scholarly journals Lithospheric evolution, thermo-tectonic history and source-rock maturation in the Gippsland Basin, Victoria, southeastern Australia

2021 ◽  
pp. 1-30
Author(s):  
J. Röth ◽  
A. Parent ◽  
C. Warren ◽  
L. S. Hall ◽  
D. Palmowski ◽  
...  
Keyword(s):  
Source Rock ◽  
Southeastern Australia ◽  
Tectonic History ◽  
Gippsland Basin ◽  
Lithospheric Evolution

Mass Transport Complexes on a Cenozoic paleo-shelf edge, Gippsland basin, southeastern Australia

2018 ◽  
Vol 98 ◽  
pp. 783-801 ◽  
Author(s):  
P.E. O'Brien ◽  
C.H. Mitchell ◽  
D. Nguyen ◽  
R.P. Langford
Keyword(s):  
Mass Transport ◽  
Shelf Edge ◽  
Southeastern Australia ◽  
Gippsland Basin

FORTESCUE RESERVOIR DEVELOPMENT AND RESERVOIR STUDIES

1985 ◽  
Vol 25 (1) ◽  
pp. 95
Author(s):  
S.T. Henzell ◽  
H.R. Irrgang ◽  
E.J. Janssen ◽  
R.A.H. Mitchell ◽  
G.O. Morrell ◽  
...  
Keyword(s):  
Oil Recovery ◽  
History Matching ◽  
Three Dimensional ◽  
Two Phase ◽  
Aquifer System ◽  
Southeastern Australia ◽  
Drainage Patterns ◽  
Stock Tank ◽  
Well Pattern ◽  
Gippsland Basin

The Fortescue field in the Gippsland Basin, offshore southeastern Australia is being developed from two platforms (Fortescue A and Cobia A) by Esso Australia Ltd. (operator) and BHP Petroleum.The Fortescue reservoir is a stratigraphic trap at the top of the Latrobe Group of sediments. It overlies the western flank of the Halibut and Cobia fields and is separated from them by a non-net sequence of shales and coals which form a hydraulic barrier between the two systems. Development drilling into the Fortescue reservoir commenced in April 1983 with production coming onstream in May 1983. Fortescue, with booked reserves of 44 stock tank gigalitres (280 million stock tank barrels) of 43° API oil, is the seventh major oil reservoir to be developed in the offshore Gippsland Basin by Esso/BHP.In mid-1984, after drilling a total of 20 exploration and development wells, and after approximately one year of production, a detailed three-dimensional, two-phase reservoir simulation study was performed to examine the recovery efficiency, drainage patterns, pressure performance and production rate potential of the reservoir.The model was validated by history matching an extensive suite of Repeat Formation Test (RFT)* pressure data. The results confirmed the reserves basis, and demonstrated that the ultimate oil recovery from the reservoir is not sensitive to production rate.This result is consistent with studies on other high quality Latrobe Group reservoirs in the Gippsland Basin which contain undersaturated crudes and receive very strong water drive from the Basin-wide aquifer system. With the development of the simulation model during the development phase, it has been possible to more accurately define the optimal well pattern for the remainder of the development.* Mark of Schlumberger

A NEW MODEL FOR THE MID-CRETACEOUS STRUCTURAL HISTORY OF THE NORTHERN GIPPSLAND BASIN

1991 ◽  
Vol 31 (1) ◽  
pp. 143 ◽  
Author(s):  
D.C. Lowry ◽  
I.M. Longley
Keyword(s):  
Early Cretaceous ◽  
Late Cretaceous ◽  
Second Phase ◽  
Northern Flank ◽  
Tectonic History ◽  
Structural History ◽  
Intermittent Compression ◽  
History Of ◽  
Transfer Faults ◽  
Gippsland Basin

The tectonic history of the northern flank of the offshore Gippsland Basin can be divided into three phases:an Early Cretaceous rift phase (120-98 Ma) with deposition of the Strzelecki Group and extension in a northeast-southwest direction.a mid-Cretaceous phase (98-80 Ma) with deposition of the Golden Beach Group and extension in a northwest- southeast direction anda Late Cretaceous to Tertiary sag phase with intermittent compression or wrenching.Previous workers have described the first and third phases. This paper argues for a distinctive second phase with extension at right angles to the first phase. The complex Cretaceous structure in the Kipper-Hammerhead area is interpreted in terms of a model in which transfer faults of the first phase became domino faults of the second phase.

