ◽  
Anders Mathiesen ◽  
Niels Hemmingsen Schovsbo ◽  
Stefan Ladage ◽  
...  
Keyword(s):  
Pilot Study ◽  
North Sea ◽  
Large Scale ◽  
Petroleum System ◽  
Source Rocks ◽  
System Model ◽  
Geochemical Data ◽  
System Modelling ◽  
Horizon 2020 ◽  
Cross Border

<p>A Geological Analysis and Resource Assessment of selected Hydrocarbon Systems (GARAH) is carried out as part of the overarching GeoERA project. Here, we report results on the first public 3D basin and petroleum system model developed in a cross-border area of the Dutch, Danish and German North Sea Central Graben. This pilot study reconstructs the thermal history, maturity and petroleum generation of potential Lower, Middle and Upper Jurassic source rocks and assesses potential unconventional resources in a first phase. The 3D pilot study incorporates new aggregated and combined layers of the three countries. Results of the study feed back into the 3DGEO-EU project of GeoERA.</p><p>Eight key horizons covering the whole German Central Graben and parts of the Dutch and Danish North Sea Central Graben were selected for building the stratigraphic and geological framework of the 3D basin and petroleum system model. The model includes depth and thickness maps of important stratigraphic units as well as the main salt structures. Petrophysical parameters, generalized facies information and organic geochemical data from well reports are assigned to the different key geological layers. Further, the model is calibrated with temperature and maturity data from selected offshore wells as well as from publications. The time span from the Late Permian to the Present is represented by the model, including the most important erosional phases related to large-scale tectonic events during the Late Jurassic to Late Cretaceous. Additionally, salt movement through time expressed as diapirs and pillows is considered within the 3D basin and petroleum system model. Simulations depict that unconventional petroleum resources (oil and natural gas) are present in varying amounts in the source rocks across all three countries.</p><p>This is a part of an ongoing EU Horizon 2020 GeoERA project (The GARAH, H2020 grant #731166 lead by GEUS).</p>

scholarly journals 3D basin and petroleum system modelling of the NW German North Sea (Entenschnabel)

2017 ◽  
Vol 8 (1) ◽  
pp. 67-86 ◽  
Author(s):  
Jashar Arfai ◽  
Rüdiger Lutz
Keyword(s):  
Heat Flow ◽  
North Sea ◽  
Late Jurassic ◽  
Upper Jurassic ◽  
Lower Jurassic ◽  
Petroleum System ◽  
Source Rocks ◽  
System Modelling ◽  
Gas Field ◽  
Posidonia Shale

Abstract3D basin and petroleum system modelling covering the NW German North Sea (Entenschnabel) was performed to reconstruct the thermal history, maturity and petroleum generation of three potential source rocks, namely the Namurian–Visean coals, the Lower Jurassic Posidonia Shale and the Upper Jurassic Hot Shale.Modelling results indicate that the NW study area did not experience the Late Jurassic heat flow peak of rifting as in the Central Graben. Therefore, two distinct heat flow histories are needed since the Late Jurassic to achieve a match between measured and calculated vitrinite reflection data. The Namurian–Visean source rocks entered the early oil window during the Late Carboniferous, and reached an overmature state in the Central Graben during the Late Jurassic. The oil-prone Posidonia Shale entered the main oil window in the Central Graben during the Late Jurassic. The deepest part of the Posidonia Shale reached the gas window in the Early Cretaceous, showing maximum transformation ratios of 97% at the present day. The Hot Shale source rock exhibits transformation ratios of up to 78% within the NW Entenschnabel and up to 20% within the Central Graben area. The existing gas field (A6-A) and oil shows in Chalk sediments of the Central Graben can be explained by our model.

