2016 Release Areas

Western Exmouth Plateau

Release Area W17-8, offshore Western Australia

Highlights

Bids close on Thursday 19 October 2017

Deep‑water gas province with multi-Tcf gas accumulations
Proximal to Vos, Eendracht, Brederode, Arnhem and Kentish Knock gas accumulations
Deep to ultra-deep water, 1400–3500 m
Triassic fault blocks, stacked reservoirs, reefs, variety of structural/stratigraphic trap styles
Proven gas in wells Alaric 1 and Cadwallon 1
Large lightly explored area with potential for discovery of new plays
This release area is considered to be lightly explored, refer to supporting infromation
Further guidance available, refer to 2017 Special Notices.

Release Area W17-8 (135 graticular blocks) is located over the southwestern Exmouth Plateau, in deep water of ~1400 m atop the plateau, down to ~3500 m along the base of the steep Cuvier Transform margin where it adjoins the Cuvier Abyssal Plain (Figure 1). The western part of the Release Area lies along the Cape Range Fracture Zone defining the southern flank of the Exmouth Plateau. The Vos gas field lies to the south, while the gas fields of Eendracht, Brederode, Arnhem and Kentish Knock lie to the east—all in 1000–1500 m water depths.

The Exmouth Plateau is a deep-water marginal plateau and is the most westerly of the structural elements that constitute the Northern Carnarvon Basin. The plateau is underlain by 10–15 km of flat-lying and tilted, block-faulted Paleozoic to Mesozoic sedimentary rocks, deposited during periods of extension prior to continental breakup in the Middle Jurassic and Early Cretaceous (Figure 2). The Triassic fluvio-deltaic Mungaroo Formation has been the primary exploration target on the Exmouth Plateau for many explorers and acts as both source and reservoir, while Upper Triassic carbonate platforms also have reservoir potential. Other reservoirs include the Upper Triassic Brigadier Formation, the Upper Jurassic Jansz Sandstone and sandstone units within the Lower Cretaceous Barrow Group. The Lower Cretaceous Muderong Shale forms a regional seal. Trap styles present on the Exmouth Plateau include fault-dependent closures and drapes associated with Triassic fault blocks, Upper Triassic pinnacle reefs (Exon et al, 1989), and stratigraphic traps of Late Jurassic (Oxfordian) and Early Cretaceous age (Figure 3).

The Release Area overlies a major north-northeast striking Rhaetian reef/carbonate shelf trend (Grain et al, 2013). Tiberius 1 encountered over 300 m of this limestone succession, characterised by zones of high porosity and permeability. As the succession directly overlies the deeply faulted gas-prone Mungaroo Formation, and is sealed by Lower Cretaceous marine shales, it should be considered as a major play concept.

Figure 4 shows the data coverage on the Exmouth Plateau in the vicinity of the Release Area. There is sparse coverage of 2D seismic with increased density to the east. Most of the eastern half of the Area is covered by 3D seismic survey Claudius 3D MSS. Just to the east of the Area lies 3D seismic surveys Bonaventure 3D MSS and Mary Rose 3D MSS and to the southeast lies Agrippina 3D MSS. Only four exploration wells lie within the Area (Alaric 1, Cadwallon 1, Genseric 1 and Tiberius 1) with additional stratigraphy provided by Vos 1, to the south, and Eendracht 1 and Brederode 1, to the east.

Petroleum systems elements

Western Exmouth Plateau

Sources	Triassic fluvio-deltaic sediments of the Mungaroo Formation Lower Triassic Locker Shale (unproven)
Reservoirs	Lower Cretaceous basin-floor fans and turbidites in the Barrow Group Upper Jurassic upper–lower shoreface Jansz Sandstone Upper Triassic shallow marine-deltaic Brigadier Formation Upper Triassic carbonate reefs (no discoveries to date) Middle-Upper Triassic fluvio-deltaic to marginal marine Mungaroo Formation
Seals	Regional seal Lower Cretaceous marine claystones of the Muderong Shale Lower Triassic Locker Shale (untested) Intraformational seals Lower Cretaceous distal marine claystones of the Barrow Group (Forestier Claystone equivalents) Upper Jurassic condensed marls and claystones of the Dingo Claystone Triassic fluvio-deltaic claystones of the Mungaroo Formation
Traps	Upper Cretaceous turbidite sandstones combined structural and stratigraphic traps Lower Cretaceous basin-floor fan stratigraphic traps Upper Jurassic shoreface sandstone stratigraphic traps Upper Triassic pinnacle reefs (unproven) Tilted Triassic fault blocks and associated drapes

Infrastructure and markets

The Release Area is distant to multi-Tcf fields—the giant Scarborough gas field lying over 100 km to the east. No production infrastructure has yet been developed over the western half of the Exmouth Plateau. However, it has been reported that Woodside will make a final investment decision on the Scarborough gas field in 2020 (PESA, 2017).

