scholarly journals 3D Petroleum Systems Model using Restored Paleo-Geometries

2014 ◽  
Author(s):  
C. Castagnac ◽  
E. Mavridou ◽  
G. Badalini ◽  
M. Moktar Mohamed ◽  
S. Ahmed Mousa ◽  
...  
Keyword(s):  
Petroleum Systems ◽  
Systems Model

Petroleum systems of the Bass Basin: a 3D modelling perspective

2010 ◽  
Vol 50 (1) ◽  
pp. 511 ◽  
Author(s):  
Natt Arian ◽  
Peter Tingate ◽  
Richard Hillis ◽  
Geoff O'Brien
Keyword(s):  
Middle Eastern ◽  
Source Rocks ◽  
Petroleum Systems ◽  
Systems Model ◽  
Basin Scale ◽  
Exploration Risk ◽  
New Locations ◽  
Petroleum Generation ◽  
And Migration ◽  
Hydrocarbon Expulsion

Petroleum generation, expulsion, migration and accumulation have been modelled in 3D at basin-scale for the Bass Basin, Tasmania. The petroleum systems model shows several source rocks of different ages have generated and expelled sufficient hydrocarbons to fill structures in the basin; however, the lithologies and fault properties in the model result in generally limited migration after hydrocarbon expulsion started. Impermeable faults, together with several fine-gained sealing facies in the Lower and Middle Eastern View Group (EVG) have resulted in minor vertical hydrocarbon migration in the lower parts of the EVG. An exception occurs in the northeastern part of the basin, where strike-slip movement of suitably oriented faults during Miocene reactivation resulted in breaches in deeper accumulations and migration to upper reservoir sands and, in several cases, leakage through the regional seal. The Middle Eastern View Group source rocks have produced most of the gas in the basin. Oil appears to be largely limited to the Yolla Trough, related to the relatively high thermal maturation of Narimba Sequence source rocks. In general, most of the hydrocarbon expelled from the Otway Megasequence occurred prior to the regional seal being deposited; however, modelling predicts it can contribute to the hydrocarbon inventory of the Cape Wickham Sub-basin. In particular, the modelling predicted an Otway sourced accumulation at the site of the recently drilled Rockhopper–1. In the Durroon Sub-basin in the Bark Trough, the Otway Megasequence is predicted to be the main source of accumulations. The modelling has provided detailed insights into migration in the existing plays and has allowed assessment of the reasons for previous exploration failures (e.g., a migration shadow at Toolka–1) and to suggest new locations with viable migration histories. Reservoir sands of the Upper EVG are only prospective in the Yolla and Cormorant troughs where charged by Early Eocene sources; however, Miocene reactivation is a major exploration risk in this area.

A NEW REGIONAL PETROLEUM SYSTEMS MODEL FOR CENTRAL ITALY AND THE CENTRAL ADRIATIC SEA SUPPORTED BY BASIN MODELLING AND AN ANALYSIS OF HYDROCARBON OCCURRENCES

2021 ◽  
Vol 44 (4) ◽  
pp. 461-485
Author(s):  
Lorenzo Lipparini ◽  
Andrea D'Ambrosio ◽  
Fabio Trippetta ◽  
Sabina Bigi ◽  
Jan Federik Derks ◽  
...  
Keyword(s):  
Adriatic Sea ◽  
Central Italy ◽  
Petroleum Systems ◽  
Basin Modelling ◽  
Systems Model

Exploring for the Future—a new oil and gas frontier in northern Australia

2020 ◽  
Vol 60 (2) ◽  
pp. 703
Author(s):  
Paul Henson ◽  
David Robinson ◽  
Lidena Carr ◽  
Dianne S. Edwards ◽  
Susannah K. MacFarlane ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Rock Properties ◽  
Geochemical Data ◽  
Seismic Line ◽  
Petroleum Systems ◽  
Systems Model ◽  
The Future ◽  
Territory Government ◽  
Analytical Tools ◽  
Systems Framework

