COOPER BASIN EXPLORATION OPPORTUNITY BLOCKS ... - MISA

COOPER–EROMANGA 

BASIN 

EXPLORATION OPPORTUNITIES 

BLOCKS CO98A–K 

COOPER 99 

October 1998

COOPER BASIN 

EXPLORATION OPPORTUNITY 

BLOCKS CO98-A to K 

Compiled by 

Elinor Alexander 

Petroleum Group 

OCTOBER 1998 

Cover photo: Sand dune in the Cooper Basin. Report book 98/00029 

© Department of Primary Industries and Resources South Australia, 1998 

This report is subject to copyright. Apart from fair dealing for the purposes of study, research, 

criticism or review as permitted under the Copyright Act, no part may be reproduced without 

written permission of the Chief Executive of Primary Industries and Resources South Australia.

CONTENTS 

EXECUTIVE SUMMARY ..............................................4 

EXPLORATION HISTORY ..............................................6 

GEOLOGICAL SUMMARY 

Eromanga Basin .................................................6 

Simpson Basin ..................................................8 

Cooper Basin ...................................................8 

Warburton Basin ................................................10 

PETROLEUM GEOLOGY 

Reservoirs ....................................................10 

Source rocks. ..................................................12 

Seals and plays .................................................13 

UNDISCOVERED POTENTIAL 

Introduction ...................................................13 

Cooper Basin gas ................................................13 

Cooper-Eromanga Basin oil. ..........................................14 

Results. .....................................................14 

INFRASTRUCTURE AND MARKETS 

Production facilities ...............................................14 

Services in the Cooper Basin ..........................................15 

Markets .....................................................15 

EXPLORATION ACCESS 

National Parks and Reserves ..........................................15 

Innamincka and Strzelecki Regional Reserves .................................17 

European heritage ...............................................17 

Aboriginal heritage ...............................................17 

Commonwealth Native Title Act 1993 .....................................17 

Environmental regulation ............................................17 

APPENDICES 

1. Block summaries ................................................21 

2. Data .......................................................57 

3. Licence application form and procedures. ...................................60 

FIGURES 

1. Cooper Basin location ..............................................5 

2. Eromanga Basin stratigraphy. ..........................................6 

3. Base Cretaceous, ‘C’ seismic horizon ......................................7 

4. Cooper Basin stratigraphy ............................................8 

5. Top Permian, ‘P’ seismic horizon ........................................9 

6. Warburton Basin stratigraphy. .........................................10 

7. Top Warburton Basin unconformity, ‘Z’ seismic horizon ...........................11 

8. Hydrocarbon plays schematic. .........................................13 

9. Pastoral leases and Regional Reserves, Cooper Basin region .........................16 

10. Native Title Claims, Cooper Basin region ...................................18 

11. Seismic line and well locations, ‘C’ horizon Block CO98 – A .........................20 

12. Seismic line and well locations, ‘C’ horizon Block CO98 – B .........................22

13. Seismic line and well locations, ‘C’ horizon Block CO98 – C .........................24 

14. Seismic line and well locations, ‘C’ horizon Block CO98 – D .........................28 

15. Seismic line and well locations, ‘C’ horizon Block CO98 – E .........................30 

16. Seismic line and well locations, ‘C’ horizon Block CO98 – F .........................36 

17. Seismic line and well locations, ‘C’ horizon Block CO98 – G .........................38 

18. Seismic line and well locations, ‘C’ horizon Block CO98 – H .........................42 

19. Seismic line and well locations, ‘C’ horizon Block CO98 – I .........................46 

20. Seismic line and well locations, ‘C’ horizon Block CO98 – J .........................50 

21. Seismic line and well locations, ‘C’ horizon Block CO98 – K .........................54 

TABLES 

1. First round acreage release blocks, Cooper Basin, 1998 .............................4 

2. Undiscovered recoverable Cooper Basin gas potential, billion cubic metres (tcf) ...............14 

3. Undiscovered recoverable Cooper Basin oil potential, million cubic metres (mmstb) .............14 

4. Major Cooper Basin pipelines .........................................14

PRIMARY INDUSTRIES AND RESOURCES 

SOUTH AUSTRALIA 

REPORT BOOK 98/00029 

COOPER BASIN EXPLORATION OPPORTUNITY 

BLOCKS CO98-A to K. 

Compiled by E.M. Alexander with contributions from J.G.G. Morton (PIRSA) – undiscovered potential, A.J. Hill (PIRSA) 

and C. Boreham (AGSO) – source rocks, D.I. Gravestock (PIRSA) – seals and traps, A. Sansome (PIRSA) – data, D. Ivic 

(PIRSA) – seismic data. 

Executive Summary 

The Cooper Basin is located 800 km north of Adelaide in a remote, sparsely populated desert environment. The Cooper region 

has been under licence continuously since 1954 and is currently held by Santos and partners – PELs 5 & 6 cover 67 000 km 2 . 

Since 1954, Santos and joint venture partners have drilled over 1200 exploration, appraisal and development wells. At 30 

September 1997, 85 gas fields with a total of 354 gas wells were on line and a combined total of 190 PJ (150 Bcf) of sales gas 

was sold in that year to market in SA and NSW. At 30 November 1997, 28 oil fields with a total of 118 oil wells were on line 

and approximately 0.6 million kL (3.8 mmbbl) of crude oil, 0.4 million kL (2.5 mmbbl) of condensate and 0.3 million tonnes of 

LPG were sold. 

On 28 February 1999, PELs 5&6 expire and the South Australian Government has decided that the Cooper Basin, exclusive of 

production (and potentially retention) tenements will be made available for competitive bidding. In order to facilitate this 

process, reviews of the legislative regime, data issues and a review of the necessity of access to existing processing plant and 

associated infrastructure have been conducted. 

