Petroleum potential and kinetic models for hydrocarbon generation from the Upper Cretaceous to Paleogene Latrobe Group coals and shales in the Gippsland Basin, Australia

2016 ◽  
Vol 91 ◽  
pp. 54-67 ◽  
Author(s):  
Soumaya Abbassi ◽  
Dianne S. Edwards ◽  
Simon C. George ◽  
Herbert Volk ◽  
Nicolaj Mahlstedt ◽  
...  
Keyword(s):  
Kinetic Models ◽  
Upper Cretaceous ◽  
Hydrocarbon Generation ◽  
Petroleum Potential ◽  
Gippsland Basin

GIFFSLAND HYDROCARBONS - A PERSPECTIVE FROM THE BASIN EDGE

1984 ◽  
Vol 24 (1) ◽  
pp. 91 ◽  
Author(s):  
J. G. Stainforth
Keyword(s):  
Heat Flow ◽  
Upper Cretaceous ◽  
Oil And Gas ◽  
Source Rocks ◽  
Hydrocarbon Generation ◽  
Lower Tertiary ◽  
Late Tertiary ◽  
Carbonaceous Shales ◽  
Basin Edge ◽  
Gippsland Basin

Permit VIC/P19 lies palaeogeographically seaward of the main producing part of the Gippsland Basin. Deposition of the Latrobe Group commenced with volcanics and continental 'rift-stage' sediments during the Late Cretaceous. This phase was succeeded first by paludal sedimentation in the failed rift during the Campanian and Maastrichtian, and then by cyclic paralic sedimentation during the Paleocene and Eocene.Analysis of the hydrocarbons recovered during recent exploration of permit VIC/P19 shows that they were sourced from moderately mature coals and carbonaceous shales in the Campanian/-Maastrichtian paludal sequence.A maturation model that assumes elevated but decreasing heat flow, related to sea-floor spreading, produces an excellent fit to the observed maturity data and predicts a long history of hydrocarbon generation during the Tertiary. The maturity of the Upper Cretaceous source sequence depends more on the thickness of the overlying Lower Tertiary clastic Latrobe sediments than on the thickness of the Upper Tertiary carbonate wedge. The Late Tertiary phase of burial had relatively little effect on maturation because of its rapidity and the lower heat flow and higher thermal conductivities of the deeper sequence at the time. Overpressures in mature Upper Cretaceous source rocks, resulting from hydrocarbon generation, have driven pore fluids, including hydrocarbons, laterally up-dip into normally pressured reservoirs.The main oil province of the Gippsland Basin has a greater thickness of Lower Tertiary than has VIC/P19. As a result, source rocks are more mature there, and became wholly so by the end of deposition of the Latrobe Group. This facilitated charge of traps at the top of the Latrobe Group, which contain most of the oil and gas discovered to date in the Basin.

scholarly journals Oil generation from coal source rocks: the influence of depositional conditions and stratigraphic age

2005 ◽  
Vol 7 ◽  
pp. 9-12 ◽  
Author(s):  
Henrik I. Petersen
Keyword(s):  
North Sea ◽  
Liquid Hydrocarbon ◽  
Source Rocks ◽  
Hydrocarbon Generation ◽  
Oil Generation ◽  
Generation Capacity ◽  
The Subject ◽  
Coal Composition ◽  
Gippsland Basin ◽  
Australasian Region

Although it was for many years believed that coals could not act as source rocks for commercial oil accumulations, it is today generally accepted that coals can indeed generate and expel commercial quantities of oil. While hydrocarbon generation from coals is less well understood than for marine and lacustrine source rocks, liquid hydrocarbon generation from coals and coaly source rocks is now known from many parts of the world, especially in the Australasian region (MacGregor 1994; Todd et al. 1997). Most of the known large oil accumulations derived from coaly source rocks have been generated from Cenozoic coals, such as in the Gippsland Basin (Australia), the Taranaki Basin (New Zealand), and the Kutei Basin (Indonesia). Permian and Jurassic coal-sourced oils are known from, respectively, the Cooper Basin (Australia) and the Danish North Sea, but in general only minor quantities of oil appear to be related to coals of Permian and Jurassic age. In contrast, Carboniferous coals are only associated with gas, as demonstrated for example by the large gas deposits in the southern North Sea and The Netherlands. Overall, the oil generation capacity of coals seems to increase from the Carboniferous to the Cenozoic. This suggests a relationship to the evolution of more complex higher land plants through time, such that the highly diversified Cenozoic plant communities in particular have the potential to produce oil-prone coals. In addition to this overall vegetational factor, the depositional conditions of the precursor mires influenced the generation potential. The various aspects of oil generation from coals have been the focus of research at the Geological Survey of Denmark and Greenland (GEUS) for several years, and recently a worldwide database consisting of more than 500 coals has been the subject of a detailed study that aims to describe the oil window and the generation potential of coals as a function of coal composition and age.

HYDROCARBON POTENTIAL OF THE MESOZOIC AND BASAL TERTIARY OF THE GIPPSLAND BASIN: A STRATIGRAPHIC ANALYSIS

1972 ◽  
Vol 12 (1) ◽  
pp. 138 ◽  
Author(s):  
T. R. Haskell
Keyword(s):  
Upper Cretaceous ◽  
Sedimentary Rocks ◽  
Economic Potential ◽  
The West ◽  
Stratigraphic Analysis ◽  
Structural Framework ◽  
Marine Influence ◽  
Gippsland Basin ◽  
North And South ◽  
Early Upper

A thick sequence of uppermost Jurassic, Cretaceous and basal Tertiary non-marine sedimentary rocks underlies the Gippsland area of Victoria. The older part of this sequence is extensively exposed in the west of the Gippsland area, but elsewhere it is known dominantly from well intersections. Although several hiates are recognised, palynological data indicate that a comparatively complete Cretaceous section can be compiled from this sequence in the Gippsland area.The uppermost Jurassic to Paleocene rocks can be divided into three units. The oldest unit is uppermost Jurassic and Lower Cretaceous in age. It consists of variably compacted greywackes and lithic sandstones, minor arkoses and interbedded siltstones and mudstones. The overlying early Upper Cretaceous and Paleocene units are distinguishable paleontologically and consist of quartzose sandstones, carbonaceous siltstones and mudstones.There is no indication of marine influence on sedimentation present in the microfossil content of any of the palynotogical preparations from samples taken throughout most of the sequence. Several species of microplankton are common in the oldest unit, but they are indicative of the lacustrine conditions under which the unit was deposited.Minor hydrocarbon shows have been recorded from the oldest unit, but the sandstones are characteristically tight. More significant shows have been reported from the two younger units that contain relatively clean sandstones interbedded with siltstones and mudstones. These units possess the greatest economic potential of all of the pre-Eocene rocks of the Gippsland Basin.The structural framework of the region is composed of separate series of north-easterly and easterly trending faults or monoclines and a south-easterly regional dip. Differential movements of blocks defined by this fault-monocline pattern appears to have resulted in erosion of the more prospective early Upper Cretaceous and Paleocene strata from all but two subrectangular areas respectively immediately north and south of Seaspray.

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