The Carribuddy Group and Worral Formation, Canning Basin, Western Australia: reassessment of stratigraphy and petroleum potential

2010 ◽  
Vol 50 (1) ◽  
pp. 425 ◽  
Author(s):  
Peter Haines
Keyword(s):  
Middle Devonian ◽  
Late Ordovician ◽  
Source Rocks ◽  
Local Source ◽  
Petroleum Potential ◽  
Canning Basin ◽  
Petroleum Wells ◽  
Reservoir Potential ◽  
Drill Holes ◽  
Reservoir Facies

Reassessment of stratigraphic relationships and biostratigraphic data pertaining to the Carribuddy Group and Worral Formation in all relevant petroleum wells and many mineral drill holes across the southern Canning Basin has led to the following important results. The Carribuddy Group is restricted to the Late Ordovician to earliest Silurian. The overlying Worral Formation is mostly of Silurian age and does not intertongue with the Middle Devonian Tandalgoo Formation, as previously thought. A thin basin-wide chronostratigraphic marker—the Pegasus Dolomite Member (previously referred to as dolomite spike or dolomite marker) of the Sahara Formation—allows improved correlation between salt-bearing sub-basins and adjacent condensed Carribuddy Group successions. The Mallowa Salt is not as extensive as previously thought; rather the Minjoo Salt thickens to become the only salt seal in the eastern and southern Kidson Sub-basin. The Carribuddy Group forms the regional seal to the prospective Larapintine 2 petroleum system, but also contains local source and reservoir facies. The Bongabinni Formation contains extremely rich oil-prone source rocks in local lagoonal facies along the Admiral Bay Fault Zone; these rocks have been linked by other studies to migrated oil in that area. The distribution of the source facies is poorly known, but it may extend down-dip into more mature parts of the Willara Sub-basin, and west into offshore areas. Other local source units may be present in the Mallowa Salt, and possibly the Nibil Formation, but are not well documented. Aeolian sandstone with excellent reservoir potential is locally present in the Nibil Formation, but is more extensive in the lower Worral Formation, particularly the Elsa Sandstone Member.

THE GEOLOGY AND PETROLEUM POTENTIAL OF THE WESTERN ARAFURA SEA

1990 ◽  
Vol 30 (1) ◽  
pp. 91 ◽  
Author(s):  
Jeanette M. McLennan ◽  
John S. Rasidi ◽  
Richard L. Holmes ◽  
Greg C. Smith
Keyword(s):  
Oil And Gas ◽  
Source Rocks ◽  
Petroleum Potential ◽  
Northern Margin ◽  
The North ◽  
Australian Plate ◽  
North Eastern ◽  
Arafura Sea ◽  
Good Potential ◽  
Reservoir Potential

The northern Bonaparte Basin and the Arafura-Money Shoal Basins lie along Australia's offshore northern margin and offer significantly different exploration prospects resulting from their differing tectonic and burial histories. The Arafura Basin is dominated by a deep, faulted and folded, NW-SE orientated Palaeozoic graben overlain by the relatively flat-lying Jurassic-Tertiary Money Shoal Basin. The north-eastern Bonaparte Basin is dominated by the deep NE-SW orientated Malita Graben with mainly Jurassic to Recent basin-fill.A variety of potential structural and stratigraphic traps occur in the region especially associated with the grabens. They include tilted or horst fault blocks and large compressional, drape and rollover anticlines. Some inversion and possibly interference anticlines result from late Cenozoic collision between the Australian plate and Timor and the Banda Arc.In the Arafura-Money Shoal Basins, good petroleum source rocks occur in the Cambrian, Carboniferous and Jurassic-Cretaceous sequences although maturation is biassed towards early graben development. Jurassic-Neocomian sandstones have the best reservoir potential, Carboniferous clastics offer moderate prospects, and Palaeozoic carbonates require porosity enhancement.The Malita Graben probably contains good potential Jurassic source rocks which commenced generation in the Late Cretaceous. Deep burial in the graben has decreased porosity of the Jurassic-Neocomian sandstones significantly but potential reservoirs may occur on the shallower flanks.The region is sparsely explored and no commercial discoveries exist. However, oil and gas indications are common in a variety of Palaeozoic and Mesozoic sequences and structural settings. These provide sufficient encouragement for a new round of exploration.

