2016 Release Areas

Vulcan Sub-basin

Release Areas AC17-2, AC17-3 and AC17-4, Territory of Ashmore and Cartier Islands

Highlights

AC17-2 and AC17-3 bids close 19 October 2017

AC17-4 bids close 22 March 2018

Proven oil and gas producing province; adjacent to Swan and Cash Maple gas fields and the Montara oil accumulation.
Shallow water depths of 100-240 m
Potential for structural and stratigraphic Triassic–Jurassic, Cretaceous and Paleogene plays
Further guidance available, refer to 2017 Special Notices.

Release Area AC17-4 is located in the Vulcan Sub-basin, western Bonaparte Basin in the Timor Sea (Figure 1), approximately 250 km offshore and 700 km from Darwin. The Release Areas cover two (165 km²), seven (~585 km²) and six (~500 km²) whole graticular blocks, respectively, in water depths of up to 240 m. Release Areas AC17-2 is situated in the Swan graben adjacent to the Ashmore. AC17-3 is located on the Montara Terrace and AC17-4 overlies the Montara Terrace and Heywood Graben and extends partly into the Caswell Sub-basin.

The Vulcan Sub-basin is a northeast-oriented Late Jurassic extensional depocentre that contains Permian–Holocene sediments (Figure 2). The sub-basin comprises a complex series of horsts, graben and marginal terraces. It is a proven hydrocarbon province which includes several producing oil fields of the Montara Project (Skua, Swift‑Swallow, Montara), as well as several other oil fields (Jabiru, Challis‑Cassini, Puffin) and sub-economic accumulations (Figure 1). The Release Areas are adjacent to the Cash‑Maple, Swan and Crux gas fields, the greater Montara oil fields and a number of discoveries including the Maret 1, Eclipse 2 and Vesta 1 oil and gas accumulations, Bilyara 1 and Tahbilk 1 gas accumulations and Talbot oil accumulation. Development options for the Cash‑Maple gas and oil accumulation are currently being considered. Examples of play types identified in the vicinity of the Release Areas is shown in Figure 3.

The Swan and Paqualin graben form the major source kitchens in the Vulcan Sub-basin, containing mature oil- and gas-prone source rocks in the Jurassic lower Vulcan, Montara and Plover formations. Hydrocarbons at Cash‑Maple gas field are reservoired in the Montara, Plover and Challis formations while the Swan gas field is in the Puffin Formation. The Jabiru oil field lies within the Montara Formation. In addition, numerous wells in the immediate vicinity of the Release Areas have oil and gas shows in the Plover (Audacious 1, Augustus 1, East Swan 1, Swallow 1), lower Vulcan (Elm 1, Vulcan 1B), upper Vulcan (Paqualin 1, Swan 1, Octavius 1, Keeling 1) and Johnson (Snowmass 1, Puffin 2) formations (Figure 1). The temporal and spatial distribution of effective source rocks, their expulsion history and migration pathways in the Vulcan Sub-basin are given in Figure 4. Structural traps containing Triassic to Jurassic sandstone reservoirs are sealed by Lower Cretaceous claystones of the Echuca Shoals Formation (Figure 3). These traps are commonly either horsts (some complexly faulted), or tilted fault blocks. Upper Jurassic and Upper Cretaceous submarine fan sandstones are proven exploration targets within the sub-basin. A well-to-well correlation across the Vulcan Sub-basin from Anson 1 on the Londonderry High to Rainbow 1 on the Ashmore Platform identifying sand and mud-prone intervals is shown in Figure 5.

Data coverage for the Vulcan Sub-basin is extensive (Figure 6), with 2D and 3D seismic data available and numerous wells drilled. Release Area AC17-4 is penetrated by Maret 1 and Circinus 1 ST1.

