2016 Release Areas

Dampier Sub-basin

Release Areas W17-5 and W17-6, offshore Western Australia

Highlights

Bids close for release area W17-5 on Thursday 19 October 2017.

Prequalification for release area W17-6 closes on Thursday 5 October 2017, with the cash bidding auction to be held on 8 February 2018.

Within one of Australia’s premier offshore producing basins
Release Area W17-5 lies on trend between the Legendre and Talisman oil accumulations, while Cash Bid Release Area W17-6 overlies the Gungurru oil and gas accumulation
Shallow water (40–80 m)
Oil-prone Upper Jurassic and gas-prone Triassic to Middle Jurassic source rocks
Stacked structural and stratigraphic targets at Triassic, Jurassic and Lower Cretaceous levels
Overlying, and proximal to gas pipelines
Further guidance available, refer to 2017 Special Notices

Release Areas W17-5 and W17-6 are small areas comprising 4 and 2 graticular blocks, respectively, lying along the eastern flank of the Dampier Sub-basin. These areas are considered mature in exploration terms, and Release Area W17-6 is available for cash bidding. Release Area W17-5 overlies a northeasterly structural trend (‘Legendre Trend’) which hosts the Legendre oil field just to its south and the Talisman and Amulet oil fields just to its northeast, as well as the Ajax 1 oil discovery and Forestier 1 gas discovery (Figure 1). Further to the southwest, Release Area W17-6 hosts the Gungurru oil and gas field, on the heavily faulted eastern flank of the Lewis Trough, with producing fields Wandoo and Reindeer just to the south and west, respectively (Figure 1).

The Dampier Sub-basin is one of a series of large rift depocentres of the Northern Carnarvon Basin. The sub-basin is an elongate northeast-trending depocentre 170 km in length and 100 km in width, and contains Paleozoic to Cenozoic sedimentary successions 10–20 km in thickness. The main structural elements of the Dampier Sub-basin are aligned northeast–southwest, which from northwest to southeast are: the Kendrew Trough, Madeleine Trend, Lewis Trough, Legendre Trend and Enderby Terrace (Figure 3).

The Dampier Sub-basin hosts proven petroleum systems. Triassic, Lower–Middle and Upper Jurassic source rocks have expelled hydrocarbons that are reservoired in both structural and stratigraphic traps. Gas is predominantly sourced from Triassic to Middle Jurassic fluvio-deltaic sediments of the Mungaroo and Brigadier formations, the Murat Siltstone, and the Athol and Legendre formations, while oil is predominantly sourced from the Upper Jurassic Dingo Claystone (Figure 2). Structural trap styles in the sub-basin include tilted fault blocks, fault dependent rollovers, anticlines, drape features and horsts, while stratigraphic trap styles are predominantly of Upper Jurassic basin-floor fan systems and Lower Cretaceous marginal marine transgressive sands (Figure 3).

Figure 4 shows the data coverage for the Dampier Sub-basin in the vicinity of the Release Areas, highlighting well concentrations and a high density of 2D seismic lines. In Release Area W17-5, Ajax 1/ST 1 and Forestier 1/ST 1 are oil and gas discoveries, respectively. Several other dry wells within the Area (Charm 1, Legendre 2, Nelson Rocks 1 and Polaris 1) provide stratigraphic information while the Release Area is completely covered by 3D seismic surveys Panaeus 1999 MC3D MSS, Panaeus 2 North MSS and Panaeus MC3D MSS. In Release Area W17-6, apart from the Gungurru oil and gas field, Cherring 1 is a gas discovery with an oil show and Coojong 1 has an oil show. Well Nickol Bay 1 provides further stratigraphic information in the sparsely explored east, while the Release Area is completely covered by 3D seismic surveys Panaeus MC3D MSS and Panaeus East 2001 MC3D MSS.