Lower Paleozoic stratigraphy and petroleum potential of the Wallal Rift System, southwest Canning Basin, Western Australia

2014 ◽  
Vol 54 (2) ◽  
pp. 521
Author(s):  
Norman Alavi ◽  
Leon Bagas ◽  
Peter Purcell ◽  
Irena Kivior ◽  
John Brett
Keyword(s):  
Source Rocks ◽  
Granitic Rocks ◽  
Large Igneous Province ◽  
Rift System ◽  
Seismic Line ◽  
Lower Paleozoic ◽  
Petroleum Potential ◽  
Continental Flood Basalts ◽  
Canning Basin ◽  
The North

The Wallal Rift System (new name) extends north-northwest for more than 300 km along the southwestern margin of the Canning Basin. The rift contains the Wallal and the Waukarlycarly embayments and the Samphire Graben. The rift segments vary in depth to 4.5 km and are all under-explored. Seismic coverage is better in the north than in the south. Six shallow wildcat and stratigraphic wells in the north provide some control on the age of the pre-Permian section. Another well on the northeastern flank of the Samphire Graben terminated in Neoproterozoic granitic rocks beneath the Lower Ordovician Nambeet Formation. The well is tied to a seismic line that indicates a synrift Ordovician section in the graben. An equivalent section is inferred in the Wallal and the Waukarlycarly embayments, and Permian syn-rift sediments are recognised in all rifts. Transtension along a regional geosuture—the Camel-Tabletop Fault Zone—may have caused initial rifting during the waning of the Paterson Orogeny (c. 550 Ma), co-incident with extrusion in the Kalkarindji Large Igneous Province. Thus, Cambrian volcano-clastics deposits may be present at the base of the (2–3 km thick) pre-Permian section, which is considered to be primarily Early Paleozoic sediments and expected to contain potential source rocks. A relatively hot Proterozoic crust and eruption of continental flood basalts during the Cambrian may have facilitated source rock maturation. Reservoirs may be more common along rift-margins and intra-rift ridges, where fault-controlled traps are also present.

A RE-ASSESSMENT OF THE PETROLEUM POTENTIAL OF THE DARLING BASIN: A DISCOVERY 2000 INITIATIVE

1998 ◽  
Vol 38 (1) ◽  
pp. 278 ◽  
Author(s):  
J.D. Alder ◽  
C. Bembrick ◽  
B. Hartung-Kagi ◽  
B. Mullard ◽  
D.A. Pratt ◽  
...  
Keyword(s):  
Mineral Resources ◽  
Source Rocks ◽  
Petroleum Exploration ◽  
Gas Field ◽  
Petroleum Potential ◽  
South Wales ◽  
1960S And 1970S ◽  
Geochemical Analyses ◽  
The 1960S ◽  
Petroleum Wells

New data, including regional high resolution aeromagnet ic coverage, acquired by the New South Wales Department of Mineral Resources (DMR) as part of its Discovery 2000 Initiative, have provided the first opportunity for a comprehensive review of the regional framework of the Darling Basin. Covering an area of 90,000 km2 in central western NSW, the Darling Basin contains over 8,000 m of mainly Palaeozoic sediments. With only 17 petroleum wells drilled in the basin, mostly during the 1960s and 1970s, and some 1,550 km of modern multifold seismic coverage, the Darling Basin represents one of the major frontier basinal regions of onshore Australia.The initial phase of petroleum exploration was discouraged by the lack of shows, the likelihood of gas-prone source rocks and presence of a thick, red-bed dominated, organically lean, Late Devonian sequence. Renewed interest in the Darling Basin's prospectivity followed from favourable, albeit superficial, comparisons between the Darling Basin and Queensland's Adavale Basin, where commercial gas is produced at the Gilmore Gas Field. Additionally, as part of some $15 million expenditure by the DMR on acquiring new and reassessing old data from the Darling Basin, new geochemical analyses of extracts collected from core holes and out-crop suggest the presence of at least one active Palaeozoic petroleum system. This system has been responsible for generating oil and possibly substantial quantities of gas found dissolved within artesian waters in the overlying shallow Mesozoic sequences.

Reservoir quality assessing and petroleum potential of Nepa horizon in Lena-Tunguska basin

2020 ◽  
pp. 42-50
Author(s):  
E. D. Sivkova ◽  
R. S. Sautkin
Keyword(s):  
Data Interpretation ◽  
Reservoir Quality ◽  
Log Data ◽  
Petroleum Potential ◽  
Gas Saturation ◽  
Tunguska Basin ◽  
Reservoir Potential

Reservoir layers were located within the Nepa horizon according to the log data interpretation of 26 wells. Porosity and gas saturation were calculated within these layers. The research provides an opportunity to determine reservoir potential of sediments and to identify further research lines.