The opening of the Cooper Basin to competitive bidding provides a unique opportunity for explorers. Advantages include 

established infrastructure and markets, proven play concepts, high wildcat discovery rates, access to detailed data and a 

government with a proven track record of facilitation of responsible petroleum exploration and development. 

The release of blocks CO98-A to K is the first in a phased acreage release in the Cooper Basin. The announcement of blocks 

before the expiry of PELs 5 & 6 is designed to ensure a smooth transition by minimising delays in new exploration in the 

Cooper Basin. 

Table 1. First round acreage release blocks, Cooper Basin, 1998. 

Block Area Last Drilled No. wells Seismic Line Basins and targets 

km 2 Acres (x 10 6 ) km 

CO-98A 4316 1.066 - 0 405 Eromanga, Simpson and Warburton Basins, oil 

CO-98B 4315 1.066 1963 1 508 Eromanga and Warburton Basin, oil 

CO-98C 4987 1.232 1989 9 2336 Eromanga, Cooper and Warburton Basin, oil 

CO-98D 4891 1.208 1984 2 1263 Eromanga, Simpson and Warburton Basins, oil 

CO-98E 1365 0.337 1997 11 2499 Eromanga, Cooper and Warburton Basins, oil 

CO-98F 2964 0.732 1967 2 1745 Eromanga, Cooper and Warburton Basins, oil 

CO-98G 2878 0.711 1991 3 2365 Eromanga, Cooper and Warburton Basins, oil 

CO-98H 1884 0.465 1996 7 2014 Eromanga, Cooper and Warburton Basins, oil 

CO-98I 2703 0.668 1996 1 1689 Eromanga, Cooper and Warburton Basins, oil 

CO-98J 3893 0.962 1987 5 3019 Eromanga, Cooper and Warburton Basins, oil 

CO-98K 5236 1.294 1970 4 1619 Eromanga, Cooper and Warburton Basins, oil 

Applications may be made for any or all of the areas CO98-A to K. Licences are offered on the basis of the most competitive 

work program. In the event that more than one area is offered to an applicant for licence, there is no obligation for the applicant 

to accept any or all of the offers. In addition, applications for this first release of acreage will in no way prejudice successful 

applications in future Cooper Basin acreage releases. 

Enquiries and applications for Petroleum Exploration Licences (PELs) may be addressed to: 

The Chief Executive PIRSA Telephone: IAC 61 8 8463 3204 

C/o Director, Petroleum Group Facsimile: IAC 61 8 8463 3229 

PIRSA Website: www.mines.sa.gov.au/petrol 

GPO Box 1671, 

Adelaide, SA, 5001 

AUSTRALIA 

Applications should be accompanied by a proposed five year work program, a map of the area applied for, a $2 240 application 

fee and details of the technical and financial resources of the applicant (an application form and summary guidelines are 

included in Appendix 3). 

4 

The closing date for CO989-A to K applications is 4.00 pm on 11 March 1999.

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EXPLORATION HISTORY 

The Cooper Basin forms the most significant element of 

Australia’s largest onshore oil and gas province (Fig. 1). 

Petroleum exploration commenced in the region in 1954 

with the granting of OEL 7 to R. Bristowe on behalf of 

Santos. Early exploration targeted the Cambro-Ordovician 

and in 1959 Innamincka 1 was drilled, following a 

reflection-refraction survey carried out over Innamincka 

Dome with Delhi Petroleum as operator. Additional 

reflection surveys over the ensuing years led to the discovery 

of gas in the Permian section in Gidgealpa 2 in 1963 and 

three years later the ‘giant’ Moomba gas field was 

discovered. One third of South Australia’s Cooper Basin 

gas reserves are in the Moomba and neighbouring Big Lake 

fields. The decision to generate the bulk of South Australia’s 

electricity from natural gas ensured the economic viability 

of constructing and operating the Moomba–Adelaide 

pipeline, and gas was first supplied to Adelaide in 1969. 

PELs 5 and 6 were granted to Delhi and Santos in 1969 to 

replace OELs 20 and 21. During 1973 an agreement was 

signed by the Cooper Basin Producers to supply gas for the 

New South Wales market and a pipeline was constructed 

linking Moomba and Sydney. 

The first Cooper Basin oil was discovered in Tirrawarra 

1 in 1970. The Tirrawarra field contains 80 per cent of 

known oil reserves in the SA region. Eromanga Basin oil 

was discovered in 1977 with an uneconomic flow from 

Poolowanna 1 (Poolowanna Trough) and the first economic 

oil flow was recorded from Strzelecki 3 in the following 

year. In order to market newly discovered oil and existing 

gas liquids, the Cooper Basin Liquids Project was initiated 

in 1980 and completed in stages from 1982 to 1984 at a cost 

of $1.4 billion. The project involved the construction of a 

high vapour pressure liquids pipeline from Moomba to a 

processing plant and storage and loading facilities at Port 

Bonython, as well as field development, oil collection and 

crude stabilisation facilities at Moomba. 

Shipments of crude oil and condensate commenced in 

1983 and LPG handling facilities were commissioned in 

July 1984. The establishment of these facilities enabled the 

Cooper Basin Producers to bring the wet gas reservoirs into 

production, which further enhanced production flexibility. 

In 1991 condensate production from Port Bonython was 

replaced by a full range naphtha, which has a greater market 

value. 

In 1991 a contract was signed for the sale of natural gas 

by the South–West Queensland Producers to South 

Australia. The gas is delivered to the South Australian 

market via a 190 km pipeline constructed by the Producers to 

link the Queensland gas fields with the Moomba processing 

facility and Moomba–Adelaide natural gas pipeline. An 

agreement was finalised between Santos on behalf of the 

Cooper Basin Producers and ICI in 1994 to supply ethane 

from Moomba to a petrochemical plant in Botany Bay. A 

pipeline was constructed and supply commenced in June 

1996. 