PETROLEUM RESOURCES OF OFFSHORE SOUTHEASTERN AUSTRALIA

1975 ◽  
Vol 15 (2) ◽  
pp. 55
Author(s):  
Ian McPhee
Keyword(s):  
Oil And Gas ◽  
Full Potential ◽  
Deep Basin ◽  
Reservoir Rocks ◽  
Sedimentary Sequences ◽  
Southeastern Australia ◽  
Petroleum Resources ◽  
Giant Fields ◽  
Gippsland Basin ◽  
Great Australian Bight

THE GIPPSLAND Basin is established as a prolific producer of oil and gas from a number of giant fields and other major discoveries are yet to be developed. Further discoveries can be expected in this petroliferous basin which has good future exploration potential. The Bass Basin has been disappointing as commercial discoveries have eluded the explorers. However source and reservoir rocks are present and the basin has future promise if the key to the nature of accumulations can be found. The Otway and Great Australian Bight Basins cover a vast area and include very thick potential source formations and good reservoir facies. Thick sedimentary sequences in the deep basin have been little explored and no significant shows encountered. The basins have potential but there are exploration difficulties to be overcome before full potential can be understood.

APPROACHES TO PALAEOGEOGRAPHIC RECONSTRUCTIONS OF THE LATROBE GROUP, GIPPSLAND BASIN, SOUTHEASTERN AUSTRALIA

2005 ◽  
Vol 45 (1) ◽  
pp. 581 ◽  
Author(s):  
T. Bernecker ◽  
A.D. Partridge
Keyword(s):  
Co2 Storage ◽  
Depositional Environments ◽  
Petroleum Systems ◽  
Fine Grained ◽  
Southeastern Australia ◽  
Depositional System ◽  
Facies Associations ◽  
Marine Fossils ◽  
Coal Accumulation ◽  
Gippsland Basin

In the Gippsland Basin, the seaward extent of paralic coal occurrences can be mapped in successive time slices through the Paleocene and Eocene to provide a series of straight to gently arcuate surrogate palaeoshorelines within the petroliferous Latrobe Group. Palaeogeographic reconstructions that incorporate this information provide a unique perspective on the changes affecting a siliciclastic depositional system on a passive continental margin where basin development has been primarily controlled by thermal sag. In contrast, the absence of calcareous marine fossils and lack of extensive, widespread and thick fine-grained sediments on the marine shelf and continental slope, beyond the seaward limits of coal accumulation, have contributed to the false impression that the Latrobe Group accumulated in a largely non-marine basin. Based on the proposed model for palaeoshoreline delineation, seismic data, sequence analysis, petrography and palynology can be integrated to subdivide the main depositional environments into distinct facies associations that can be used to predict the distribution of petroleum systems elements in the basin. The application of such palaeogeographic models to the older section of the Latrobe Group can improve the identification of these petroleum systems elements in as yet unexplored parts of the Gippsland Basin. Given the recent attention paid to the basin as a CO2 storage province, palaeogeographic interpretations may be able to assist with the selection of appropriate injection sites.

scholarly journals New small-bodied ornithopods (Dinosauria, Neornithischia) from the Early Cretaceous Wonthaggi Formation (Strzelecki Group) of the Australian-Antarctic rift system, with revision ofQantassaurus intrepidusRich and Vickers-Rich, 1999

2019 ◽  
Vol 93 (3) ◽  
pp. 543-584 ◽  
Author(s):  
Matthew C. Herne ◽  
Jay P. Nair ◽  
Alistair R. Evans ◽  
Alan M. Tait
Keyword(s):  
Phylogenetic Analysis ◽  
Early Cretaceous ◽  
Rift System ◽  
Micro Ct ◽  
Internal Anatomy ◽  
Vertebrate Fauna ◽  
Southeastern Australia ◽  
Gippsland Basin

AbstractThe Flat Rocks locality in the Wonthaggi Formation (Strzelecki Group) of the Gippsland Basin, southeastern Australia, hosts fossils of a late Barremian vertebrate fauna that inhabited the ancient rift between Australia and Antarctica. Known from its dentary,Qantassaurus intrepidusRich and Vickers-Rich, 1999 has been the only dinosaur named from this locality. However, the plethora of vertebrate fossils collected from Flat Rocks suggests that further dinosaurs await discovery. From this locality, we name a new small-bodied ornithopod,Galleonosaurus dorisaen. gen. n. sp. from craniodental remains. Five ornithopodan genera are now named from Victoria.Galleonosaurus dorisaen. gen. n. sp. is known from five maxillae, from which the first description of jaw growth in an Australian dinosaur is provided. The holotype ofGalleonosaurus dorisaen. gen. n. sp. is the most complete dinosaur maxilla known from Victoria. Micro-CT imagery of the holotype reveals the complex internal anatomy of the neurovascular tract and antorbital fossa. We confirm thatQ. intrepidusis uniquely characterized by a deep foreshortened dentary. Two dentaries originally referred toQ. intrepidusare reassigned toQ.?intrepidusand a further maxilla is referred to cf.Atlascopcosaurus loadsiRich and Rich, 1989. A further ornithopod dentary morphotype is identified, more elongate than those ofQ. intrepidusandQ.?intrepidusand with three more tooth positions. This dentary might pertain toGalleonosaurus dorisaen. gen. n. sp. Phylogenetic analysis recovered Cretaceous Victorian and Argentinian nonstyracosternan ornithopods within the exclusively Gondwanan clade Elasmaria. However, the large-bodied taxonMuttaburrasaurus langdoniBartholomai and Molnar, 1981 is hypothesised as a basal iguanodontian with closer affinities to dryomorphans than to rhabdodontids.UUID:http://zoobank.org/4af87bb4-b687-42f3-9622-aa806a6b4116