The Yenisei-Khatanga Composite Tectono-Sedimentary Element, Northern Siberia

2021 ◽  
pp. M57-2021-15
Author(s):  
E. V. Deev ◽  
G. G. Shemin ◽  
V. A. Vernikovsky ◽  
O. I. Bostrikov ◽  
P. A. Glazyrin ◽  
...  
Keyword(s):  
Siberian Craton ◽  
Middle Triassic ◽  
Foreland Basin ◽  
Early Carboniferous ◽  
Source Rocks ◽  
Total Thickness ◽  
Petroleum Potential ◽  
Early Paleocene ◽  
Middle Carboniferous ◽  
Severnaya Zemlya

AbstractThe Yenisei-Khatanga Composite Tectono-Sedimentary Element (YKh CTSE) is located between the Siberian Craton and the Taimyr-Severnaya Zemlya fold-and-thrust belt. The total thickness of the Mesoproterozoic-Cenozoic sediments of YKh CTSE reaches 20 to 25 km. They are divided into four tectono-sedimentary elements (TSE): (i) Mesoproterozoic-early Carboniferous Siberian Craton continental margin, (ii) middle Carboniferous-Middle Triassic syn-orogenic Taimyr foreland basin, (iii) late Permian-Early Triassic syn-rift, and (iv) Triassic-Early Paleocene post-rift. The last one is the most important in terms of its petroleum potential and is the most drilled part of the CTSE. Its thickness accounts for half of the total thickness of YKh CTSE. The margins of the post-rift TSE and the inner system of inversion swells and adjacent troughs and depressions were shaped by three tectonic events: (i) middle Carboniferous-Middle Triassic Taimyr orogeny, (ii) Late Jurassic-Early Cretaceous Verkhoyansk orogeny, (iii) Late Cenozoic uplift. These processes led to more intense migration of hydrocarbons, the trap formation and their infill with hydrocarbons. Triassic, Jurassic, and Lower Cretaceous source rocks are mostly gas-prone, and among 20 discovered fields in Jurassic and Cretaceous plays, 17 are gas or mixed-type fields.

An overview of the Ionian zone source rocks and petroleum potential of NW Greece (Ioannina concession block)

First Break ◽  
2014 ◽  
Vol 32 (12) ◽  
Author(s):  
Henry David ◽  
Constantinos Tzimeas ◽  
Paschalia Kiomourtzi ◽  
Panagiotis Konstantopoulos ◽  
George Panagopoulos ◽  
...  
Keyword(s):  
Source Rocks ◽  
Petroleum Potential

AN INTEGRATED GEOLOGICAL AND GEOPHYSICAL INTERPRETATION OF A PORTION OF THE OFFSHORE SYDNEY BASIN, NEW SOUTH WALES

2003 ◽  
Vol 43 (1) ◽  
pp. 495 ◽  
Author(s):  
P.A. Arditto
Keyword(s):  
New South ◽  
Source Rocks ◽  
Reservoir Quality ◽  
Hydrocarbon Generation ◽  
Late Permian ◽  
Early Permian ◽  
South Wales ◽  
Permian Coal ◽  
Coal Measures ◽  
Reservoir Facies

The study area is within PEP 11, which is more than 200 km in length, covers an area over 8,200 km2 and lies immediately offshore of Sydney, Australia’s largest gas and petroleum market on the east coast of New South Wales. Permit water depths range from 40 m to 200 m. While the onshore Sydney Basin has received episodic interest in petroleum exploration drilling, no deep exploration wells have been drilled offshore.A reappraisal of available data indicates the presence of suitable oil- and wet gas-prone source rocks of the Late Permian coal measure succession and gas-prone source rocks of the middle to early Permian marine outer shelf mudstone successions within PEP 11. Reservoir quality is an issue within the onshore Permian succession and, while adequate reservoir quality exists in the lower Triassic succession, this interval is inferred to be absent over much of PEP 11. Quartz-rich arenites of the Late Permian basal Sydney Subgroup are inferred to be present in the western part of PEP 11 and these may form suitable reservoirs. Seismic mapping indicates the presence of suitable structures for hydrocarbon accumulation within the Permian succession of PEP 11, but evidence points to significant structuring post-dating peak hydrocarbon generation. Uplift and erosion of the order of 4 km (based on onshore vitrinite reflectance studies and offshore seismic truncation geometries) is inferred to have taken place over the NE portion of the study area within PEP 11. Published burial history modelling indicates hydrocarbon generation from the Late Permian coal measures commenced by or before the mid-Triassic and terminated during a mid-Cretaceous compressional uplift prior to the opening of the Tasman Sea.Structural plays identified in the western and southwestern portion of PEP 11 are well positioned to contain Late Permian clean, quartz-rich, fluvial to nearshore marine reservoir facies of the coal measures. These were sourced from the western Tasman Fold Belt. The reservoir facies are also well positioned to receive hydrocarbons expelled from adjacent coal and carbonaceous mudstone source rock facies, but must rely on early trap integrity or re-migrated hydrocarbons and, being relatively shallow, have a risk of biodegradation. Structural closures along the main offshore uplift appear to have been stripped of the Late Permian coal measure succession and must rely on mid-Permian to Early Permian petroleum systems for hydrocarbon generation and accumulation.

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