Since 1963, a total of 229 billion cubic metres (8.2 tcf) of 

recoverable raw gas and 6.9 million cubic metres (43.9 

million stocktank barrels) of recoverable oil have been 

discovered in the Cooper and Eromanga Basins in South 

Australia. 

6 

GEOLOGICAL SUMMARY 

Eromanga Basin 

The Eromanga Basin covers one million square 

kilometres of central-eastern Australia and contains the 

multi-aquifer system of the Great Artesian Basin. It 

unconformably overlies the Cooper and Warburton Basins. 

Eromanga Basin stratigraphy can be divided into three 

sequences – lower non-marine, marine and upper 

non-marine (Fig. 2). Exploration is concentrated on the 

productive lower non-marine sequence. 

The lowermost unit of the Eromanga Basin is the Early to 

Middle Jurassic Poolowanna Formation, which consists of 

interbedded siltstone, sandstone and coal, deposited in high 

sinuosity fluvial and floodplain environments. Poolowanna 

Formation intertongues with and is overlain by low sinuosity 

fluvial deposits of the Hutton and Algebuckina Sandstones. 

Basinward lateral equivalents of the Algebuckina Sandstone 

are Hutton Sandstone, Birkhead Formation, Adori 

Sandstone, Westbourne Formation, Namur Sandstone and 

Murta Formation. The Hutton, Adori and Namur 

Sandstones are similar in lithology and facies to the 

Algebuckina but with an additional volcaniclastic 

component in minor amounts. 

Middle to Late Jurassic Birkhead Formation consists of 

interbedded siltstone, coal and sandstone, Westbourne 

SYSTEM 

QUAT. 

CRETACEOUS TERTIARY 

JURASSIC 

AGE 

SERIES 

Late 

Early 

Late 

Middle 

Early 

Oodnadatta Formation 

Mackunda Formation 

Allaru Mudstone 

Coorikiana Sst. Toolebuc Formation 

Algebuckina 

Sandstone 

Bulldog Shale 

ROCK UNIT 

Millyera Formation and equivalent 

Yandruwantha Sand 

Namba Formation 

Eyre Formation 

Winton Formation 

Cadna-owie Formation 

Namur 

Sandstone 

Fig. 2. Eromanga Basin stratigraphy. 

Mount Howie 

Sandstone 

Wallumbilla 

Formation 

Murta Formation 

McKinlay Member 

Westbourne 

Formation 

Adori Sandstone 

Birkhead Formation 

Hutton Sandstone 

Poolowanna Formation 

GROUP 

MARREE 

SUBGROUP 

LAKE EYRE 


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Formation consists of interbedded siltstone and sandstone of 

Late Jurassic age. Murta Formation and McKinlay Member 

overlie and intertongue with the Namur Sandstone and 

consist of thinly interbedded siltstone, shale, sandstone 

deposited in a large lake which extended throughout the 

Cooper Basin region. The McKinlay Member is a lacustrine 

shoreface facies. 

Cadna-owie Formation records the transition into open 

marine conditions during the Early Cretaceous and consists 

of interbedded sandstone, siltstone and claystone with minor 

carbonate. The fluvio-deltaic Wyandra Sandstone Member 

is developed at the top of the Cadna-owie Formation. The 

contact between sandstones of the upper Cadna-owie 

Formation (Wyandra Sandstone Member) and overlying 

marine shales of the Bulldog Shale or Wallumbilla 

Formation approximates a prominent seismic reflector - the 

C horizon – which is mappable across the entire Eromanga 

Basin (Fig. 3). Formations of the Early Cretaceous (Aptian 

to Albian) are of secondary interest to petroleum exploration 

in the area and are not discussed in detail. The marine 

succession is overlain by the rapidly deposited upper 

non-marine sequence (Winton Formation) which consists of 

coal, floodplain and low sinuosity channel deposits. 

A period of erosion and deep weathering in the Late 

Cretaceous caused by a switch in drainage from the Cooper 

region to the Ceduna Depocentre on the rifted southern 

margin of the continent was followed by deposition of the 

non-marine Cainozoic Lake Eyre Basin. The modern 

landscape was formed during the Pliocene-Quaternary. 

Simpson Basin 

Non-marine Triassic sandstone, siltstone and shale of the 

Simpson Basin have been split into two formations. The 

Walkandi Formation is the older unit and consists of 

varicoloured interbedded shale, siltstone and minor 

sandstone. Pedogenic structures indicate fluctuation of the 

water table on a flood plain which was cut by high sinuosity 

fluvial channels. Walkandi Formation has been correlated 

with the Tinchoo Formation in the Cooper Basin, although 

Triassic palynological data are poor. 

Walkandi Formation is conformably overlain by Late 

Triassic Peera Peera Formation which consists of 

carbonaceous shale, coal and thin sandstone interbeds 

deposited in a high sinuosity fluvial environment. The Peera 

Peera Formation is correlated with the Cuddapan Formation 

in the Cooper Basin region based on well preserved, 

distinctive palynomorphs. 

Cooper Basin 

The intracratonic Cooper Basin represents a Late 

Carboniferous to Triassic depositional episode. It lies 

unconformably over early Palaeozoic sediments of the 

Warburton Basin and is overlain disconformably by the 

Eromanga Basin (Fig. 4). Three major troughs 

(Patchawarra, Nappamerri and Tenappera) are separated by 

structural ridges (Gidgealpa-Merrimelia-Innamincka (GMI) 

and Murteree) associated with the reactivation of 

northwest-directed thrust faults in the underlying Warburton 

Basin. These troughs contain up to 2500 m of 

Permo-Carboniferous to Triassic sedimentary fill overlain 

by as much as 1300 m of Jurassic to Tertiary cover. 

