PATTERNS OF DIAGENESIS IN SOME AUSTRALIAN SEDIMENTARY BASINS

1977 ◽  
Vol 17 (1) ◽  
pp. 58 ◽  
Author(s):  
M. Shibaoka ◽  
A. J. R. Bennett
Keyword(s):  
Sedimentary Basins ◽  
Hydrocarbon Generation ◽  
Liquid Hydrocarbons ◽  
Geological Time ◽  
Oil Generation ◽  
History Of ◽  
And Migration ◽  
Gippsland Basin ◽  
Reflectance Data ◽  
Generation Activity

Three characteristic types of Australian sedimentary basins can be recognized on the basis of depth-reflectance curves. These may be designated as the Cooper, Sydney, and Gippsland Basin types. Characteristic depth-reflectance curves allow an assessment of the depositional and tectonic histories of sedimentary basins to be made. If the geological history and especially the stratigraphy of a basin is well known, it is possible to estimate the maturity which coal or kerogen would have attained at any past or present time. This maturity would be expressed by particular reflectance values of vitrinite. By making actual measurements of vitrinite and kerogen reflectance, the model of maturation can be tested. In this way it has been possible, for a number of basins, to estimate the geological period in which liquid hydrocarbons were generated and the rate at which the maturation process proceeded. The formation of an accumulation of oil is a matter of balance between the supply and loss of oil to and from traps, as well as persistence of traps and migration paths through geological time. The lapse of time after oil generation and the rate of generation are thus most important. The above-mentioned three types of sedimentary basins differ in these respects. Reflectance data can therefore be used not only to estimate the present state of organic maturity, but also in conjunction with the history of sedimentation in the basin, to interpret hydrocarbon generation activity in geological time.

Hydrocarbon charge history of the Gippsland Basin

2010 ◽  
Vol 50 (2) ◽  
pp. 729
Author(s):  
Keyu Liu ◽  
Peter Eadington ◽  
David Mills ◽  
Richard Kempton ◽  
Herbert Volk ◽  
...  
Keyword(s):  
System Analysis ◽  
Evaluation Research ◽  
Petroleum System ◽  
Additional Information ◽  
Oil Generation ◽  
History Of ◽  
And Migration ◽  
Hydrocarbon Charge ◽  
Gas Fields ◽  
Gippsland Basin

As part of a larger petroleum system analysis and resource re-evaluation research program in the Gippsland Basin, over 400 samples from 29 selected wells in the Gippsland Basin were investigated using quantitative fluorescence techniques developed by CSIRO Petroleum, including the quantitative grain fluorescence (QGF) and QGF on extracts (QGF-E) and the total scanning fluorescence (TSF) techniques. Preliminary results have provided new insight into the hydrocarbon migration and charge history of the Gippsland Basin. The investigation has revealed: widespread occurrence of palaeo oil columns in some of the major gas fields, indicating that a significant amount of oil was charged into these reservoirs prior to a subsequent gas accumulation; that some of the current oil intervals appear to have received a relatively late oil charge, either through new charge or through palaeo oil re-distribution due to adjustments within the petroleum system; palaeo oil columns appear to be restricted to a certain distance range from the major source kitchens; and, evidence of a sequential oil migration and displacement along structural highs where reservoirs distal to the source kitchens received progressively lighter and more mature palaeo oils. These findings are consistent with the oil generation and migration model proposed by O’Brien et al (2008). Fluid inclusion petrographic investigations and molecular composition of inclusions (MCI) analysis are currently underway that will provide additional information on the hydrocarbon charge history in the Gippsland 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.

SUPPRESSED VITRINITE REFLECTANCE AND ITS EFFECT ON THERMAL HISTORY MODELLING IN THE BARROW AND DAMPIER SUB-BASINS.