Petroleum systems elements

Dampier Sub-basin

Sources	Upper Jurassic marine Dingo Claystone Lower–Middle Jurassic marine and deltaic Murat Siltstone and Athol and Legendre formations Triassic fluvio-deltaic sediments of the Mungaroo Formation Lower Triassic Locker Shale
Reservoirs	M. australis Sandstone Member and other sandstone units within the Lower Cretaceous marine to marginal marine Muderong Shale Upper Jurassic Angel Formation turbidites Middle–Upper Jurassic fluvio-deltaic to marine Legendre and Calypso formations Lower–Middle Jurassic marginal marine Athol Formation Lower Jurassic fluvio-deltaic to marginal marine North Rankin Formation Upper Triassic fluvio-deltaic to shallow marine Brigadier Formation Middle–Upper Triassic fluvio-deltaic to marginal marine Mungaroo Formation Lower Triassic marginal marine transgressive sand underlying the Locker Shale (unproven)
Seals	Regional seal Lower–Upper Cretaceous marine Gearle Siltstone Lower Cretaceous marine claystones of the Muderong Shale Lower Triassic Locker Shale (untested) Intraformational seals Upper Jurassic condensed marls and claystones of the Dingo Claystone Lower–Middle Jurassic marine to marginal marine Athol Formation Lower Jurassic marine Murat Siltstone
Traps	Lower Cretaceous M. australis Sandstone Member stratigraphic trap Lower Cretaceous low-side rollover structures and faulted horst blocks Upper Jurassic–Lower Cretaceous drape structures Upper Jurassic–Lower Cretaceous submarine fan stratigraphic traps Middle Jurassic faulted anticlines Upper Triassic–Lower Jurassic horst and tilted fault-blocks and associated drapes

Infrastructure and markets

Release Area W17-5 lies within 30 km of the Angel Platform, over the Angel gas field to the west, which is serviced by the Angel Pipeline to the North Rankin Complex and thence via two other pipelines to the Karratha Gas Plant onshore (Figure 1). Although the Legendre and Talisman oil fields, just to the south and north, respectively, have ceased production, nearby oil fields Hurricane and Amulet await development opportunities.

Release Area W17-6 overlies the midway point of the Northwest Shelf 42” (1.067 m) Trunkline and the North Rankin to Withnell Bay gas pipelines to the Karratha Gas Plant (Figure 1). These pipelines source gas from the North Rankin Platform and other Dampier Sub-basin gas fields to the northwest and north, respectively (Woodside Petroleum Ltd, 2013). In addition, the Wandoo oil field platform and Reindeer gas field platform lie 10 km to the south and 15 km to the west, respectively. Reindeer supplies gas to the onshore Devil Creek Gas Plant (Quadrant Energy, 2016) via the Devil Creek Pipeline.

Critical risks

In parts of the Dampier Sub-basin, trap integrity and reservoir preservation constitute significant exploration risks. Variable sandstone distribution and porosity within fine-grained deep-water sediments can also be problematic. Exploration risks associated with the inboard areas of the Dampier Sub-basin include hydrocarbon migration distance, biodegradation of oil in shallow reservoirs and the potential absence of a competent seal. Late gas flushing of oil reservoirs is also considered an exploration risk.

Well control

Legendre 2 (1971)

Legendre 2 was drilled by B.O.C. of Australia Limited to test the northeastern extent of the anticlinal crest hosting the oil-bearing ‘Neocomian’ sandstone found in Legendre 1 (B.O.C. of Australia Ltd, 1971). The well was drilled in 157 ft (48 m) water depth and reached TD at 11 871 ft (3618 mRT). As predicted, the target ‘Neocomian’ sandstone was absent in Legendre 2, possibly due to a facies change. The Jurassic section was found to have good reservoir characteristics, but was 100% water bearing. The well was plugged and abandoned. Appraisal drilling to the south of Legendre 1 defined the southwestern extent of the oil field (Figure 1)—just south of the Release Area—and after 10 years of production the Legendre oil field was decommissioned in 2011.

Talisman 1 (1984)

Talisman 1 was drilled by Marathon Petroleum Australia Limited primarily to test Tithonian sandstones within an anticlinal closure, whilst also targeting deeper Kimmeridgian–Oxfordian and Lower Jurassic sandstones within the underlying fault block (Marathon Petroleum Australia Ltd, 1984). The well was drilled in 78 m water depth and reached TD at 2924 mRT. The Lower Cretaceous to Tithonian sandstones had significant hydrocarbon shows with Drill Stem Tests (DSTs) over three zones flowing oil. Talisman 1 was an oil discovery and with the drilling of subsequent wells (Talisman 2–7) defined a producing oil field, which ceased production in 1992—the small Amulet oil field to its east remains undeveloped.