8 

The Cooper Basin unconformably overlies Warburton 

Basin sediments. The Late Carboniferous to Early Permian 

formations comprise, in ascending order, the Merrimelia 

Formation and Tirrawarra Sandstone which comprise a 

glaciofluvial system deposited on glacially sculpted flat 

lying to deformed Warburton Basin sediments and volcanics 

and intrusives. The Tirrawarra Sandstone represents low 

sinuosity fluvial to proglacial outwash deposits overlain by 

peat swamp, floodplain and high sinuosity fluvial facies of 

the Patchawarra Formation. 

Two lacustrine shale units (Murteree and Roseneath 

Shales) with intervening fluvio-deltaic sediments (Epsilon 

and Daralingie Formations) were deposited during a phase 

of continued subsidence. Early Permian uplift led to erosion 

of the Daralingie Formation and underlying units from 

basement highs. 

SYSTEM 

CAMBRO- 

ORDOVICIAN CARBON- 

JURASSIC- 

IFEROUS PERMIAN TRIASSIC CRETACEOUS 

CENOZOIC 

AGE 

SERIES 

Late 

Middle 

Early 

Late 

Early 

Late 

STAGE 

Norian to 

Rhaetian 

Carnian 

Ladinian 

Anisian 

Scythian 

Artinskian PP3 

Sakmarian 

Stephanian Asselian 

PALYNOLOGICAL 

ZONE 

LAKE EYRE BASIN 

EROMANGA BASIN 

PT5 

PT4 

PT3 

PT2 

Wimma 

Sandstone 

Member 

PT1 Callamurra 

Member 

Tatarian 

Kazanian 

PP6 

PP5 

Toolachee Formation 

Ufimian Daralingie 

Formation 

PP4 

Kungurian 

Roseneath Shale 

PP2 

PP1 

WARBURTON BASIN 

Fig. 4. Cooper Basin stratigraphy. 

ROCK UNIT 

Cuddapan Formation 

Tinchoo Formation 

Paning 

Member 

Epsilon Formation 

Arrabury 

Formation 

Murteree 

Shale 

Patchawarra Formation 

Tirrawarra Sandstone 

Merrimelia Formation 

GIDGEALPA GROUP NAPPAMERRI GROUP 

COOPER BASIN 

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Floodplain, peat swamp and high sinuosity fluvial facies 

of the Late Permian Toolachee Formation were deposited on 

the Daralingie unconformity surface and are overlain 

conformably by Late Permian to Early Triassic Arrabury 

Formation. The uppermost coal, approximating the top 

Permian is mapped as the ‘P’ seismic horizon (Fig. 5). The 

Arrabury Formation comprise floodplain and channel facies 

of the Callamurra, Paning and Wimma Sandstone Members, 

which are overlain by the Early Triassic Tinchoo Formation. 

In the northern Patchawarra Trough, the Cooper Basin is 

locally overlain by the Middle to Late Triassic Cuddapan 

Formation. Deposition in the region was terminated at the 

end of the Early Triassic with slight but widespread 

deformation, regional tilt and erosion. 

Warburton Basin 

The Cooper Basin is unconformably underlain by 

sediments and volcanics of the eastern Warburton Basin 

(Fig. 6). Warburton Basin sediments range from Cambrian 

to Ordovician; Devonian sediments have not been 

intersected in the Cooper Basin region of South Australia 

The eastern Warburton Basin is essentially a fold belt 

deformed during the Late Devonian-Carboniferous Alice 

Springs Orogeny intruded by mid-Carboniferous granitoids 

and subsequently buried to depths ranging from 1300 m to 

almost 4000 m. 

The eastern Warburton Basin contains a basal suite of 

acid-intermediate volcanics, tuff and agglomerate 

(Mooracoochie Volcanics), overlain by dolomitised shelfal 

limestone historically assigned to the basal Kalladeina 

Formation. A Middle to Late Cambrian carbonate shelf 

developed in the Coongie-Cuttapirie area, with a slope to the 

east. Several depositional sequences have been identified in 

the Kalladeina Formation typically with deep water shales 

overlain progressively by shallow water carbonate and 

clastic deposits. The Pando and Innamincka Formations 

continue this trend to shallow water depths as part of a 

deltaic complex with an extensive marine shelf sand. Black 

shale of the Dullingari Group with rare graptolites was 

deposited in the deep water Larapintine Sea which extended 

through the Warburton and Amadeus Basins to the Canning 

Basin. 

Middle to Late Ordovician shale and siltstone constitute 

the last preserved deposits of the eastern Warburton Basin. 

Early-Middle Carboniferous granitic intrusives (Big Lake 

Suite) beneath the Nappamerri and Wooloo Troughs were 

responsible for localised silicification and contact 

metamorphism of Cambrian country rock. A weathered 

zone up to 150 m thick has altered Warburton Basin strata 

and the granites in particular, immediately beneath the 

Cooper Basin unconformity. The unconformity at the top of 

the Warburton Basin is mapped as the ‘Z’ seismic horizon 

(Fig. 7). 

Structural style superimposed by compressional 

deformation during the Alice Springs Orogeny follows 

arcuate northeasterly trends imposed by northwest-directed 

thrust faults. Wrench fault zones have been mapped 

seismically in the Titan-Charo-Yanta area on the northwest 

flank of the Patchawarra Trough. Complex folding and 

faulting occur in some parts of the basin, but in many regions 

the Early Palaeozoic is almost flat lying. 

