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dc.contributor.advisorHolford, Simon-
dc.contributor.advisorHamilton, Douglas-
dc.contributor.authorHawke, Peter James-
dc.description.abstractThe intracratonic Canning Basin, Western Australia, contains three Palaeozoic petroleum systems (The Larapintine L2, Ordovician – Silurian; The Larapintine L3 and L4, Devonian – early Carboniferous; and the Gondwannan G1 and G2, late Carboniferous – Permian). The NW-SE oriented Fitzroy Trough and Gregory Sub-basin (separated only by the Jones Arch) are the regional source kitchens, and shelfal positions updip from the Fitzroy Trough are oil productive from the Larapintine L3 and L4 petroleum system in fields such as Blina and Sundown, and more recently the Ungani field. A lack of exploration drilling in comparable shelfal positions updip from the Gregory Sub-basin is perceived to account for the absence of similar hydrocarbon discoveries. Through the use of a newly reprocessed regional 2D seismic grid and an enhanced stratigraphic framework produced from well correlations and palaeogeographic reconstructions, it is demonstrated that elements of all of the three petroleum systems are present on the Betty Terrace, Balgo Terrace and within the Billiluna Sub-basin of the northeast Canning Basin. Good quality reservoirs such as the late Devonian Knobby Sandstone (averaging 20.6% porosity and 567 mD permeability), the Tournaisian Laurel Formation (featuring up to 22% porosity), members of Visean-Sakmarian Grant Group (up to 18.5% porosity and 1015 mD permeability), and the Sakmarian Poole Sandstone (in excess of 20% porosity) were intersected in well bores, tied to 2D seismic data and mapped throughout the study area. Stratigraphy with regional seal potential (including Laurel Formation shales, the Grant Group B member, shales of the mid-Carboniferous Anderson Formation and the Permian Noonkanbah Formation) are determined from exploration wells to be present across the project area. A regional geochemical source rock assessment indicates that the Permian Noonkanbah Formation is organically rich (2.17% TOC), and that the pre-Carboniferous stratigraphy (members of Anderson Formation, 0.14% TOC; Laurel Formation, 0.56% TOC; Devonian Gogo Formation, 0.14% TOC; and the Silurian Carribuddy Group Bongabinni Member, 0.13% TOC) are organically lean. The Llanvirn Goldwyer Formation (1.5% TOC) is regionally organically rich, though is unlikely to be found in a basinal palaeogeographic setting within the study area. Thermal maturity was investigated using 1D and 2D petroleum systems models, which determined that (1) the Noonkanbah Formation is immature, and (2) that the pre-Carboniferous source rocks are mature for hydrocarbon generation, reaching peak thermal maturity in the Triassic (200 Ma). 4-way dip closures, 3-way fault bound dip closures, and horst block trapping configurations were identified on 2D seismic, but an analysis of exploratory dry holes indicates that structural closures that developed in the Carboniferous were likely reconfigured during the Triassic Fitzroy Movement, where hydrocarbons leaked out of traps. Modelling indicates that the timing of hydrocarbon generation occurred over two main periods; the Siluro-Devonian (436 Ma – 350 Ma) and in the Triassic (220 Ma – 192 Ma). It is designated that exploration within all three petroleum systems in the project area is considered to be high-risk. It is concluded from this study that the Larapintine L3 and L4 petroleum system represents the best prospectivity in positions nearest the Gregory Sub-basin.en
dc.subjectPetroleum systemsen
dc.subjectPetroleum system modelen
dc.subjectBilliluna Sub-basinen
dc.subjectCanning Basinen
dc.subjectseismic interpretationsedimentologyen
dc.subjectwell log interpretationen
dc.subjectpetroleum explorationen
dc.titleAn evaluation of petroleum systems within the Billiluna Sub-basin and adjacent structural regions, northeastern Canning Basinen
dc.contributor.schoolAustralian School of Petroleumen
dc.provenanceThis electronic version is made publicly available by the University of Adelaide in accordance with its open access policy for student theses. Copyright in this thesis remains with the author. This thesis may incorporate third party material which has been used by the author pursuant to Fair Dealing exceptions. If you are the owner of any included third party copyright material you wish to be removed from this electronic version, please complete the take down form located at:
dc.description.dissertationThesis (MPhil) -- University of Adelaide, Australian School of Petroleum, 2017en
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