Petroleum systems elements

Vulcan Sub-basin

Sources	Potential Lower Cretaceous marine claystones of the Echuca Shoals Formation Middle–Upper Jurassic transgressive marine shales of the Montara and lower Vulcan formations and their potential inboard coaly source facies equivalents Lower–Middle Jurassic fluvio-deltaic Plover Formation Potential Permian sources
Reservoirs	Paleogene marine carbonates of the Oliver Sandstone Member, Oliver Formation and Cartier Formation Eocene Grebe Sandstone of the Hibernia Formation Upper Cretaceous submarine fan sandstones of the Puffin Formation Upper Cretaceous limestones of the Brown Gannet Limestone Upper Jurassic–Lower Cretaceous submarine fan and shelfal and topset sandstones of the Vulcan Formation Middle–Upper Jurassic marine shoreface/barrier bar sandstones of the Montara Formation Lower–Middle Jurassic fluvio-deltaic Plover Formation Upper Triassic estuarine to intertidal Challis Formation and deltaic Nome Formation plus equivalents Triassic fluvial-deltaic Pollard Formation Potential Permian plays
Seals	Regional seals Paleocene marine carbonates of the Johnson Formation Marine claystones of the Lower Cretaceous Echuca Shoals and Cretaceous Jamieson formations Upper Jurassic–Lower Cretaceous marine claystones of the Vulcan Formation Intraformational seals Paleogene–Neogene Woodbine Group carbonates Lower Triassic Mount Goodwin Formation marine shales
Traps	Stratigraphic traps including submarine fan/channel sandstones, reefs, pinchouts and unconformities Structural traps consisting of tilted fault blocks, horst blocks and anticlines including faulted and unproven salt induced anticlines

Well Control

Puffin field (1972-)

Puffin 1 (1972) was drilled in exploration permit NT/P2 to test the crest of an elongate northeast-southwest trending faulted anticline on the eastern flank of the Ashmore Platform adjacent to the Swan Graben (Arco Australia Ltd, 1972). The anticlinal feature was mapped with apparent closure at base Paleocene and near base Cretaceous levels. The well reached a total depth of 2961 mKB and penetrated 603 m of Triassic clastics and shallow marine oolitic carbonates (Sahul Group), unconformably overlain by mid-Upper Cretaceous sandstones and shales (Bathurst Island Group) and Cenozoic carbonates, marls and minor sandstones (Woodbine Group). Electric log and core analysis indicated the presence of heavy sour crude oil in vuggy Eocene carbonates from 1021-1029 mKB, trapped below the Eocene-Miocene unconformity. A formation interval test taken at 2067 m in Maastrichtian sandstone (Puffin Formation) indicated the presence of 45°API crude oil in the interval 2066-2067 m. These were the first known occurrences of hydrocarbons in Paleogene and Cretaceous strata in the Bonaparte Basin. Puffin 2 (1974) and Puffin 3 (1975) which were drilled as follow-up wells also encountered good oil and gas shows in Maastrichtian sands. A DST across a thin, stratigraphically isolated, Maastrichtian sand in Puffin 2 flowed 48°API oil at a maximum unstabilised rate of 4608 bopd (~733 m3/d). The field produces light, sweet crude with an API of 43.8° and encompasses two sections. Puffin North East consists of the historic Puffin 1, 3 and 4 wells, and more recently drilled horizontal wells Puffin 5, 7 and 8, as well as the Puffin 12 well. Puffin South West consists of the Puffin 2 and Puffin 9, 11 and 13 wells (SubseaIQ, 2017). Production commenced in the North East sector in October 2007. While initial flow rates were expected to reach 18 000 bopd (2862 m3/d), production reached 27 000 bopd (4293 m3/d) within two days. The Puffin oil field ceased production in 2009 and decommissioned in 2014 (AGR, 2014)

Swan 1–3/3ST1 (1972-1993)

