2016 Release Areas

Durroon Sub-basin

Release Area T17-2, offshore Tasmania

Highlights

Bids close on Thursday 19 October 2017

Under-explored rift basin containing a Cretaceous–Cenozoic succession up to 7000 m thick
Two wells drilled in the Release Area
Numerous untested structural and stratigraphic plays
Potential source rocks in Eumeralla Formation (Otway Basin) equivalent coaly rocks
Situated in shallow water (<82 m) close to infrastructure, including the BassGas production facility at the Yolla Field, and southeastern Australian gas markets
This release area is considered to be lightly explored, refer to supporting information
Further guidance available, refer to 2017 Special Notices.

Release Area T17-2 is located in the eastern Bass Basin, covering much of the frontier Durroon Sub-basin and extending into the easternmost Cape Wickham Sub-basin (Figure 1). The Release Area is located approximately 60 km east of the producing Yolla Field (BassGas Project) in the Cape Wickham Sub-basin, and is traversed by the Gippsland–Tasmania gas pipeline. The data coverage for the Release Area is shown in Figure 2. Only two wells—Chat 1 and Durroon 1—have been drilled in the Durroon Sub-basin, and the region has a moderately good coverage of mostly 2D seismic data.

The Cretaceous–Cenozoic Bass Basin is a northwest-trending, intracratonic rift basin that underlies Bass Strait between northern Tasmania and southern Victoria. The Bass Basin is separated from the Otway and Sorell basins to the west by the King Island High, and from the Gippsland Basin to the northeast by Flinders Island and the Bassian Rise. The Bass Basin is divided into the Cape Wickham Sub-basin in the west and the Durroon Sub-basin in the east (Blevin et al, 2005). While the Cape Wickham Sub-basin is a proven hydrocarbon province, hosting several gas discoveries and a producing gas and condensate field (Yolla), the Durroon Sub-basin is underexplored, and no discoveries have been made in this portion of the Bass Basin.

The Durroon Sub-basin is characterised by a series of northwest- to north-northwest-trending half graben bounded by northeast-dipping faults, and these half graben are generally narrower and more intensely faulted than those in the western part of the basin (Blevin, 2003b). The sub-basin contains a Cretaceous–Cenozoic rift and post-rift succession up to 7000 m thick (Baillie and Pickering, 1991).

Two Early Cretaceous rift phases can be identified across the Durroon Sub-basin (Figure 3, Figure 4). The first, in the Barremian–earliest Cenomanian, was coeval with extension in the adjacent Otway Basin and resulted in deposition of the non-marine Otway Megasequence (Blevin, 2003b). Where intersected in Durroon 1, it comprises stacked fluvial channel sands interbedded with thin, coaly overbank–floodplain shales (Figure 5). A second phase of extension (Durroon Rift Phase) affected the basin during the Turonian–Campanian, driven by Tasman Basin rifting to the east. Half graben initiated in the previous rifting phase continued to develop and expand, forming a system of linked depocentres (Blevin et al, 2005). Thick shales within the megasequence are interpreted to have been deposited in deep, freshwater lacustrine environments (Blevin et al, 2005; Partridge, 2003).

Extension had generally ceased by the mid-Campanian and until the late early Eocene, deposition took place within an internal drainage basin, with fluvial systems feeding into the slowly subsiding depocentres from the uplifted basin flanks (DITR, 2004). Due to erosion, the upper Paleocene–lower Eocene coaly succession that is known to have sourced hydrocarbon accumulations in the Cape Wickham Sub-basin (Aroo Sequence; Boreham et al, 2003) is either poorly developed or absent in the Durroon Sub-basin (Blevin et al, 2005).

The overlying middle Eocene–lower Oligocene Flinders Sequence is an overall transgressive–regressive succession deposited in shallow bay to open marine environments (Blevin et al, 2005). Massive sandstone units near the top of the sequence are assigned to the Boonah Formation, which is generally considered the top reservoir unit across most of the Bass Basin. The uppermost unit of the Flinders Sequence, the “Demons Bluff Shale”, is regarded as the regional seal; in the Durroon Sub-basin it is generally thin and relatively coarse-grained (Blevin et al, 2005; Figure 5). The Flinders Sequence is overlain unconformably by marine strata of the upper Oligocene–Holocene Torquay Sequence. The Durroon Sub-basin was only mildly affected by the Oligocene and younger magmatic events that characterise the Cape Wickham Sub-basin (Blevin et al, 2005).

Petroleum systems elements

Durroon Sub-basin

Sources	Barremian–Albian coaly facies of the Otway Megasequence, equivalent to Eumeralla Formation of the Otway Basin Maastrichtian–lower Paleocene coals and shales (generally immature)
Reservoirs	Sandstone units in the upper Otway Megasequence Sandstone units in the Campanian–Eocene Bass Megasequence and Flinders Sequence
Seals	Deep-water lacustrine shales in the Upper Cretaceous Durroon Megasequence Overbank shales in the Lower Cretaceous Otway Megasequence Shales within the Eocene–Oligocene Flinders Sequence and the overlying Torquay Sequence
Traps	Rotated fault blocks with structural closure extending in to onlapping and overlying strata Stratigraphic traps in sandy facies along eastern basin margin and lacustrine and deltaic facies associated with the Durroon Lake near the base of the Durroon Megasequence.