10 

AGE 

CARBONACEOUS–CRETACEOUS 

ORDOVICIAN 

CAMBRIAN 

Mid-Late 

Early 

Late 

Middle 

Early 

PROTEROZOIC 

ROCK UNIT 

COOPER–EROMANGA BASINS 

DULLINGARI 

Innamincka 

Formation 

Jena 

Basalt 

Fig. 6. Warburton Basin stratigraphy. 

Kalladeina 

Formation 

Mooracoochie 

Volcanics 

GROUP 

PETROLEUM GEOLOGY 

Reservoirs 


Principal reservoirs are good to excellent reservoir 

quality Hutton and Namur Sandstones (porosities up to 25%, 

permeability up to 2500 mD). Oil is also reservoired in fair 

to excellent quality sandstones in the Poolowanna and 

Birkhead Formations, McKinlay Member and Murta 

Formation. The Algebuckina Sandstone is a major artesian 

aquifer. The Cadna-owie Formation (Wyandra Sandstone 

Member) forms a significant oil reservoir in Queensland, 

however economic hydrocarbons have yet to be discovered 

in this unit within SA. 

Simpson Basin 

Sandstone beds within the Walkandi and Peera Peera 

Formation may form reservoirs in the eastern Simpson 

Basin. Where deeply buried in the Poolowanna Trough to 

the west, porosity and permeability have been severely 

reduced by silica overgrowths. 

Cooper Basin 

Multi-zone high sinuosity fluvial sandstones form poor 

to good quality reservoirs. The main gas reservoirs occur 

primarily within the Patchawarra Formation (porosities up 

to 23.8%, average 10.5% and permeability up to 2500 mD) 

and Toolachee Formation (porosities up to 25.3%, average 

12.4% and permeability up to 1995 mD). Shoreface and 

delta distributary sands of the Epsilon and Daralingie 

Formations are also important reservoirs. Oil is produced 

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principally from low sinuosity fluvial sands within the 

Tirrawarra Sandstone (porosities up to 18.8%, average 

11.1% and permeability up to 329 mD). Towards the margin 

of the Cooper Basin, oil is also produced from the 

Patchawarra Formation. 

The Callamurra Member of the Arrabury Formation is 

conventionally regarded as a regional seal but nevertheless 

contains economic oil and gas reservoirs in some areas and is 

a leaky seal in others. Low sinuosity fluvial sandstones of 

the Paning and Wimma Sandstone Members form economic 

oil and gas reservoirs and high sinuosity fluvial sandstone of 

the Tinchoo Formation reservoir oil. As yet, there have been 

no economic oil or gas fields discovered in the Cuddapan 

Formation in South Australia. 


Fractures in brittle siltstones (e.g. Dullingari Group in 

Lycosa 1) are capable of storing commercial oil and gas. 

Fracture patterns and their relation to pre-Cooper and 

post-Cooper Basin structure are currently being studied by 

PIRSA and NCPGG. 

Pando Formation sandstone has surprisingly high 

porosity (~10%) in view of its low stratigraphic position. It 

is glauconitic and zircon-rich and consequently has a high 

gamma ray response. Moolalla 1 gas is reservoired in this 

formation which extends from Pando in the west to Moomba 

in the northeast. 

Basal and middle Kalladeina Formation dolomites 

represent shelf limestones exposed to meteoric diagenesis 

during marine lowstands. Although minor gas shows have 

been recorded, porosity prediction has proved elusive, the 

dolomites and associated karst breccias proving tight when 

drilled. 

Sturt 6 oil was produced from weathered tuff which 

forms an extensive unit beneath the southwest Cooper 

Basin. The tuff, together with underlying agglomerate and 

lava, comprises the Mooracoochie Volcanics. Both the oil 

and gas originated from Permian source rocks. 

Source Rocks 

Both Cooper and Eromanaga Basin mature source rocks 

have actively contributed to oil accumulations in the region. 

Each oil accumulation needs to be considered on its merits 

with respect to the extent of ‘mixing’ from Permian and 

Mesozoic sources. 


Oil originated either in the Eromanga or the Cooper 

Basin or a mixture of both. Although it is recognised that 

Birkhead and Murta Formation sources exist, there is still 

considerable debate as to their extent and relative 

contribution. 

Potential source rocks of Jurassic and Early Cretaceous 

age contain Type II to Type III organic matter and have been 

shown to have maturities within the ‘oil window’ (onset of 

oil generation between vitrinite reflectance 0.65-0.7%). 

Significant suppression of Ro has been detected in some 

Eromanga Basin source rocks. Average TOC and pyrolysis 

yields are slightly lower for Eromanga source rocks 

compared to Permian source rocks. However, the Birkhead 

Formation contains the most hydrogen-rich organic matter 

and has an average TOC of 2.5% and S2 pyrolysis yield of 

12 

10.8 kg/tonne. The Poolowanna Formation shows fair to 

good source richness; the Westbourne Formation exhibits 

mainly fair source richness. 

Hydrocarbon extracts of Jurassic potential source rocks 

are paraffinic and waxy and similar to those from Permian 

sediments. This lack of distinction probably reflects only 

minor changes in organic facies and/or maturation histories 

or alternatively, reflects oil staining/contamination of 

Eromanga source rocks by migrating Permian 

hydrocarbons. 

Oils in Cretaceous reservoirs are often geochemically 

distinct from those in Jurassic reservoirs. They are typically 

light (45° API gravity), non-waxy, low sulphur, paraffinic 

crudes although waxy oils do occur. In Dullingari field, 

Murta Formation oils are thought to be locally sourced from 

Cretaceous source rocks. 

The marine Cretaceous sequence contains good potential 

source rocks, however it is considered immature for 

hydrocarbon generation. Clearly, more work needs to be 

done in order to distinguish local Eromanga Basin sourcing. 