Swan 1 (1972) was drilled by Arco Australia Ltd on the northwest flank of an interpreted salt diapir to test the Upper Cretaceous Puffin sandstone that was oil-bearing at Puffin 1, 22 km to the southeast (Arco Australia Limited, 1973). The well reached a total depth of 3284 mKB within a thick section of Oxfordian-Tithonian shales and siltstones that are unconformably overlain by mid-Upper Cretaceous marls. Gas shows were recorded while drilling the Upper Cretaceous and Upper Jurassic sections (Figure 3a). A formation interval test of thin sandstones at 2364 m in the Upper Cretaceous section recovered 72.6 cf (2.056 m³) of gas and 625 cm³ of a colourless condensate with gravity of 54.7°API. Thin sandstones in the Upper Jurassic section were also tested, but were found to be tight. Swan 2 (1980) was drilled to further evaluate the tilted fault block of the Swan structure (Arco Australia Limited, 1977) (Figure 3e). It encountered good gas shows in the Upper Cretaceous sandstones (2248-2335 mKB), which were updip to those encountered in Swan 1. Swan 2 also encountered shows in thin sandstones or fractures within the Oxfordian section (3341 mKB), but these shows were not thought to be economically significant and were not tested. Swan 3 ST1 (1993) was drilled by BHP Petroleum Pty Ltd, approximately 400 m west of Swan 2. It targeted a structural/stratigraphic play designed to evaluate the extent of hydrocarbons encountered in the Upper Cretaceous Puffin Formation in the Swan 1 and 2 wells. Swan 3 was side-tracked due to the absence of the primary objective P3 sandstones of the Puffin Formation. The side-track reached a total depth of 2530 mKB after successfully intersecting the top of the P3 sandstone at 2445 mKB. Logging identified the presence of an 18.2 m gas column in the P1 and P2 sandstone reservoirs over the interval 2342-2375 mKB. Average porosity of 21% and an average hydrocarbon saturation of 63% were recorded. The primary objective P3 sandstone comprises 14.3 m of reservoir facies with an average porosity of 19% and an average hydrocarbon saturation of 72%. The interval was entirely gas saturated, and no gas/oil or gas/water contacts could be identified. While successful in discovering gas and condensate, Swan 3 ST1 did not intersect the expected oil leg, and was subsequently plugged and abandoned.

Challis field (1984-)

Challis 1 (1984) was drilled by BHP Petroleum Pty Ltd in exploration permit NT/P26. It tested the fault-dependent closure of Lower Triassic to Upper Jurassic sandstones, beneath the base Cretaceous unconformity on the Challis-Cleghorn Horst (BHP Petroleum, 1988) (Figure 3b). The well was terminated at 1960 mRT after entering interbedded sandstones and claystones of the Middle-Late Triassic Sahul Group. Challis 1 intersected a gross oil column of 32 m, which included a net oil column of 18.5 m in porous sands (porosities of 19-30%) below the base-Cretaceous unconformity (BHP Petroleum, 1985). Production testing of Challis 6 flowed up to a rate of 7447 bbl/d (1184 m³/d) of 39.9°API oil (BHP, 1998). The well was plugged and suspended with subsequent wells (Challis 2-15) appraising the extent of, and producing from, the oilfield. Joint production of the Challis and nearby Cassini oil fields commenced in 1989. The Challis oilfield was produced using 2 sub-sea completions connected to the Challis Venture FPSO. Production ceased in 2010 (Wright, 2015).

Montara field (1988-)