1996 ◽  
Vol 36 (1) ◽  
pp. 428 ◽  
Author(s):  
A. R. Kaiko ◽  
P. R. Tingate
Keyword(s):  
Vitrinite Reflectance ◽  
Thermal Conditions ◽  
Thermal Gradients ◽  
History Analysis ◽  
Oil Generation ◽  
Petroleum Generation ◽  
And Migration ◽  
Uplift And Erosion ◽  
Timing Of Onset ◽  
Reflectance Data

The Barrow and Dampier Sub-basins form an important offshore petroleum province containing major oil discoveries associated with Triassic to Cretaceous reservoirs and source reeks. Constraining the timing cf oil generation and migration within the sub-basins has been hampered by difficulties in assessing thermal maturity using vitrinite reflectance data. Jurassic-Cretaceous formations of predominantly marine origin yield vitrinite reflectance values that are often lower than expected compared to the present day thermal conditions. The two main explanations put forward by workers for this situation are that:a recent increase in thermal gradients has occurred; orthe vitrinite reflectance is suppressed, and this suppression is related to the marine environment of deposition.Thermal history analysis of 65 wells throughout the Barrow and Dampier Sub-basins has confirmed, using multiple maturity parameters, that vitrinite reflectance data are suppressed over large parts of the study area.Thermal history modelling and the confirmation of vitrinite reflectance suppression has enabled revised estimates of pr esent maturity to be made. Maturity levels based on measured reflectance data and values calculated from thermal information exhibit large differences, related to suppression; up to 1,500 m in the depth to the 0.7 per cent R(1 iso-reflectance surface. Vitrinite reflectance suppression, if not taken into account, also strongly affects modelling of uplift and erosion, and the timing of onset of maturity for petroleum generation. Variations of up to 100 Ma have been noted between histories based on measured vitrinite reflectance and those taking vitrinite reflectance suppression into account.

Thermal History and Hydrocarbon Maturity Study in the Norton Basin, Alaska

1992 ◽  
Vol 10 (6) ◽  
pp. 402-421 ◽  
Author(s):  
Z. Yu ◽  
Y. Li ◽  
I. Lerche
Keyword(s):  
Fluid Flow ◽  
Late Miocene ◽  
Thermal Gradient ◽  
Vitrinite Reflectance ◽  
Hydrocarbon Generation ◽  
One Dimensional ◽  
Thermal Peak ◽  
Initial Stage ◽  
History Of ◽  
Reflectance Data

Two COST wells in the Norton Basin of Alaska were examined using a one-dimensional quantitative dynamic model (1-D). By inversion of vitrinite reflectance data with the present day thermal gradient in the basin, the paleothermal history of the basin was reconstructed and showed two high thermal peaks, one during the initial stage of basin development (60–50 MaBP) and the other at late Miocene (15–5 MaBP). The early thermal peak corresponded to thinning of the lithosphere and subsidence with upwelling of the hot asthenosphere, and the more recent thermal high was caused by the subsidence and volcanic activity during late Miocene. The Norton Basin is thermally mature with hydrocarbon generation occurring in 15–2 MaBP. Modeling the fluid flow and geopressure development using a two-dimensional fluid flow/compaction model in the basin shows that the directions of fluid movement are both vertical and towards the Yukon Horst, a main horst structure in the basin, suggesting that the hydrocarbons might accumulate in structures around the Yukon Horst and in stratigraphic traps within the basin, which are expected to be common because of the depositional variation of the various facies.

The Variscan thermal history of west Clare, Ireland

1994 ◽  
Vol 131 (4) ◽  
pp. 545-558 ◽  
Author(s):  
E. Fitzgerald ◽  
M. Feely ◽  
J. D. Johnston ◽  
G. Clayton ◽  
L. J. Fitzgerald ◽  
...  
Keyword(s):  
Fluid Inclusion ◽  
Vitrinite Reflectance ◽  
Sedimentary Basins ◽  
Fluid Migration ◽  
Burial History ◽  
Vertical Movements ◽  
Quartz Veins ◽  
History Of ◽  
Exploration Well ◽  
Reflectance Data

AbstractVitrinite reflectance data from Namurian rocks in west Clare suggest that high maturation levels, corresponding to palaeotemperatures of 340–370 °C, were attained prior to Variscan deformation. Fluid inclusions in syntectonic quartz veins homogenize between 330 °C and 50 °C with an accompanying decrease in salinity from 27 to 5 eq. wt % NaCl. Maximum fluid inclusion entrapment temperatures ranged from more than 300 °C to 250 °C during Variscan folding in County Clare. The observed maturation levels (c. 7.5% Rmax) far exceed values for simple burial maturation based on the estimated burial history and ‘normal’ geothermal gradients, and do not increase with depth in the Doonbeg No. 1 exploration well. Fluid advective heating is suggested as the most likely mechanism consistent with the Clare reflectance and thermometric data. Vein and shear zone dimensions preclude rapid vertical movements of hot fluids through the section, and extensive lateral fluid migration from sedimentary basins undergoing tectonically driven dewatering to the south or west is therefore proposed.