Infrastructure and markets

The Bass Basin is an established gas and condensate producing province that services the southeastern Australian energy market. Release Area T17-2 is close to the Yolla Field, which commenced production in 2006. The greater Melbourne region is one of Australia’s largest domestic gas markets and is supported by major petroleum refineries.

Critical risks

The main exploration risks in the Durroon Sub-basin relate to maturity of source rocks, hydrocarbon charge, preservation of accumulations, and the presence of good quality reservoir and seal facies.

A key prospectivity risk in the Durroon Sub-basin is the maturity of potential source rocks in areas where the basin fill is less than 3000 m thick. Mature source rocks are likely to be present only within the deepest parts of the half graben. Given the compartmentalised nature of the Lower Cretaceous depocentres where potential source rocks accumulated, and likely early generation and expulsion from those source rocks (Arian et al, 2010), the volume and timing of charge are also considered to be key exploration risks. Cummings and Tingate (2003) suggested that generation and expulsion from potential source rocks within the Otway Megasequence was driven by rapid deposition of the Durroon Megasequence in the Turonian–Campanian. Although the sub-basin has not undergone significant deformation since that time, uplift and erosion associated with the Durroon Unconformity (early–middle Eocene) may have implications for the preservation of early accumulations. Biodegradation of accumulations in shallow middle–upper Eocene reservoirs is also a potential risk.

Due to the paucity of drilling, the extent, distribution and quality of intraformational reservoir and seal facies within the Otway and Durroon megasequences are poorly understood.

Well control

Durroon 1 (1972)

Durroon 1 (Figure 5), drilled in 1972 by Esso Exploration and Production Australia Ltd, was the first well to test the sedimentary succession and petroleum potential of the eastern Bass Basin. The well targeted a rotated fault block with onlapping and draping strata with anticlinal closure. Previous drilling in the western Bass Basin, along with regional correlations and onshore geology, suggested that the age of the deeper basin succession would range from Permian to Early Cretaceous. However, drilling confirmed the section to be much younger than predicted, with the oldest sediment penetrated being Aptian in age (Esso, 1973); the well reached a total depth of 3024 mKB. The overlying Cenozoic succession was encountered essentially as predicted, although it consisted of largely coarse- to medium-grained siliciclastic sediments. The “Eocene Shale” (or “Demons Bluff Shale”), considered a regional seal in the western Bass Basin, was largely absent at the Durroon 1 well. No significant hydrocarbons were encountered in Durroon 1 or interpreted from well logs, although numerous small indications of gas (maximum reading of C1 = 0.7%) were recorded from 1000 mKB to TD (Trigg, 2003). Well failure was attributed to minimal structural closure, poor regional sealing facies and a lack of hydrocarbon charge. The well was plugged and abandoned.

Chat 1 (1986)

Chat 1 was drilled by Bridge Oil Ltd in early 1986. The well targeted a large fault block with overlying anticlinal closure located near the western boundary of the Durroon Sub-basin. The primary objective of the well was to test the hydrocarbon potential of the Upper Cretaceous to Oligocene succession, in particular the Paleocene section. The well reached a total depth of 3104 m in volcanic rocks underlying Maastrichtian–Campanian strata. No significant hydrocarbon shows were encountered at Chat 1 during drilling, nor were any indicated from log analysis. Some traces of gas and oil were observed at 2450 m depth (Bridge Oil, 1986).

Post-drill analysis suggests the well was a valid structural test. The well intersected good quality reservoir, sealing and potential source facies. Well failure was attributed to the lack of mature source rocks, access to hydrocarbon charge or possible trap breach. A fluid inclusion study by Kempton et al. (2002) identified a potential palaeo-hydrocarbon zone, characterised by aqueous inclusions containing small amounts of oil, within Eocene sands at Chat 1. These sands occur near the top of structural closure at the well, within an interval affected by late stage reactivation faulting.

Data

Data relating to the Release Areas can be accessed through the National Offshore Petroleum Information Management System (NOPIMS), an online data discovery and delivery system for all Australian offshore petroleum wells and seismic surveys at http://www.ga.gov.au/nopims

Marine and Environment

Release Area T17-2 characteristics

Release Area T17-2 is approximately 230 km in width and is located in Bass Strait in water depths of approximately 40-80 m. The area lies 10.2 km north of Tasmania’s northern coastline and 82 km south of Wilsons Promontory, Victoria. The closest island is Waterhouse Island, 5.5 km south of the Release Area’s southeastern boundary. The Flinders Island group is located 30–40 km to the east of the area. The closest industrial ports are Devonport and Bell Bay.
Offshore Durroon Sub-Basin and shelf sediments are typically comprise over 60–90% calcium carbonate (Passlow et al, 2004). Sand dominates the seafloor throughout the Release Area, with mud (<63%) increasing towards the west, and gravel (up to 30%) in the eastern third of the Release Area (MARS, 2017).
Hazards: idal sand waves have been mapped 5 km east of the Release Area (Malikides et al, 1988, 1989). Some turbidite activity has been forecast in the far western end, and further west, of the Release Area (Li et al, 2007).