Forestier 1 (1986)

Forestier 1 was drilled by Woodside Offshore Petroleum Pty Ltd to test a low-relief, northeast-trending anticlinal trap with primary objective Tithonian sandstones and secondary objective Oxfordian sandstones (Woodside Offshore Petroleum Pty Ltd, 1987). The well was drilled in 43 m water depth and reached TD at 2514 mRT. A thin interval in the Tithonian sands was found to be gas-saturated and the well was plugged and abandoned as a gas discovery. In addition, geochemical analyses showed very good source rock quality within the Upper Jurassic to Lower Cretaceous section.

Coojong 1 (1992)

Coojong 1 was drilled by Ampolex Limited to test the hydrocarbon potential of seven objectives over 2000 m of relief in a structural rollover atop a block downthrown to the east (Ampol Exploration Limited, 1993). Although little closure over the rollover was expected for the Upper Cretaceous section, the M. australis Sandstone Member (Muderong Shale) was the shallowest objective. The well was drilled in 57 m water depth and reached TD at 2528 mRT. Of the ten potential reservoir intervals intersected, residual oil was found in the M. australis Sandstone Member, Aalenian–Toarcian sands and the Hettangian–Pliensbachian sands. The well was plugged and abandoned. Failure to host significant hydrocarbons for the deeper Lower Jurassic and Triassic section was attributed to poor charge from Jurassic source rocks, and for the Upper Jurassic section, poor or compromised seals.

Cherring 1 (1997)

Cherring 1 was drilled by Mobil Exploration to target the M. australis Sandstone Member (Muderong Shale) in an anticline of 4-way dip closure atop the Enderby Terrace (Mobil Exploration and Producing Australia Pty Ltd, 1999). Secondary sand targets at the Bathonian–Bajocian, Aalenian and Pliensbachian age level (Figure 2) were also objectives in the structure. The well was drilled in 60 m water depth and reached TD at 1950 mRT. A 12.3 m gas column was found in the M. australis Sandstone with biodegraded residual oil at its base, while weak oil shows were also detected in the secondary target, Pliensbachian sands. The well was plugged and abandoned as a gas discovery. Failure of the Jurassic objectives was attributed to the absence of a viable migration pathway from the Upper Jurassic source rocks in the Lewis Trough to the west (Figure 3).

Ajax 1/ST 1 (2003)

Ajax 1 was drilled by Apache Energy primarily to target the Oxfordian Eliassen Formation and, secondarily, Upper Jurassic Angel Formation sandstones, interpreted to be part of submarine fan complexes, in an anticline trap (Apache Energy, 2005a). The well was drilled in 55 m water depth and reached TD at 3350 mRT. A gross 8.8 m (net 4.9 m) oil column was found in the Eliassen Formation, as well as gas shows in the Forestier Claystone, based on log and pressure interpretations. The well was plugged and abandoned as an oil discovery. Subsequent appraisal found the secondary target, the Angel Formation to not be within closure.

Gungurru 1 (2004)

Gungurru 1 was drilled by Apache Energy to test a 4-way dip closure hosting the primary objective the upper M. australis Sandstone. Secondary objectives targeted middle to lower M. australis and Lower Cretaceous Sandstones (Apache Energy, 2005b). Closure is provided by differential compaction over a Cretaceous channel comprising lowstand sands. The well was drilled in 61 m water depth and reached TD at 1235 mRT. A 15.3 m gross hydrocarbon column (12.6 m gas over 2.7 m oil) was encountered in the upper M. australis sands, which have an average porosity of 28.9%. The well was plugged and abandoned as an oil and gas discovery, and defined oil and gas field outlines (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 W17-5 characteristics

Release Area W17-5 is located over the Carnarvon shelf and terrace geomorphic features in water depths of approximately 50–100 m, 95 km north of the nearest coast where the Murujuga, also known as the Burrup Peninsula, is located.
Seabed sediment is mainly composed of ooids and peloids (70–80%), with few biofragments, and 20–30% relict intraclasts (James et al, 2004). Sediment texture is described as carbonate sand and gravel, with very little mud.
Potential hazards include tropical cyclones.

Commonwealth marine reserves

Release Area W17-5 is located 70 km north of the Dampier Commonwealth Marine Reserve and 83 km northeast of Montebello Commonwealth Marine Reserve.