HYDROCARBON PROSPECTIVITY OF THE DEEPWATER GIPPSLAND BASIN, VICTORIA, AUSTRALIA

2001 ◽  
Vol 41 (1) ◽  
pp. 91 ◽  
Author(s):  
T. Bernecker ◽  
M.A. Woollands ◽  
D. Wong ◽  
D.H. Moore ◽  
M.A. Smith
Keyword(s):  
Source Rock ◽  
Oil And Gas ◽  
Data Sets ◽  
Hydrocarbon Generation ◽  
The North ◽  
Potential Source Rock ◽  
Exploration And Production ◽  
Modelling Studies ◽  
History Of ◽  
Gippsland Basin

After 35 years of successful exploration and development, the Gippsland Basin is perceived as a mature basin. Several world class fields have produced 3.6 billion (109) BBL (569 GL) oil and 5.2 TCF (148 Gm3) gas. Without additional discoveries, it is predicted that further significant decline in production will occur in the next decade.However, the Gippsland Basin is still relatively underexplored when compared to other prolific hydrocarbon provinces. Large areas are undrilled, particularly in the eastern deepwater part of the basin. Here, an interpretation of new regional aeromagnetic and deep-water seismic data sets, acquired through State and Federal government initiatives, together with stratigraphic, sedimentological and source rock maturation modelling studies have been used to delineate potential petroleum systems.In the currently gazetted deepwater blocks, eight structural trapping trends are present, each with a range of play types and considerable potential for both oil and gas. These include major channel incision plays, uplifted anticlinal and collapsed structures that contain sequences of marine sandstones and shales (deepwater analogues of the Marlin and Turrum fields), as well as large marine shale-draped basement horsts.The study has delineated an extensive near-shore marine, lower coastal plain and deltaic facies association in the Golden Beach Subgroup. These Late Cretaceous strata are comparable to similar facies of the Tertiary Latrobe Siliciclastics and extend potential source rock distribution beyond that of previous assessments. In the western portion of the blocks, overburden is thick enough to drive hydrocarbon generation and expulsion. The strata above large areas of the source kitchen generally dip to the north and west, promoting migration further into the gazetted areas.Much of the basin’s deepwater area, thus, shares the deeper stratigraphy and favourable subsidence history of the shallow water producing areas. Future exploration and production efforts will, however, be challenged by the 200–2500 m water-depths and local steep bathymetric gradients, which affect prospect depth conversion and the feasibility of development projects in the case of successful exploration.

TIMING CONSTRAINTS ON THE STRUCTURAL HISTORY OF THE WESTERN OTWAY BASIN AND IMPLICATIONS FOR HYDROCARBON PROSPECTIVITY AROUND THE MORUM HIGH, SOUTH AUSTRALIA

2003 ◽  
Vol 43 (1) ◽  
pp. 59 ◽  
Author(s):  
I.R. Duddy ◽  
B. Erout ◽  
P.F. Green ◽  
P.V. Crowhurst ◽  
P.J. Boult
Keyword(s):  
Late Cretaceous ◽  
Vitrinite Reflectance ◽  
South Australia ◽  
Source Rocks ◽  
Hydrocarbon Generation ◽  
Seismic Line ◽  
Late Paleocene ◽  
History Of ◽  
And Migration ◽  
Uplift And Erosion