Montara 1 (1988) was drilled to test a fault block closure defined at the Oxfordian unconformity (BHP Petroleum Pty Ltd, 1989). The primary targets were Oxfordian sandstones below the unconformity, with secondary targets identified at the Maastrichtian (Puffin Formation), Lower Cretaceous (upper Vulcan Formation) and Lower-Middle Jurassic (Plover Formation) levels. The well reached a total depth of 3444 mKB within the Plover Formation, which is unconformably overlain by a thick section of late Callovian-Oxfordian transgressive sandstones (Montara Formation), that are sealed by shales and siltstones of the lower Vulcan Formation. The Montara Formation was not previously penetrated in the Timor Sea region. A 25 m net gas column and at least 10 m net oil column was discovered in Oxfordian shoreface barrier bar or strandline sandstones, although a conclusive oil-water contact could not be identified. DST 1 over the interval 2641.5‑2648.5 mKB flowed 35.5°API oil at 457 bbl/d (73 m³/d) and gas at 6654 m³/d; DST 2 over the interval 2628-2633 mKB flowed 35.5°API oil at 4285 bbl/d (681 m³/d) and gas at 438 373 m³/day. The oil is quite waxy, suggesting a terrestrial influence, and it is thus different to the Jabiru and Challis crudes. The subsequent Montara 2 (1991) extension/appraisal well intersected a 15 m gross oil column, and established an oil/water contact. The upper 6 m of the column is thought to be moveable oil, and the lower 9 m is considered to be a residual oil column with an average water saturation of 63%. Montara 3 (2002), drilled in the northeast extension of the Montara structure, intersected a 13.4 m oil column. The Montara Project which comprises Montara, Skua, Swift and Swallow fields, recommenced oil production in June 2013 using the FPSO vessel Montara Venture (PTTEP, 2016). Estimated recoverable reserves for the Montara Project are 24 MMbbls (3.8 GL), with 35 000 Bbls/d (5.6 Ml/d) of light, low-sulphur crude also expected to be produced. The estimated lifespan of the Montara field is 12 years (Offshore Technology, 2015; PTTEP, 2016). In the first half of 2014, Montara produced 2 940 000 Bbls (467 Ml) of crude oil – the sixth largest producer in Australia (Australian Petroleum Production and Exploration Association, 2014). PTTEP Australasia is planning to commence production drilling of one well (H5) at the Well Head Platform in September 2017. The drilling program is estimated to last approximately 60 days but is dependent on weather conditions and operational efficiencies (PTTEP Australasia, 2017).

Maret 1 (1992)

Maret 1 (1992) was drilled to evaluate the hydrocarbon potential of Oxfordian sandstones on a northeast–southwest-trending horst block 1 km southwest of the Montara field (Norcen International Limited, 1992). No significant shows were observed in the Oxfordian, but the Lower–Middle Jurassic Plover Formation exhibited moderately strong fluorescence with wireline logs indicating a ca. 3 m net hydrocarbon pay. An RFT sample taken at 3409.5 mKB recovered gas/condensate. Log analysis shows that the condensate-bearing sand occurs within an interbedded sequence in which all other sandy intervals are water saturated. This suggests that the condensate is probably an isolated pocket which has been trapped stratigraphically. The total depth reached was 3560 mKB.

Cash 1ST1A (2002)

Cash 1 (2002) was drilled by Coastal Oil and Gas Australia 20 Pty Ltd to test a large northeast-trending horst block on the eastern flank of the Paqualin Graben (Figure 3d) some 8 km northeast of Maple 1. The Maple‑Cash structure was mapped using the Onnia 3D seismic data, and the objective was to evaluate predicted better quality reservoirs within the Upper Triassic Challis Formation, which was gas-bearing but tight in Maple 1. The well was side-tracked due to drilling problems and Cash 1 ST1A reached a total depth of 3929 mRT within reservoir sandstones of the Lower-Middle Jurassic Plover Formation (12-13% log porosity), rather than the predicted Triassic section. The Plover Formation is unconformably overlain by a thick section of claystones of the lower Vulcan Formation and poor quality basal Oxfordian sandstones. Oil and gas shows were recorded while drilling the Oxfordian sandstones and the Plover Formation, and a tight gas column was interpreted in the Plover Formation with water saturations of 30-44%. Cash‑Maple accumulation appraisal drilling of Cash 2 and Maple 2 indicates the gas resource was larger than previously assessed. The project is in the initial concept stage, and is considering both conventional LNG and FLNG options (PTTEP, 2013). Plans to develop the Cash‑Maple in the near future seem to be on hold (Energy News Premium, 2016).