Critical risks

The areal extent of the petroleum system(s) present on the northern and western parts of the Exmouth Plateau is yet to be determined. Continued exploration success on the Exmouth Plateau will be dependent most likely on the delineation of competent traps that have access to charge from either the gas-prone Mungaroo Formation or the unproven underlying Locker Shale (Figure 2). Seismic and well data indicate that traps tested by several wells on the Plateau have been breached (e.g. Jupiter 1). Trap breach has been identified as a significant exploration risk on the northern part of the plateau and is a possible explanation for the occurrence of hydrocarbon-bearing structures that are not filled to spill point (Longley et al, 2002).

Within Release Area W17-8, trap integrity, and reservoir distribution and quality, constitute the primary exploration risks. Reservoir quality is generally greater in the shallower Triassic reservoirs. For Upper Jurassic, and younger, deep-water basin-floor fan sand and turbidite plays, the distribution of reservoir quality sandstones within fine-grained deposits can be problematic. Structurally controlled targets are also dependent upon the complexities of fault-linkages between the various phases of breakup-related extension in the Middle–Late Jurassic and Early Cretaceous (Yang and Elders, 2016), and its implications for secondary migration pathways. Furthermore, as Release Area W17-8 is located along and over the Cape Range Fracture Zone, which forms the southern flank of the Exmouth Plateau, transcurrent motion, associated with Breakup and the initial northwest drift direction of Greater India, is expected to have strongly influenced the local structural fabric and, therefore, the architecture of traps.

Parts of the western Exmouth Plateau seafloor provide evidence for slumping and, therefore, seafloor stability needs to be factored in (Scarselli et al, 2016). In addition, potential hazards due to variability of seafloor morphology, resulting from subsurface fluid discharge, should also be considered (The Explorationist, 2000; Dirstein et al, 2013).

Well control

Eendracht 1 (1980)

Eendracht 1 was drilled by Esso Australia Limited to test a tilted Triassic fault block (Esso Australia Ltd, 1981). The well was drilled in 1354 m water depth and reached TD at 3410 mKB. Four gas-bearing sandstones in the Triassic Mungaroo Formation were intersected over the interval 2467–2652 mKB, with a total net gas pay section of 25.5 m. Net pay sand average porosities were 16–25% with average permeabilities of 20–100 mD. The absence of gas indicators in the post-Rhaetian section suggests a competent seal overlies the structure. The well was plugged and abandoned as a gas discovery, and defines the Eendracht gas field (Figure 1).

Alaric 1 (2010)

Alaric 1 was drilled by Woodside Energy Limited primarily to test stacked Triassic Mungaroo Formation sandstones in a three-way dip and fault combination trap, covering about 5 km² at the top Triassic level (Woodside Energy Ltd, 2011a). The well was drilled in 1961 m water depth and reached TD at 4563 mRT. Six gas-bearing sand intervals, throughout the target Mungaroo Formation, were encountered in the interval 3297–4257 mRT. The gas sampled is geochemically distinct from the rest of the Exmouth Plateau gases, which are considered to be derived from Mungaroo Formation coals and/or coaly shales, and may be sourced from marine or freshwater shales containing an algal component. In addition, the gas-bearing sands had average log-derived porosities of 20.1% and permeabilities of 1457 mD. The well was plugged and abandoned as a gas discovery.

Tiberius 1 (2010)

Tiberius 1 was drilled by Woodside Energy Limited primarily to establish the presence of hydrocarbons within an interpreted carbonate platform and, secondarily, to test the hydrocarbon potential of the underlying Mungaroo Formation (Woodside Energy Ltd, 2011b). The well was drilled in 1659 m water depth and reached TD at 2856 mRT. Although the well confirmed the presence of the 370 m thick Rhaetian (i.e. Brigadier Formation equivalent) reefal zone, with average porosity of 13% and a low permeability of 0.02 mD, the interval was water-bearing. Given the presence of a trap, seal and reservoir at Tiberius 1, as well as evidence of active gas charge in the area (e.g. Alaric 1), the lack of hydrocarbons was attributed to the absence of a viable migration pathway. The Tiberius 1 well is interpreted to have reached TD in Rhaetian carbonates and did not intersect Mungaroo Formation clastics. The well was plugged and abandoned.

Cadwallon 1 (2011)

Cadwallon 1 was drilled by Woodside Energy Limited to test Triassic reservoirs within the M. crenulatus palynozone of the Mungaroo Formation, supported on seismic by eight stacked amplitude anomalies stratigraphically equivalent to the gas-bearing interval in Alaric 1, in an adjacent fault block (Woodside Energy Ltd, 2012a). The well was drilled in 2007 m water depth and reached TD at 4460 mRT. The well encountered one gas-bearing interval comprising several sands over 3882–3971 mRT, and two interpreted residual gas intervals between 3952 mRT and 4100 mRT. Gases in Cadwallon 1 are geochemically quite similar to those in Alaric 1 and are distinct from others recovered on the Exmouth Plateau. The latter generally considered to be derived from Mungaroo Formation coals and/or coaly shales. The well was plugged and abandoned as a gas discovery.