Simpson Basin 

The Peera Peera Formation is rich in organic matter in 

the Poolowanna Trough to the west (TOC up to 5%) and is 

considered to be gas-prone, with modest oil generative 

potential. 

Cooper Basin 

Permian coal measures and shales are the principal 

hydrocarbon source rocks in the region and are dominated 

by Type III kerogens derived from higher plant 

assemblages. Oils and condensates are typically medium to 

light (30 to 60° API) and paraffinic, with low to high wax 

contents. Most Permian oils in Permian reservoirs contain 

significant dissolved gas and show no evidence of water 

washing. Gas composition is closely related to 

maturity/depth with drier gas occurring towards basin 

depocentres although there is strong geological control on 

hydrocarbon composition. 

The Patchawarra Trough contains the bulk of the oil and 

wet gas reserves consistent with local source rocks being in 

the ‘oil window’ while the hot Nappamerri Trough 

(40–50°C/km), underlain in part by granite, is overmature 

and contains mainly dry gas. 

Permian source rocks have average TOC and S2 

pyrolysis yields of 3.9% and 6.9 kg/tonne, respectively 

(excluding coals). Locally, the Toolachee Formation is the 

richest source unit. The Patchawarra Formation is 

considered the other major source unit especially the lower 

shales and coals. The lacustrine Murteree and Roseneath 

Shales appear to have little source potential. 

Together, the petrographic and geochemical evidence 

support coals and associated DOM as the effective source 

rocks capable of generating gas and minor oil, albeit in low 

yields. At maturity levels between 0.7-0.95% Ro, initial 

generation from the richer facies has led to partial filling of 

reservoirs with wet gas and oil. There is a sharp onset of 

significant hydrocarbon accumulation when the source 

reaches a maturity of 0.95% Ro. 

Thin, laterally discontinuous coals represent the best 

source rocks of the upper Nappamerri Group whilst shales

tend to be organically lean. Kerogen in formations of the 

lower Nappamerri Group tends to be oxidised and source 

rocks are humic-rich and gas-prone. 


Source rock quality of samples principally from the 

Kalladeina Formation is poor to fair. With the exception of 

anomalously low maturity indices from Kalladeina 1, the 

succession below 3000 m is late-mature to post-mature for 

oil. Organic matter is mainly Type II kerogen derived from 

marine algal/bacterial precursors. 

Seals and Plays 

Where the regional seal is thin or absent multiple oil and 

gas pools are stacked in coaxial Permian-Mesozoic 

structures and may occur from as low as the Patchawarra 

Formation to as high as the Murta Formation. Locally, 

Permian oil has migrated into Warburton Basin reservoirs on 

the basin margin and gas has migrated into fractured 

Ordovician reservoirs fringing the Allunga Trough. 


Trapping mechanisms are dominantly structural 

(anticlines with four–way dip closure or drapes over 

pre-existing highs) with a stratigraphic component (e.g. 

Hutton–Birkhead transition, Poolowanna facies, McKinlay 

Member and Murta Formation). Eromanga structures in 

South Australia are rarely filled to spill with oil – net oil 

columns are relatively thin compared to the height under 

closure (due to poor sealing characteristics). Seals consist of 

intraformational siltstones and shales of the Poolowanna, 

Birkhead and Murta Formations – no economic 

hydrocarbons have been discovered in SA above the Murta 

Formation. Where these units are absent, potential seals 

include Bulldog Shale and Wallumbilla Formation. 

Cooper Basin 

Anticlinal and faulted anticlinal traps have been relied on 

as proven exploration targets but potential remains high for 

discoveries in stratigraphic and sub-unconformity traps, 

especially where the Permian sediments are truncated by the 

overlying Eromanga Basin succession. Economic oil and 

gas are reservoired in the Nappamerri Group, paradoxically 

metres 

1000 

2000 

3000 

Source rock Shale 

Gas Sandstone 

Oil Carbonate 

Fig. 8. Hydrocarbon plays schematic. 

Cenozoic 

LAKE EYRE 


Jurassic- 

Cretaceous 

EROMANGA 


Permo- 

Triassic 

COOPER 


Cambro- 

Ordovician 

WARBURTON 


98-1407 

regarded as a regional seal to the Cooper Basin. 

Intraformational shale and coal form local seals in the major 

reservoir units. Beneath the Daralingie Unconformity are 

two important early Permian regional seals - the Roseneath 

and Murteree Shales. The Roseneath Shale is the top seal of 

the Epsilon Formation and the Murteree Shale seals the 

Patchawarra Formation. 


Cooper Basin reservoirs, source rocks and seals have 

been juxtaposed against elevated ridges of Warburton Basin 

rock by faulting or by original deposition. These ridges are 

potential lateral seals but may also be reservoirs. Ridges are 

composed of sandstone, shale, carbonate and volcanic units, 

which are fresh to severely altered by weathering and 

diagenesis (but not metamorphism). Dips vary from 

horizontal to vertical, and units range from massive to 

slightly to pervasively fractured, with weak to strong 

faulting and folding. Their competence as lateral seals is 

dependent upon a combination of lithologic and structural 

factors. 

Potential traps in the Warburton Basin include large 

hanging wall anticlines associated with northeasterly 

trending thrust faults and upthrown fault blocks on wrench 

fault zones. 

A thick impermeable weathered profile on the top 

Warburton unconformity surface forms a semi-regional seal 

and is distinguished on logs by its low uniform resistivity. 

UNDISCOVERED POTENTIAL 

Introduction 

The Cooper Basin is a mature petroleum province, 

however potential remains high for discoveries in 

stratigraphic and sub-unconformity traps, which have 

received increasing interest in the past five years. Pinchout 

plays along the margins of the Cooper Basin have been 

tested with commercial success. 3D seismic will have a 

critical role to play in delineating more subtle traps in the 

future. 