Key ecological features

Release Area W17-5 overlaps the Glomar Shoals key ecological feature (Falkner et al, 2009) and is also 9 km south of the ancient coastline at the 125 m depth contour. (www.environment.gov.au/webgis-framework/apps/ncva/ncva.jsf.

Biologically important areas

Release Area W17-5 overlaps, or is close to, the following biologically important areas (www.environment.gov.au/webgis-framework/apps/ncva/ncva.jsf):

Overlaps with the foraging and breeding area for Wedge-tailed Shearwater, between mid-August and April.
Overlaps with the Pygmy Blue Whale known distribution area.
Lies to the north of the Humpback Whale northern migration corridor.
Lies to the north of the summer Flatback Turtle internesting area.
Overlaps with the Whale Shark foraging area and northern migration along the 200 m isobath.

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

Heritage

No shipwrecks are listed in the area.

Release Area W17-6 characteristics

Release Area W17-6 is located over shelf geomorphic features in water depths of approximately 50 m, 50 km from the nearest coast to the south where the Murujuga, also known as the Burrup Peninsula, is located.
Seabed sediment is dominated by relict biofragmental carbonate sediments (Colwell and von Stackelberg, 1981; James et al, 2004; Baker et al, 2008), and its texture is described as carbonate sand and gravel, with very little mud (James et al, 2004).
Specific hazards are few, except for tropical cyclones.

Commonwealth marine reserves

Release Area W17-6 is located 37 km northwest of the Dampier Commonwealth Marine Reserve and 44 km east of Montebello Commonwealth Marine Reserve.

Key ecological features

Glomar Shoals, a key ecological feature, is located 25 km to the northeast of the area (www.environment.gov.au/webgis-framework/apps/ncva/ncva.jsf).

Biologically important areas

Release Area W17-6 includes the biologically important areas (www.environment.gov.au/webgis-framework/apps/ncva/ncva.jsf):

Foraging and breeding area for seabirds (overlapping, Fairy Tern and Wedge-tailed Shearwater, and, to the south of the area, Roseate Tern).
Overlapping, Humpback Whale, northern migration corridor extends 100 km out from the coast, late July to September, and known distribution and migration area for Pygmy Blue Whale.
Overlapping, Whale Shark foraging area along the 200 m isobath.

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

Fairy Tern

Roseate Tern

Wedge-tailed Shearwater

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.

Dampier Commonwealth Marine Reserve www.environment.gov.au/topics/marine/marine-reserves/north-west/dampier

Montebello Commonwealth Marine Reserve www.environment.gov.au/topics/marine/marine-reserves/north-west/montebello.

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

North West Atlas www.northwestatlas.org.

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

Interpreted Horizons and Faults for Seismic Survey 110. Carnarvon Basin. Dataset by Kennard et al, 2003.
Interpreted Horizons and Faults Data for Seismic Survey 101. Carnarvon Basin. 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.
Carnarvon Cretaceous-Tertiary Tie Report. Australian Geological Survey Organisation Record 1996/36 by Romine and Durrant, 1996.
1994 Barrow and Dampier Sub-basins Airborne Laser Fluorosensor (Mk III) Survey Interpretation Report. Australian Geological Survey Organisation Record 2001/16 by Cowley, 2001.
Barrow/Dampier, WA, 1993 (P597). Airborne Digital dataset by Richardson, 1993.
Survey 97: Operations Report for the Joint BMR/Woodside Petroleum High Resolution Seismic Program in the Dampier Sub-basin, October 1990. Bureau of Mineral Resources Record 1991/67 by O’Brien and Bickford, 1991.

Stratigraphy

Northern Carnarvon Basin Biozonation and Stratigraphy, 2013, 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. Dampier Sub-basin module. Australian Geological Survey Organisation Record 1993/31 by Spencer et al, 1993.
Australian Petroleum Accumulations Report. Carnarvon Basin, Western Australia. Australian Geological Survey Organisation Report by Felton et al, 1993.
Light Hydrocarbon Geochemistry of the WA-28-P Area, Dampier Sub-basin, Western Australia: Rig Seismic Survey 97: Project 121.19. Bureau of Mineral Resources Record1992/61 by O’Brien, 1992.

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

References

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