Exploring for the Future (EFTF) is a four-year, AU$100.5 million initiative from the Australian Government conducted by Geoscience Australia in partnership with state and Northern Territory government agencies, CSIRO and universities to provide new geoscientific datasets for frontier regions. As part of this program, Geoscience Australia acquired two new seismic surveys that collectively extend across the South Nicholson Basin (L120 South Nicholson seismic line) and into the Beetaloo Sub-basin of the McArthur Basin (L212 Barkly seismic line). Interpretation of the seismic has resulted in the discovery of new basins that both contain a significant section of presumed Proterozoic strata. Integration of the seismic results with petroleum systems geochemistry, structural analyses, geochronology, rock properties and a petroleum systems model has expanded the knowledge of the region for energy exploration. These datasets are available through Geoscience Australia’s newly developed Data Discovery Portal: an online platform delivering digital geoscientific information, including seismic locations and cross-section images, and field site and well based sample data. Specifically for the EFTF energy project, a petroleum systems framework with supporting organic geochemical data has been built to access source rock, crude oil and natural gas datasets via interactive maps, graphs and analytical tools that enable the user to gain a better and faster understanding of a basin’s petroleum prospectivity.

Shale oil and gas resource evaluation through 3D basin and petroleum systems modelling: a case study from the East Midlands, onshore UK

2020 ◽  
Vol 26 (4) ◽  
pp. 525-543
Author(s):  
F. Palci ◽  
A. J. Fraser ◽  
M. Neumaier ◽  
T. Goode ◽  
K. Parkin ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Homogeneous Layer ◽  
Shale Oil ◽  
Horizontal Drilling ◽  
Considerable Uncertainty ◽  
Petroleum Systems ◽  
Systems Model ◽  
Technological Advances ◽  
East Midlands ◽  
The Uk

Technological advances in horizontal drilling and hydraulic fracturing have led to a re-evaluation of the UK Carboniferous sequences for shale oil and gas potential. In the Gainsborough Trough, hemipelagic mudstones known collectively as the Bowland Shale were deposited during the Pendleian Substage (Late Mississippian). In this study the interpretation of heritage 2D and recent 3D seismic data allowed the reconstruction of the tectonic evolution of the basin, which was simulated in a 3D basin and petroleum systems model. The model enabled the first prediction of generated, adsorbed, retained and expelled hydrocarbon volumes. Between 8 and 26 Bbbl of STOIIP, and between 11 and 38 tcf of GIIP have been estimated to lie within the Bowland Shale in the Gainsborough Trough. However, at the present time, there is considerable uncertainty concerning these in-place volumes, and no tests have proven the recoverability of oil and gas from the Bowland Shale in this area. Importantly, the Bowland Shale has been modelled as a single homogeneous layer, and the in situ volume numbers need to be corrected for a net to gross factor, once the criteria required for the definition for net reservoir in this formation are better understood.

scholarly journals Utilization of grey madm methodology in technology attractiveness assessment: a case study in upstream industry

2020 ◽  
Vol 11 (7) ◽  
pp. 2872-2887
Author(s):  
Azadeh Dabbaghi
Keyword(s):  
Technology Assessment ◽  
Model Building ◽  
Resource Scarcity ◽  
Assessment Process ◽  
Petroleum Systems ◽  
Systems Model ◽  
Drilling Tools ◽  
Nano Coating ◽  
Overall Evaluation

Technology assessment help managers to accomplish an overall evaluation of technologic options and to identify investment priorities. Making such priority has become of great importance owing to ever-increasing costs of technological research and development and resource scarcity. Technology Attractiveness Assessment, as a primary step of Technology assessment process, has been considered in this paper. Based on the multi-criteria decision-making approach and because of the inherent uncertainty in the preference information on attributes, a Grey-MADM based methodology has been utilized in this paper to assess the technology attractiveness and rank the upstream industry technological options. Its application to a real case problem has been described step by step. The results of the case study showed that "Nano Coating for Drilling Tools", "Petroleum Systems Model Building" and "Integrated Asset Modelling" are the most attractive upstream technologies.