Infrastructure and markets

Release Area AC17-2 is proximal to the Cash‑Maple gas accumulation may be developed by PTTEP. Release Area AC17-4 is adjacent to fixed infrastructure of the Montara platform. Historically, production from oil fields in the Vulcan Sub-basin has been through the use of floating, production, storage and offtake (FPSO) vessels. The port of Darwin is about 700 km from the Release Areas.

Critical risks

Structural complexity in the Vulcan Sub-basin has meant adequate imaging of reservoirs, traps and seals has been challenging. Repeated episodes of fault reactivation (particularly during the Neogene) and associated remigration, water washing and gas flushing have locally degraded oil accumulations in ‘leaky traps’ such as Skua and Jabiru. The risk of water washing degrading any oil accumulations in the Release Areas is difficult to predict. For example; oil from Puffin 1, 2 and 5 shows significant water washing; the Skua, Jabiru and Tenacious oils show moderate water washing, and the Bilyara 1 and Crux 1 oils show negligible evidence of water washing (Edwards et al, 2004). The Montara 1 and 2 oil accumulation near Release Area AC17-4 is biodegraded (Edwards et al, 2004). While remobilised evaporites, as seen at Paqualin 1 and adjacent to Vulcan 1B are less extensive in the Vulcan Sub-basin than in other parts of the Bonaparte Basin, there is a risk that localised salt intrusions could impact on seal integrity. Elevated geothermal gradients during the Middle Jurassic, as modelled in Jabiru 1 and Swan 2 (Lisk, 2012), may affect the timing of hydrocarbon generation and expulsion in the Vulcan Sub-basin and adversely affect reservoir quality.

NOPIMS 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. http://www.ga.gov.au/nopims

Marine and Environment

Release Area AC17-2 characteristics

Release area AC17-2 is located over the North West Shelf in water depths of approximately 120 m, and is approximately 250 km northwest of the nearest mainland. Darwin is the closest industrial port.
Based on detailed seabed sampling across the shelf (Baker et al, 2008), seafloor substrate interpolations indicate that sediments are generally gravelly muddy sand.
Potential hazards: tropical cyclones occur throughout the monsoon season.

Commonwealth marine reserves

Release Area AC17-2 is located 103 km east of Cartier Commonwealth Marine Reserve and 130 km south east of Ashmore Reef Commonwealth Marine Reserve.

Key ecological features

Key ecological features near the area include: the carbonate bank and terrace system of the Sahul Shelf, 39 km to the east; continental slope demersal fish communities, 99 km to the west; Ashmore Reef and Cartier Island and surrounding Commonwealth waters, 104 km to the west; and the ancient coastline at 125 m depth contour, 117 km to the south (National Conservation Values Atlas, 2017 http://www.environment.gov.au/webgis-framework/apps/ncva/ncva.jsf).

Biologically important areas

Release Area AC17-2 overlaps or is close to the following biologically important areas (National Conservation Values Atlas, 2017). The Area:

Overlaps breeding and foraging area on and surrounding Ashmore Reef for the Brown Booby, Greater Frigatebird, Lesser Crested Tern, Lesser Frigatebird, Red-footed Booby, Roseate Tern, Wedge-tailed Shearwater and White-tailed Tropicbird. The Little Tern uses Ashmore Reef for resting.
Overlaps to the north known Pygmy Blue Whale distribution and migration area.
Overlaps Whale Shark foraging area along the 200 m isobath.
Overlaps biologically important area for Green and Hawksbill turtles foraging and internesting on Ashmore Reef.

Table 2 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

Brown Booby

Greater Frigatebird

Lesser Crested Tern

Lesser Frigatebird

Red-footed Booby

Roseate Tern

White-tailed Tropicbird

Wedge-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

No shipwrecks are listed in the area.