Genseric 1 (2011)

Genseric 1 was drilled by Woodside Energy Limited to test Triassic Mungaroo Formation sandstones, supported on seismic by five stacked moderate amplitude anomalies stratigraphically equivalent to the gas-bearing interval in Alaric 1, in an adjacent fault block (Woodside Energy Ltd, 2012b). The well was drilled in 1882 m water depth and reached TD at 3598 mRT. Although many of the target formation sandstones were of reservoir quality, all were water-bearing and the well was plugged and abandoned. Lack of charge, or post-charge migration, was considered the reason for failure.

Vos 1 (2011)

Vos 1 was drilled by Chevron Australia Pty Ltd to test Triassic upper Mungaroo Formation sands at the crest of a northwest-southeast oriented antiform, as well as the reservoir quality and continuity of deeper Mungaroo Formation sands (Chevron Australia Pty Ltd, 2012). The well was drilled in 1483 m water depth and reached TD at 3798 m. The prospectivity of the Mungaroo Formation objectives, within structural closure, was supported by seismic amplitude-vs-offset (AVO) anomalies suggesting direct hydrocarbon indicators (DHIs). Gas saturated reservoir sands were penetrated in the Mungaroo Formation, with a total of 131 m net gas pay intersected. Most sands encountered were of very good reservoir quality. The well was plugged and abandoned as a gas discovery, and has a gas field outline associated with it (Figure 1).

NOPIMS data

Data relating to the Release Area 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 www.ga.gov.au/nopims.

Marine and Environmental information

Release Area W17-8 characteristics

Release Area W17-8 is located over plateau and slope (Harris et al, 2005), in water depths of approximately 1400−3500 m, 270 km south east from the nearest coast, North West Cape.
Planktonic foraminifers are a major component in seabed sediment in this area, and in nearby sediment transects (90–110 km north and south-east of the Release Area). Sediment texture is generally sandy mud, which is dominated by foraminiferal oozes and sands (Colwell and von Stackelberg, 1981).
No detailed information is available for shallow (<100 m) subsurface geology.
Potential hazards include tropical cyclones.

Commonwealth marine reserves

Release Area W17-8 overlaps the northern edge of the Gascoyne Commonwealth Marine Reserve.

Key Ecological Features

Exmouth Plateau, a Key Ecological Feature, overlaps Release Area W17-8 (www.environment.gov.au/webgis-framework/apps/ncva/ncva.jsf).

Biologically important areas

Release Area W17-8 overlaps, or is close to the following biologically important areas (www.environment.gov.au/webgis-framework/apps/ncva/ncva.jsf):

Overlaps an area biologically important for the Pygmy Blue Whale.

The Atlas of Living Australia (www.ala.org.au) and the North West Atlas (www.northwestatlas.org) provide further information and visualisations regarding animals and plants recorded from the Release Area, including Threatened or Listed Species.

Heritage

No shipwrecks are listed in the area.

References and Information Resources

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

Atlas of Living Australia www.ala.org.au

Gascoyne Commonwealth Marine Reserve www.environment.gov.au/topics/marine/marine-reserves/north-west/gascoyne

Commonwealth Fisheries www.afma.gov.au/fisheries/

Western Australian Fisheries www.fish.wa.gov.au/Fishing-and-Aquaculture/Commercial-Fishing/

Shipwrecks www.environment.gov.au/heritage/historic-shipwrecks/australian-national-shipwreck-database

Geoscience Australia products

Regional geology and seismic

Seismic Transects of Australia’s Frontier Continental Margins. Geoscience Australia Record 2006/04, by Alcock et al, 2006.
Geological Framework of the Outer Exmouth Plateau and Adjacent Ocean Basins. Geoscience Australia Record 2004/13, by Stagg et al, 2004.
Interpreted Horizons and Faults for Seismic Survey 128. Outer Carnarvon, Roebuck and Browse basins. Dataset by Kennard et al, 2003.
Interpreted Horizons and Faults for Seismic Survey 110. Carnarvon Basin. Dataset by Kennard et al, 2003.
Interpreted Horizons and Faults for Seismic Survey 101. Carnarvon Basin. Dataset by Kennard et al, 2003.
Interpreted Horizons and Faults for Seismic Survey 95. Carnarvon and Roebuck basins. Dataset by Kennard et al, 2003.
Line Drawings of AGSO-Geoscience Australia’s Regional Seismic Profiles, Offshore Northern and Northwestern Australia. Australian Geological Survey Organisation Record 2001/36 by Colwell and Kennard 2001.

Stratigraphy

Northern Carnarvon Basin Biozonation and Stratigraphy Chart 36. Chart by Kelman et al, 2013.

Petroleum systems and accumulations

The Oils of Western Australia II. Report by Edwards and Zumberge, 2005.
Source Rock Time Slice Maps: Offshore Northwest Australia, 2004. Dataset by West et al, 2004.
Characterisation of Natural Gases from West Australian Basins. AGSO and Geotechnical Services Non-Exclusive Study, 2000.
Australian Petroleum Systems. Exmouth Plateau & Outer Rankin Platform Module. Australian Geological Survey Organisation Record 1995/80, by Spencer et al 1995.
Australian Petroleum Accumulations Report 8. Carnarvon Basin, Western Australia. Australian Geological Survey Organisation Report by Felton et al, 1993.

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

References

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