Overview of conventional hydrocarbon resources in the North Sea Basin – harmonization of assessments, cross-border play mapping and new concepts

2020 ◽  
Author(s):  
Susanne Nelskamp ◽  
Margaret Steward ◽  
Niels Schovsbo ◽  
Stefan Ladage ◽  
Stefan Peeters ◽  
...  
Keyword(s):  
North Sea ◽  
System Modelling ◽  
Multiple Use ◽  
Offshore Area ◽  
Horizon 2020 ◽  
Cross Border ◽  
The North ◽  
New Concepts ◽  
Potential Risk Factors ◽  
The North Sea

<p>A cross-border assessment study looking at selected hydrocarbon systems is conducted as part of the EU Horizon 2020 GeoERA project (GARAH H2020 grant #731166 lead by GEUS). Within this project the geological surveys of the Netherlands (TNO), Germany (BGR), the United Kingdom (BGS) and Denmark (GEUS) are working together to create an overview of hydrocarbon resources and potential plays in the North Sea Basin. The project will harmonize the available resource assessments, and take a closer look at the play systems and potential new concepts. The focus of the work is on resolving border issues and identifying play concepts that are successful in one country but are underexplored in others. Potential risk factors related to subsurface exploration and production as well as options for multiple use of the subsurface will also be included in the overview. The results of the project will be published in report and GIS format and made available to legislators as well as the public.</p><p>Other parts of the project include the assessment of unconventional hydrocarbon plays (see Schovsbo et al. this conference), detailed basin and petroleum system modelling of a case study area in the Danish-German-Dutch offshore area (Lutz et al. this conference) and a pan-European database for gas hydrates (Léon et al. this conference).</p>

Triassic mudstones of the Central North Sea: cross-border characterization, correlation and their palaeoclimatic significance

2020 ◽  
pp. SP494-2019-61
Author(s):  
Stuart G. Archer ◽  
Tom McKie ◽  
Steven D. Andrews ◽  
Anne D. Wilkins ◽  
Matt Hutchison ◽  
...  
Keyword(s):  
North Sea ◽  
Large Scale ◽  
Regional Scale ◽  
Climatic Conditions ◽  
Fluvial Systems ◽  
Correlation Lengths ◽  
Cross Border ◽  
The Uk ◽  
Stratigraphic Nomenclature ◽  
Central North Sea

AbstractThe Triassic of the Central North Sea is a continental succession that contains prolific hydrocarbon-bearing fluvial sandstone reservoirs stratigraphically partitioned by mudstones. Within the Skagerrak Formation of the UK sector, hydrocarbon accumulations in the Judy, Joanne and Josephine Sandstone members are top sealed by the Julius, Jonathan and Joshua Mudstone members, respectively. However, UK and Norwegian stratigraphic correlations have been problematical for decades, largely due to biostratigraphic challenges but also due to the non-uniqueness of the lithotypes and because the cross-border stratigraphic nomenclature differs and has yet to be rationalized. This study focuses on mudstones rather than sandstones to unify cross-border correlation efforts at a regional scale. The mudstone members have been characterized by integrating sedimentological, petrophysical and geophysical data. The facies are indicative of playa lakes that frequently desiccated and preserved minor anhydrite. These conditions alternated with periods of marshy, palustrine conditions favourable for the formation of dolostones. Regional correlations have detected lateral facies changes in the mudstones which are important for their seismically mappable extents, resulting palaeogeographies and, ultimately, their competency as intraformational top seals. Significant diachroneity is associated with the lithological transitions at sandstone–mudstone member boundaries and although lithostratigraphic surfaces can be used as timelines over short distances (e.g. within a field), they should not be assumed to represent timelines over longer correlation lengths. Palaeoclimatic trends are interpreted and compared to those of adjacent regions to test the extent and impact of climate change as a predictive allogenic forcing factor on sedimentation. Mudstone member deposition occurred as a result of the retreat of large-scale terminal fluvial systems during a return to more arid ‘background’ climatic conditions. The cause of the member-scale climatic cyclicity observed within the Skagerrak Formation may be related to volcanic activity in large igneous provinces which triggered the episodic progradation of fluvial systems.

AN EARLY CRETACEOUS SOURCE ROCK IN THE KENDREW TERRACE, DAMPIER SUB-BASIN?