Release Area AC17-3 characteristics

Release area AC17-3 is located over shelf, terrace and valley geomorphic features in water depths of approximately 100−120 m, and is 217 km northwest of the nearest mainland. Darwin is the closest industrial port.
Based on detailed seabed sampling across the shelf (Baker et al, 2008), seafloor substrate interpolations indicate that sediments are generally gravelly muddy sand and slightly gravelly muddy sand.
Potential hazards: tropical cyclones occur throughout the monsoon season.

Commonwealth marine reserves

Release Area AC17-3 is located 115 km east of Cartier Island Commonwealth Marine Reserve and 152 km from Ashmore Reef Commonwealth Marine Reserve. The area is also 125 km to the west of the Oceanic Shoals Commonwealth Marine Reserve and 104 km north of the Kimberley Commonwealth Marine Reserve.

Key ecological features

Key ecological features near the area include: the carbonate and bank terrace system of the Sahul Shelf, located 9.5 km east; Ashmore Reef and Cartier Island and surrounding Commonwealth waters, 116 km to the west; and the Continental Slope Demersal Fish Communities,114 km to the southwest. (National Conservation Values Atlas, 2017 http://www.environment.gov.au/webgis-framework/apps/ncva/ncva.jsf).

Biologically important areas

Release Area AC17-3 overlaps, or is close to the following biologically important areas (National Conservation Values Atlas, 2017 http://www.environment.gov.au/webgis-framework/apps/ncva/ncva.jsf). The Area:

Lies to the east of breeding and foraging area on and surrounding Ashmore Reef for the Brown Booby, Greater Frigatebird, Lesser Crested Tern, Lesser Frigatebird, Red-footed Booby, Roseate Tern, Wedge-tailed Shearwater and White-tailed Tropicbird. The Little Tern uses Ashmore Reef for resting.
Lies south of Pygmy Blue Whale distribution and migration area.
Overlaps Whale Shark foraging areas along the 200 m isobath.
Lies to the east of internesting area around Ashmore Reef and Cartier Island for the Green Turtle and around Ashmore Reef for the Hawksbill Turtle.

Table 3 Breeding periods (b) for key seabirds whose foraging areas are adjacent to the Release Area.

Jan

Feb

Mar

Apr

May

Jun

Jul

Aug

Sept

Oct

Nov

Dec

Brown Booby

Greater Frigatebird

Lesser Crested Tern

Lesser Frigatebird

Red-footed Booby

Roseate Tern

White-tailed Tropicbird

Wedge-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

No shipwrecks are listed in the area.

Release Area AC17-4 characteristics

Release area AC17-4 is located over reef, pinnacle, terrace and valley geomorphic features in water depths of approximately 30−150 m, and is approximately 212 km north west of the nearest mainland. Darwin is the closest industrial port.
Based on detailed seabed sampling across the shelf (Baker et al., 2008), seafloor substrate interpolations indicate that sediments are generally gravelly muddy sand and slightly gravelly muddy sand.
Potential hazards: tropical cyclones occur throughout the monsoon season.

Commonwealth marine reserves

Release Area AC17-4 is located 100 km north west of Kimberley Commonwealth Marine Reserve, 73 km from Cartier Island Commonwealth Marine Reserve, and 166 km to the west of the Oceanic Shoals Commonwealth Marine Reserve.

Key ecological features

Key ecological feature near the area include: the carbonate and bank terrace system of the Sahul Shelf, 44.5 km to the east; Continental Slope Demersal Fish Communities, 53 km to the west; Ashmore Reef and Cartier Island and surrounding Commonwealth waters, 72 km to the northwest; and the ancient coastline at 125 m depth contour, 38 km to the south (National Conservation Values Atlas, 2017 http://www.environment.gov.au/webgis-framework/apps/ncva/ncva.jsf).