Redefining the relationship between the oil company and its vendor

2020 ◽  
Vol 60 (2) ◽  
pp. 424
Author(s):  
Clare E. Davies ◽  
Tristan Allen ◽  
Craig E. Dempsey ◽  
Kunal Mishra
Keyword(s):  
Broad Band ◽  
Time Frame ◽  
Seismic Survey ◽  
Team Members ◽  
Petroleum Systems ◽  
Systems Model ◽  
Project Coordinator ◽  
The Us ◽  
Seismic Acquisition ◽  
Scheduled Time

During 2016, BHP committed to produce a petroleum systems model for the complete Exmouth Sub-basin area; such a model would require knowledge of the sub-basin’s evolution through time and a uniquely qualified team to deliver within the agreed time frame. Existing seismic coverage rarely illuminated the deepest portion of the basin; however, through a collaboration with WesternGeco Multiclient, a basin-wide broad-band 3D seismic survey was acquired to underpin the new study to ensure its success. To facilitate this acquisition and the development of the petroleum systems model, BHP and WesternGeco Multiclient created a virtual world-wide team to combine their expertise of seismic acquisition and processing, seismic and potential field interpretation, geochemistry and basin modelling. Although the work was coordinated in Perth (WA, Australia), team members were located in Australia, Europe and the US, where particular specific expertise was located. Both companies made a commitment before the commencement of the project to have open exchange of data, interpretations and knowledge transfer, with one project coordinator. Although individual contributors were located in Australia, Europe and the US, monthly video or telephone coordination meetings combined with weekly meetings between individual specialists, as needed, allowed for the project to be completed to the highest technical quality within the scheduled time frame. The collaborative interpretation from this new seismic data and the resulting petroleum system model has created significant value for both companies, with insights benefiting the industry as a whole as a result of this redefined relationship between company and vendor.

Petroleum systems analysis of the northern Houtman Sub-basin

2017 ◽  
Vol 57 (2) ◽  
pp. 755 ◽  
Author(s):  
Lisa Hall ◽  
Emmanuelle Grosjean ◽  
Irina Borissova ◽  
Chris Southby ◽  
Ryan Owens ◽  
...  
Keyword(s):  
Systems Analysis ◽  
Source Rocks ◽  
Rock Properties ◽  
Hydrocarbon Generation ◽  
Petroleum Systems ◽  
Systems Model ◽  
Potential Source ◽  
Lithospheric Extension ◽  
Half Graben ◽  
Potential Field Modelling

Interpretation of newly acquired seismic data in the northern Houtman Sub-basin (Perth Basin) suggests the region contains potential source rocks similar to those in the producing Abrolhos Sub-basin. The regionally extensive late Permian–Early Triassic Kockatea Shale has the potential to contain the oil-prone Hovea Member source interval. Large Permian syn-rift half-graben, up to 10 km thick, are likely to contain a range of gas-prone source rocks. Further potential source rocks may be found in the Jurassic–Early Cretaceous succession, including the Cattamarra Coal Measures, Cadda shales and mixed sources within the Yarragadee Formation. This study investigated the possible maturity and charge history of these different source rocks. A regional pseudo-3D petroleum systems model was constructed using new seismic interpretations. Heat flow was modelled using crustal structure and possible basement composition determined from potential field modelling, and subsidence analysis was used to investigate lithospheric extension through time. The model was calibrated using temperature and maturity data from nine wells in the Houtman and Abrolhos sub-basins. Source rock properties are assigned based on an extensive review of total organic carbon, Rock Eval and kinetic data for the offshore northern Perth Basin. Petroleum systems analysis results show that Permian, Triassic and Early Jurassic source rocks may have generated large cumulative volumes of hydrocarbons across the northern Houtman Sub-basin, whereas the Middle Jurassic–Cretaceous sources remain largely immature. However, the timing of hydrocarbon generation and expulsion with respect to trap formation and structural reactivation is critical for the successful development and preservation of hydrocarbon accumulations.

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