Remaining South Australian Cooper–Eromanga 

reserves estimated by Santos at 1 January 1997 were 2534 PJ 

of sales gas, 5.08 x 10 6 t of LPG, 5.61 x 10 6 kL of 

condensate, 5.33 x 10 6 kL of crude oil and 349 PJ of ethane. 

Undiscovered reserves of hydrocarbons have also been 

estimated by PIRSA, the Bureau of Resource Sciences 

(BRS) and Stratigraphic Research International AS 

(APRAS) to predict the undiscovered potential of the 

Cooper and Eromanga Basins. Results are summarised 

below. For more detail, refer to The Petroleum Geology of 

SA – Volume 4, Cooper Basin. 

Cooper Basin gas 

The present discovered recoverable raw gas reserves (as 

at 1/1/98) of the basin are 229 billion cubic metres (8.2 TCF) 

comprising 129 billion cubic metres (4.6 TCF) of produced 

gas and 101 billion cubic metres (3.6 TCF) of gas yet to be 

produced from known discoveries. The average recovery 

factor for gas fields is 64%. There have been 121 Cooper 

Basin gas fields discovered in South Australia to 1/1/98 from 

298 new field wildcats. 

13

Table 2. Undiscovered recoverable Cooper Basin gas potential, billion cubic metres (tcf). 

Method (gas) Low estimate Average estimate High estimate 

Basin analogue 108 (3.8) 192 (6.8) 277 (9.8) 

APRAS (average) 39 (1.4) 181 (6.4) 546 (19.4) 

Pareto 41 (1.5) 60 (2.1) 83 (3.0) 

Basin plays 0 (0) 25 (0.9) 215 (7.7) 

Lognormal 7 (0.3) 12 (0.4) 19 (0.7) 

Table 3. Undiscovered recoverable Cooper Basin oil potential, million cubic metres (mmstb). 

Method (oil) Low estimate Average estimate High estimate 

Basin analogue 14.8 (93.8) 20.2 (128.2) 25.6 (162.6) 

Basin plays 0 (0) 13.7 (87) 41.5 (264) 

Pareto 2.0 (12.9) 5.4 (34.3) 20.3 (127.6) 

Lognormal 0.3 (2.0) 1.6 (10.0) 4.3 (27) 

APRAS (average) 0 (0) 0 (0) 4.3 (27.2) 

Cooper–Eromanga Basin oil 

The present recoverable oil reserves (as at 1/1/98) of the 

basin are 6.9 million cubic metres (43.9 MMSTB) 

comprising 4.6 million cubic metres (29.1 MMSTB) of 

produced oil and 2.3 million cubic metres (14.8 MMSTB) of 

oil yet to be produced from known discoveries. The 

combined average primary and secondary recovery factor 

for oil fields is 21%. More than 80% of the oil reserves are 

contained in the Tirrawarra Field. There have been 25 

Cooper oil fields discovered in South Australia up to 1/1/98 

from 297 new field wildcats. In the overlying Eromanga 

Basin, there have been 33 oil fields discovered from 293 

wildcats (to 1/1/93). 

Results 

Potential (undiscovered) resources should not be 

compared to traditional Proved, Probable and Possible 

reserves in known discoveries. Undiscovered resources are 

calculated to give a quantitative indication of the potential of 

the basin, and require considerable exploration to establish 

their existence. The results of methods considered to be 

reasonably reliable are summarised below. 

Table 4. Major Cooper Basin pipelines 

14 

Some of the potential attributed to the Cooper Basin may 

have already been discovered in the Eromanga Basin. The 

current discovered recoverable oil reserves of the Eromanga 

Basin in the Cooper Basin region are 14.5 million cubic 

metres (92.5 mmstb). 

INFRASTRUCTURE AND MARKETS 

Production Facilities 

A total of 5090 km of pipeline have been laid to gas 

markets in SA and NSW and to the liquids load out facility at 

Port Bonython. Key pipelines are listed in Table 4 and 

shown on Figure 1. 

Gas emerges at the wellhead at pressures up to 

25000 kPa and temperatures up to 120°C. Gas from 

individual wells passes via field gathering systems 

(flowlines) to satellite stations which separate gas, free water 

and condensate. Evaporation ponds are used for water 

disposal. The essentially water-free gas and condensate pass 

to the Moomba treatment plant through trunklines. Crude 

oil is transported by either pipeline or truck to the Moomba 

plant. Currently, nine oil and eleven gas satellites are in 

PL Pipeline name Operator Product Length Pipe diam. MAOP Construction 

(km) (mm) KPa Period 

1 Moomba–Adelaide Epic Energy Sales gas 1065 560 7300 1968–69 

total 

+ 12 laterals various 1969–90 

2 Moomba – Port Bonython Epic Energy (under Liquids 659 356 10380 1982 

liquids line contract to Santos) 

5 South–West Queensland Santos Sales gas 92 400 1991–92 

7 Moomba–Sydney East Australian Pipelines Sales gas 101 864 6200 1976 

+ loop line 10 660 1984 

8 Moomba–Sydney ethane line East Australian Pipelines 101 219 15300 1996

operation in the Cooper and Eromanga Basins. 

Approximately 1010 km of trunklines and 1135 m of 

flowlines have been laid to date in the region. 