Reconstructed thermal and structural histories derived from new AFTA Apatite Fission Track Analysis, vitrinite reflectance and (U-Th)/He apatite dating results from the Morum–1 well, Otway Basin, reveal that the Morum High is a mid-Tertiary inversion structure. Uplift and erosion commencing in the Late Paleocene to mid-Eocene (57–40 Ma) removed around 1,500 m of sedimentary section. The eroded section is attributed to the Paleocene- Eocene Wangerrip Group which is considered to have been deposited in a major depocentre in the vicinity of the present Morum High. This depocentre is interpreted to have been one of a number of transtensional basins developed at the margin of the Morum Sub-basin and adjacent to the Tartwaup Hinge Zone and Mussel Fault during the Early Tertiary. The Portland Trough in Victoria represents a similar depocentre in which over 1,500 m of Wangerrip Group section, mostly represented by deltaic sediments of the Early Eocene Dilwyn Formation, is still preserved.Quantification of the maximum paleotemperature profile in Morum–1 immediately prior to Late Paleocene to mid-Eocene inversion shows that the paleo-geothemal gradient at the time was between 21 and 31°C/km, similar to the present-day level of 29°C/km, demonstrating that there has been little change in basal heat flow since the Early Tertiary.Reconstruction of the thermal history at the Trumpet–1 location reveals no evidence for any periods of significant uplift and erosion, demonstrating the relative stability of this part of the Crayfish Platform since the Late Cretaceous.The thermal and burial histories at Morum–1 and Trumpet–1 have been used to calibrate a Temis2D hydrocarbon generation and migration model along seismic line 85-13, encompassing the Crayfish Platform, Morum High and Morum Sub-basin. The model shows the cessation of active hydrocarbon generation from Eumeralla Formation source rocks around the Morum High due to cooling at 45 Ma (within the range 57–40 Ma) resulting from uplift and erosion of a Wangerrip Group basin. There has been almost no hydrocarbon generation from the Eumeralla Formation beneath the Crayfish Platform.Migration of hydrocarbons generated from the Eumeralla Formation began in the Late Cretaceous in the Morum Sub-basin and is predicted to continue to the present day, with the potential for accumulations in suitably placed reservoirs within the Late Cretaceous package both within the Morum Sub-basin and at the southern margin of the Crayfish Platform.

Thermal diagenesis in the Swiss molasse basin: implications for oil generation

1982 ◽  
Vol 19 (2) ◽  
pp. 328-342 ◽  
Author(s):  
F. Monnier
Keyword(s):  
Organic Matter ◽  
Clay Mineral ◽  
Maximum Level ◽  
Hydrocarbon Generation ◽  
Molasse Basin ◽  
Burial History ◽  
Oil Generation ◽  
History Of ◽  
Mixed Layers ◽  
Mineral Transformations

Clay mineral transformations during burial are indicators of the degree of diagenesis of sediments. Diagenetic zonations in numerous wells of the Swiss molasse basin are defined by the disappearance of smectite and (or) the appearance of either corrensite or irregular 2:1 mixed layers. The maximum level attained in the thickest molasse sections corresponds to organic matter maturation suitable for hydrocarbon generation. Reconstructed on the basis of the clay mineral transformation data, a burial history of the basin is proposed.

Afterword: The Littoral Museum of the Twenty-First Century

2021 ◽  
Vol 73 (2) ◽  
pp. 237-254
Author(s):  
Morgane Cadieu
Keyword(s):  
First Century ◽  
Special Issue ◽  
Women's Labor ◽  
Geological Time ◽  
Marine Life ◽  
War Memorials ◽  
Key Concepts ◽  
History Of ◽  
Twenty First Century ◽  
And Migration

Abstract The museum, the mausoleum, and the memorial are key concepts for theorizing beaches and ports in twenty-first-century literature and cinema. On the littoral, these constructions suggest the very opposite of a sealed off monumentality to become living museums of women’s labor in modern and contemporary France (Sciamma, Varda), bodily mausolea of migration on the Senegalese shoreline (Diop), and shapeshifting war memorials in Atlantic and Pacific tidelands (Darrieussecq, Rolin, Virilio). Examples of anamorphic seascapes, especially in photography, underscore the reversibility of sand and cement in Japan (Narahashi, Ono), as well as the dereliction of Cuban beach architecture and American industrial harbors (Morales, Sekula). In art as in criticism, the waterfront stages gender and class crossings (Dumont) and tangles fields. The afterword thereby weaves the major threads of the special issue: textures, labor, and ruins; social mobility and migration; marine life, geological time, and the history of sensation.

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