Biologically important areas

Release Area AC17-4 overlaps, or is close to the following biologically important areas (National Conservation Values Atlas, 2017 http://www.environment.gov.au/webgis-framework/apps/ncva/ncva.jsf). The Area:

Lies south east of breeding and foraging area on and surrounding Ashmore Reef for the Brown Booby, Greater Frigatebird, Lesser Crested Tern, Lesser Frigatebird, Red-footed Booby, Roseate Tern, Wedge-tailed Shearwater and White-tailed Tropicbird. The Little Tern uses Ashmore Reef for resting.
Lies south of Pygmy Blue Whale distribution and migration area.
Overlaps Whale Shark foraging areas along the 200 m isobath.
Lies to the east of internesting area around Ashmore Reef and Cartier Island for Green Turtle and around Ashmore Reef for Hawksbill Turtle.

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

Jan

Feb

Mar

Apr

May

Jun

Jul

Aug

Sept

Oct

Nov

Dec

Brown Booby

Greater Frigatebird

Lesser Crested Tern

Lesser Frigatebird

Red-footed Booby

Roseate Tern

White-tailed Tropicbird

Wedge-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

No shipwrecks are listed in the area.

References and Information Resources

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

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

Cartier Island Commonwealth Marine Reserve http://www.environment.gov.au/topics/marine/marine-reserves/north-west/cartier

Ashmore Reef Commonwealth Marine Reserve http://www.environment.gov.au/topics/marine/marine-reserves/north-west/ashmore

Kimberley Commonwealth Marine Reserve https://www.environment.gov.au/topics/marine/marine-reserves/north-west/kimberley

Oceanic Shoals Commonwealth Marine Reserve https://www.environment.gov.au/topics/marine/marine-reserves/north/oceanic-shoals

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

Northern Territory Fisheries https://nt.gov.au/marine/commercial-fishing/about-nt-commercial-fishing-industry

Western Australian Fisheries http://www.fish.wa.gov.au/Fishing-and-Aquaculture/Commercial-Fishing/Pages/default.aspx

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

Geoscience Australia products

Regional geology and seismic

Basement and Crustal Structure of the Bonaparte - Browse Basins, 2003. Conference Abstract by Goncharov et al, 2003
Interpreted Horizons and Faults for Seismic Survey 98. Vulcan Basin, 2001. Data Package by Kennard et al, 2003
Vulcan Sub-basin, Offshore WA, 1989 (P556). Airborne Geophysics Dataset by Richardson, 2002
1996 Vulcan Sub-basin Airborne Laser Fluorosensor Survey Interpretation Report (WGC Vulcan Graben Survey Number 1113). Australian Geological Survey Organisation Record 2000/033 by Cowley, 2001
Line Drawings of AGSO – Geoscience Australia’s Regional Seismic Profiles, Offshore Northern and Northwestern Australia, 2001. Australian Geological Survey Organisation Record 2001/036 by Colwell and Kennard, 2001
Vulcan Sub-basin Composite Well Log, 1999 Petroleum Wells Dataset by Kennard, 1999
Vulcan Tertiary Tie (VTT) Basin Study, Vulcan Sub-basin, Timor Sea, Northwestern Australia, 1996.Australian Geological Survey Record 1996/061 by O’Brien, 1996
Vulcan Sub-basin, Timor Sea Survey 97: High Resolution Seismic Reflection Profiling and Direct Hydrocarbon Detection (Vulcan I): Post-Cruise Report: Project 121.19, 1991. Bureau of Mineral Resources Record 1991/068 by O’Brien and Marshall, 1992

Stratigraphy

Geoscience Australia’s Basin Biozonation and Stratigraphy Chart Series: Bonaparte Basin Biozonation and Biostratigraphy Chart 33, 2014. Geoscience Australia Stratigraphy Chart by Kelman et al, 2014