1996 ◽  
Vol 36 (1) ◽  
pp. 477 ◽  
Author(s):  
S. Ryan-Grigor ◽  
C. M. Griffiths
Keyword(s):  
Source Rock ◽  
North Sea ◽  
Early Cretaceous ◽  
Late Jurassic ◽  
Large Scale ◽  
Free Water ◽  
Organic Content ◽  
Source Rocks ◽  
The North ◽  
Northern North Sea

The Early to Middle Cretaceous is characterised worldwide by widespread distribution of dark shales with high gamma ray readings and high organic contents defined as dark coloured mudrocks having the sedimentary, palaeoecological and geochemical characteristics associated with deposition under oxygen-deficient or oxygen-free bottom waters. Factors that contributed to the formation of the Early to Middle Cretaceous 'hot shales' are: rising sea-level, a warm equable climate which promoted water stratification, and large scale palaeogeographic features that restrict free water mixing. In the northern North Sea, the main source rock is the Late Jurassic to Early Cretaceous Kimmeridge Clay/Draupne Formation 'hot shale' which occurs within the Viking Graben, a large fault-bounded graben, in a marine environment with restricted bottom circulation and often anaerobic conditions. Opening of the basin during a major trans-gressive event resulted in flushing, and deposition of normal open marine shales above the 'hot shales'. The Late Callovian to Berriasian sediments in the Dampier Sub-basin are considered to have been deposited in restricted marine conditions below a stratified water column, in a deep narrow bay. Late Jurassic to Early Cretaceous marine sequences that have been cored on the North West Shelf are generally of moderate quality, compared to the high quality source rocks of the northern North Sea, but it should be noted that the cores are from wells on structural highs. The 'hot shales' are not very organic-rich in the northern Dampier Sub-basin and are not yet within the oil window, however seismic data show a possible reduction in velocity to the southwest in the Kendrew Terrace, suggesting that further south in the basin the shales may be within the oil window and may also be richer in organic content. In this case, they may be productive source rocks, analogous to the main source rock of the North Sea.

scholarly journals Petroleum System Modelling of the Akri-Bijeel Oil Field, Northern Iraq: Insights From 1-Dimensional Basin Modelling

2020 ◽  
Vol 4 (2) ◽  
pp. 35-47
Author(s):  
Rzger Abdula ◽  
Hema Hassan ◽  
Maryam Sliwa
Keyword(s):  
Lower Cretaceous ◽  
Vitrinite Reflectance ◽  
Petroleum System ◽  
Oil Field ◽  
Source Rocks ◽  
Reservoir Rock ◽  
Maturity Stage ◽  
System Modelling ◽  
Northern Iraq ◽  
High Maturity

The petroleum system of the Akri-Bijeel oil field shows that the Palaeogene formations such as the Kolosh Formation seem to be immature. However, the Jurassic–Lower Cretaceous source rocks such as those from the Chia Gara, Naokelekan, and Sargelu formations are thermally mature and within the main oil window because their vitrinite reflectance (Ro%) values are >0.55%. The Triassic Kurra Chine and Geli Khana formations are thought to be in the high maturity stage with Ro values ≥1.3% and within the wet and dry gas windows, whereas the older formations are either within the dry gas zone or completely generated hydrocarbon stage and depleted after the hydrocarbons were expelled with subsequent migration to the reservoir rock of the structural traps.

The hydraulic actuation of multi-body structures through large scale motions. Part 1: Development and validation of system model

2008 ◽  
Vol 222 (2) ◽  
pp. 181-193
Author(s):  
D T Branson ◽  
P S Keogh ◽  
D G Tilley
Keyword(s):  
Hydraulic System ◽  
Large Scale ◽  
Controller Design ◽  
System Model ◽  
Modular System ◽  
System Modelling ◽  
Structural Components ◽  
Independent Manner ◽  
Damping Matrix ◽  
Non Linear

Modern engineering design is leading towards structures that are complex and lightweight. These structures often contain flexible and rigid components actuated through large displacements by a non-linear hydraulic system. Due to the increased system complexities, there is a need to define structural models that can be easily coupled to models of the hydraulic system for use in the design of suitable controllers. The current paper develops a modular system model composed of rigid and flexible structural components coupled directly to a non-linear hydraulic system. The resulting model allows for changes to be made to the hydraulic and structural components in an independent manner such that the entire system may be incorporated in a single simulation domain. A structural damping matrix is introduced that allows a control system designer to assign realistic modal damping ratios to well established modes, and higher damping to modes with significant uncertainty. This allows for increased steady-state accuracy and model run-time efficiency, which is beneficial to the controller design process presented in Part 2. The system modelling approach is applied to a hydraulically actuated experimental rig for validation purposes.

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