Plate tectonic history, basin development and petroleum source rock deposition onshore China

1987 ◽  
Vol 4 (3) ◽  
pp. 205-225 ◽  
Author(s):  
M.P. Watson ◽  
A.B. Hayward ◽  
D.N. Parkinson ◽  
Zh.M. Zhang
Keyword(s):  
Source Rock ◽  
Plate Tectonic ◽  
Tectonic History ◽  
Basin Development ◽  
Petroleum Source Rock

GEOLOGIC EVOLUTION AND HYDROCARBON HABITAT GIPPSLAND BASIN

1972 ◽  
Vol 12 (1) ◽  
pp. 132 ◽  
Author(s):  
J. Barry Hocking
Keyword(s):  
Late Cretaceous ◽  
Upper Cretaceous ◽  
Meteoric Water ◽  
Oil And Gas ◽  
Basin Evolution ◽  
Fold Belt ◽  
Apparent Lack ◽  
Northern Flank ◽  
Southeastern Australia ◽  
Gippsland Basin

The Gippsland Basin of southeastern Australia is a post-orogenic, continental margin type of basin of Upper Cretaceous-Cainozoic age.Gippsland Basin evolution can be traced back to the establishment of the Strzelecki Basin, or ancestral Gippsland Basin, during the Jurassic. Gippsland Basin sedimentation commenced in the middle to late Cretaceous and is represented as a gross transgressive-regressive cycle consisting of the continental Latrobe Valley Group (Upper Cretaceous to Eocene or Miocene), the marine Seaspray Group (Oligocene to Pliocene or Recent), and finally the continental Sale Group (Pliocene to Recent).The hydrocarbons of the Gippsland Shelf petroleum province were generated within the Latrobe Valley Group and are trapped in porous fluvio-deltaic sandstones of the Latrobe. At Lakes Entrance, however, oil and gas are present in a marginal sandy facies of the Lakes Entrance Formation (Seaspray Group).The buried Strzelecki Basin has played a fundamental role in the development and distribution of the Cainozoic fold belt in the northern Gippsland Basin. The Gippsland Shelf hydrocarbon accumulations fall within this belt and are primarily structural traps. The apparent lack of structural accumulations onshore in Gippsland is largely due to a Plio-Pleistocene episode of cratonic uplift that was accompanied by basinward tilting of structures and meteoric water influx.The non-commercial Lakes Entrance field, located on the stable northern flank of the basin, is a stratigraphic trap and may serve as a guide for future exploration.

FOSSIL RESIN BIOMARKERS AND THEIR APPLICATION IN OIL TO SOURCE-ROCK CORRELATION, GIPPSLAND BASIN, AUSTRALIA

1987 ◽  
Vol 27 (1) ◽  
pp. 63 ◽  
Author(s):  
R. Alexander ◽  
R.A. Noble ◽  
R.I. Kagi
Keyword(s):  
Organic Matter ◽  
Source Rock ◽  
Relative Abundance ◽  
Genetic Relationships ◽  
Crude Oils ◽  
Chemical Markers ◽  
Uniform Distributions ◽  
Fossil Resin ◽  
Gippsland Basin ◽  
Fossil Resins

Diterpanes occur widely in the resins of modern conifers, suggesting that sedimentary diterpanes are chemical markers for fossil resins, particularly those derived from conifers. In this paper, the use of the relative abundance of these chemical fossils for establishing genetic relationships between the organic matter in sediments and crude oils has been demonstrated using sediments and crude oils from the Gippsland Basin.The crude oils were characterised by their remarkably uniform distributions of diterpanes and similar relative amounts of diterpanes and hopanes. In contrast, the sediments showed much greater variability, with only one sediment horizon, an organic-rich shale, showing the same properties as the crude oils.

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