Petroleum systems and accumulations

Source Rock Distributions and Petroleum Fluid Bulk Compositional Predictions on the Vulcan Sub-basin, Offshore Western Australia, 2009. Geoscience Australia Report by Neumann et al, 2009
Oils of Western Australia II, 2005. Geoscience Australia Report by Edwards and Zumberge, 2005
Bonaparte Basin, Northern Territory (NT), Western Australia (WA), Territory of Ashmore and Cartier Islands Adjacent Area (AC), Joint Petroleum Development Area (JPDA), 2004. Geoscience Australia Report 5 by Cadman and Temple, 2004
The Petroleum Systems of the Bonaparte Basin, 2004. Dataset by Earl, 2004
Source Rock Time-slice Maps, Offshore Northwest Australia, 2004. Petroleum data by West et al, 2004
Hydrocarbon Migration and Seepage in the Timor Sea and Browse Basin, North West Shelf, Australia: An Integrated SAR, Geological and Geochemical Study, 2001. Dataset and Geoscience Australia Record 2001/11 by O’Brien et al, 2001
Vulcan Sub-basin – Hydrocarbon Shows Analyses, 2001. Data Package by Royal et al, 2001
AGSO Marine Survey 176 Direct Hydrocarbon Detection North-West Australia: Yampi Shelf; Southern Vulcan Sub-Basin; Sahul Platform (July/September 1996) - Operational Report and Data CompendiumAustralian Geological Survey Record 2000/042 by Wilson, 2000
Characterisation of Natural Gases from West Australian Basins, 2000. Geoscience Australia Report by Boreham et al, 2000
Light Hydrocarbon Geochemistry of the Vulcan Sub-basin, Timor Sea: Rig Seismic Survey 97: Project 121.19, 1992. Bureau of Mineral Resources Record 1992/062 by O’Brien, 1992
Ashmore-Cartier prospectivity package: an analysis of the petroleum prospectivity of vacant areas overlying the Ashmore Platform, Vulcan Sub-basin, Jabiru Terrace and northern Browse Bureau of Mineral Resources Record 1991/090 by Lavering, 1991.

Contact Geoscience Australia’s Client Services for more information or to order these reports or products,
phone 61 (0)2 6249 9966, email clientservices@ga.gov.au

References

Abbassi, S., Horsfield, B., George, S.C., Edwards, D.S., Volk, H., di Primio, R., 2014—Geochemical characterisation and predicted bulk chemical properties of petroleum generated from Jurassic and Cretaceous source rocks in the Vulcan Sub-basin, Bonaparte Basin, North West Shelf of Australia. Organic Geochemistry, 76, 82–103.

AGR 2014—[Web Page] AGR completes a seven well abandonment campaign in Puffin field. https://www.agr.com/snackbox/case-studies/well-management/agr-delivers-decommissioning-on-puffin-field (last accessed 10 April 2017).

AGSO, OIL AND GAS CONSULTANTS PTY LTD AND PGS NOPEC, 1996—Vulcan Tertiary Tie (VTT) Basin Study, Vulcan Sub-basin, Timor Sea, Northwest Australia. Australian Geological Survey Organisation, Oil and Gas Consultants Pty Ltd and PGS Nopec report. Australian Geological Survey Organisation Record, 1996/61.

AHMAD, M. AND MUNSON, T.J., 2013—Chapter 36: Bonaparte Basin. In: Ahmad, M. and Munson, T.J. (compilers), Geology and mineral resources of the Northern Territory, Northern Territory Geological Survey, Special Publication 5, 33 pp.

AMBROSE, G.J., 2004—Jurassic pre-rift and syn-rift sedimentation in the Bonaparte Basin – new models for reservoir and source rock development. In: Ellis, G.K., Baillie, P.W. and Munson, T.J. (Eds), Timor Sea Petroleum Geoscience, Proceedings of the Timor Sea Symposium, Darwin Northern Territory, 19–20 June 2003. Northern Territory Geological Survey, Special Publication 1, 125–142.

ARCO AUSTRALIA LIMITED, 1972—Puffin 1well completion report: basic and interpretive data, unpublished

ARCO AUSTRALIA LIMITED, 1973—Swan 1 well completion report: basic and interpretive data, unpublished.

ARCO AUSTRALIA LIMITED, 1977—Swan 2 well completion report: basic and interpretive data, unpublished.

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