Commonwealth marine reserves

Release Area T17-2 is located 35 km south of the Beagle Commonwealth Marine Reserve (CMR), and 122 km east of Boags CMR.

There are no Tasmanian state marine reserves near the Release Area.

Key ecological features

There are no key ecological features in the Release Area (Department of Environment and Energy, 2017).

Biologically important areas

Release Area T17-2 overlaps, or is close to, the following biologically important areas (Department of Environment and Energy, 2017). The Release Area:

Overlaps with the foraging area for seabirds including the Shy, Indian Yellow-nose, Black-browed, Buller’s, Campbell and Wandering
Is north of known Southern Right Whale connecting habitat in shallow coastal waters. This generally occurs between May and November, although some whales stay year round.
Overlaps a known Pygmy Blue Whale foraging area through the Bass Strait migratory corridor.
Overlaps with the White Shark known distribution area and breeding nursery area, in autumn, winter and spring.

Table 1 Breeding periods (b) for key seabirds whose foraging areas are adjacent or overlapping to the Release Area.

Jan

Feb

Mar

Apr

May

Jun

Jul

Aug

Sept

Oct

Nov

Dec

Common Diving Petrel

Little Penguin

Short-tailed Shearwater

The Atlas of Living Australia (www.ala.org.au) provides further information on animals and plants recorded from the release area, including Threatened or Listed Species.

Heritage

There are a number of shipwrecks located in and surrounding the area. Wrecks located within the Release Area include:

Martha and Jane, a schooner wrecked in 1878, located at -40.62°, 146.01°
Eagle, a motor launch wrecked in 1904, located at -40.53°, 146.76°
Elizabeth, a schooner wrecked in 1847, located at -40.741°, 146.769°
Pride of the Tamar, a steamer, wrecked in 1875, located at, -40.15°,146.91°
Maile, a schooner wrecked in 1893, located at -40.63°, 147.46°
J. H. Astell, a dredge wrecked in 1968, located at -40.69°, 146.75°

There are currently no native title claims in Tasmania.

References and Information Resources

National Conservation Values Atlas http://www.environment.gov.au/webgis-framework/apps/ncva/ncva.jsf

Boags Commonwealth Marine Reserve https://www.environment.gov.au/topics/marine/marine-reserves/south-east/boags

Beagle Commonwealth Marine Reserve https://www.environment.gov.au/topics/marine/marine-reserves/south-east/beagle

Atlas of Living Australia http://www.ala.org.au/

Geoscience Australia Marine Sediments http://dbforms.ga.gov.au/pls/www/npm.mars.search

Fisheries http://www.afma.gov.au/fisheries/ and http://dpipwe.tas.gov.au/sea-fishing-aquaculture/commercial-fishing

Shipwrecks http://www.environment.gov.au/heritage/historic-shipwrecks

Marine Sediments (MARS) database http://dbforms.ga.gov.au/pls/www/npm.mars.search

Geoscience Australia products

Regional geology and seismic

Petroleum geology inventory of Australia’s offshore frontier basins. Geoscience Australia Record by Totterdell et al, 2014
Australian southern margin synthesis, Project GA707. A report to Geoscience Australia by Blevin and Cathro, 2008
Petroleum geology of the Bass Basin: interpretation report. Geoscience Australia Record by Blevin, 2003
An audit of petroleum exploration wells in the Bass Basin: 1965–1999. Geoscience Australia Record by Trigg et al, 2003
Bass Basin basic data compilation. Geoscience Australia record by Blevin et al, 2003
Regional potential field interpretation report, Bass Basin. Geoscience Australia Report by Teasdale et al, 2003

Stratigraphy

Review and compilation of open file micropalaeontology and palynology data from offshore Tasmania. Geoscience Australia Record by Partridge et al, 2003
Bass Basin biozonation and stratigraphy chart, 1998, Chart 17. Australian Geological Survey Organisation Chart by Shafik et al, 1998

Petroleum systems and accumulations

The Oils of Eastern Australia. Geoscience Australia Report by Summons et al, 2002
South-eastern Australia Surface Geochemistry II: Light Hydrocarbon Geochemistry in Bottom-waters of the Gippsland Basin, Eastern Otway Basin, Torquay Sub-basin and the Durroon Sub-basin. Vols 1 and 2. Australian Geological Survey Organisation Record by Bishop et al, 1992
Australian Petroleum Accumulations Report 2: Bass Basin, Tasmania and Victoria. Bureau of Mineral Resources Report by Ozimic et al, 1987
Petroleum potential of the Bass Basin. AGSO Journal of Australian Geology & Geophysics article by Nicholas et al, 1981

Search for these and other Geoscience Australia reports and products at www.ga.gov.au/search

Contact Geoscience Australia Client Services for more information: phone +61 (0)2 6249 9966, email clientservices@ga.gov.au

References

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