At the Moomba plant free condensate and water are 

initially removed from the raw gas at the slug catchers. The 

gas then proceeds to the Benfield unit to ensure that no 

greater than 3% by volume of CO2 remains in the sales gas 

stream. The gas is dehydrated at molecular sieves before it 

proceeds to the liquid recovery plant where 100% of the 

remaining condensate, 98% of the LPG (C3 and C4) and 

75% of the ethane are removed, leaving sales gas for 

Adelaide and Sydney with a heating value %.5 megajoules 

per cubic metre. The plant has been designed to process 25.4 

x 10 6 m 3 (902 mmcf) of raw gas and 6000 kL (42 000 bbl) of 

condensate and crude oil per day. Condensate, LPG, crude 

and some ethane are transported as a ‘cocktail’ via a pipeline 

to Port Bonython where they are separated and marketed. 

The feedstock delivered to Port Bonython is first 

sampled, filtered and metered to determine flow rates and 

composition. It is then pumped through a series of 

fractionating towers to separate ethane (which is used as fuel 

gas for the plant), propane, butane, light naphtha, 

intermediate naphtha, heavy naphtha, and reduced crude. 

Once cooled to ambient temperatures, the naphtha and 

reduced crude fractions are pumped to the blending section 

where they are mixed in precise ratios. The resulting two 

products, ‘naphtha’ and ‘crude oil’ are sent to storage tanks 

to await shipping. 

One destination for Cooper–Eromanga crude oil and 

condensate is the refinery at Port Stanvac, which supplies 

petroleum products mainly for the South Australian market. 

The refinery commenced operations in 1963 and the 

adjacent lubricating oil refinery began operations in 1976. 

The refinery does not have sufficient capacity to produce all 

the State’s requirements for motor spirit, and some must be 

imported from interstate. The main refinery products from 

Port Stanvac are LPG, solvents, motor gasoline, jet fuel, 

kerosene, diesel, lube oil base stocks for Australian and 

overseas markets, fuel oil and bitumen. 

Mini-refinery technology has proven itself viable in the 

Eromanga Basin at Eromanga in southwest Queensland, 

where the company, Inland Oil Refiners has been operating 

since 1985. The Eromanga mini refinery has a throughput 

capacity of 1500 barrels of crude per day and receives 

feedstock from a number of Eromanga Basin oil fields, 

including the Inland oilfield, discovered by the company in 

1994. The principal product is diesel, which is trucked 

across western Queensland to regional centres for 

marketing. Other products include automotive distillate, jet 

fuel, high quality kerosenes and specialised products for 

Mount Isa Mines. Heavy residues are processed in Brisbane. 

A mini-refinery located adjacent to the Port Bonython 

liquids plant produces 95 kL/day (600 bbl/day) of gasoline 

by refining naptha feedstock from the liquids plant. The 

mini-refinery supplies the northern Spencer Gulf region. 

Services in the Cooper Basin 

The northern part of South Australia is sparsely 

populated and relatively undeveloped due to its remoteness 

and harsh climate. The main primary industry in the region 

is cattle which are run on large pastoral leases. Eco-tourism 

is a growing industry in the region. The township of 

Innamincka is located 65 km from Moomba and offers a 

hotel, general store and light aircraft airstrip. The Birdsville 

and Strzelecki Tracks are unsealed, but provide access for 

heavy vehicle transport in the region. 

Accommodation and support facilities are located at 

Moomba, a fly in-fly out camp operated by the Cooper Basin 

Joint Venture. Access to these facilities is by arrangement 

with Santos Ltd. The Moomba Camp can accommodate 450 

people, with an additional 150 beds mothballed. A full range 

of support services is available at Moomba including 

logging, wireline, fraccing, cementing, transport, fuel 

supply, aviation and emergency services. The sealed airstrip 

is 1720 m long and able to accept medium-sized jets. 

Groundwater, extracted from the Great Artesian Basin 

aquifer system, is critical for petroleum operations in the 

region. There are two major aquifers, the lower occurs 

within the Algebuckina Sandstone and Cadna-owie 

Formation and provides hot (up to 100°C) good quality 

(TDS 1000 mg/l) artesian water. The upper aquifer 

comprises the Winton and Mackunda Formations and 

produces poorer quality water but is shallower. 

Markets 

A free market was introduced in 1988 for all oil and 

condensate produced in Australia. There is no restriction on 

imports or exports of crude oil or refined petroleum 

products. A similar regime has applied since 1991 for LPG. 

Markets for crude oil and condensate exist in South 

Australia and Australia and low sulphur light crude oils find 

a ready domestic and overseas market. 

Ex-field natural gas prices in SA are freely negotiated 

between buyer and seller. As a consequence of a gas reform 

process in Australia, regulatory policy impediments to the 

free trade in gas are being removed and the rights of access 

to gas transmission and reticulation pipelines have been 

provided, and direct negotiations between consumers and 

producers facilitated. The deliverability of a right of access 

to upstream facilities is also currently being reviewed. 

The Australian Gas Association study of future 

Australian gas supplies and demand forecasts that an 

Australian gas grid would be economic early next century. 

South Australia, with Moomba as a potential hub, is ideally 

placed to be a supplier to this grid when it eventuates. 

EXPLORATION ACCESS 

National Parks and Reserves 

A number of National Parks and Reserves have been 

created to conserve the best examples of vegetation and 

landforms in the region (Fig. 9). There are three types of 

South Australian reserves including Conservation Parks, 

National Parks and Regional Reserves. The conditions of 

access vary from park to park, based upon the type of reserve 

classification, the activity proposed and its likely impact on 

the environment. Access for petroleum exploration and 

production is allowed in all parks in the Cooper Basin region 

and in all regional reserves in the state. Access issues into 

the Coongie Lakes Control Zone are currently under review. 

15

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Innamincka and Strzelecki Regional 

Reserves 

These Regional Reserves provide for the conservation of 

wildlife and the natural or historic features of the land while, 

at the same time, permitting use of its natural resources. 

Petroleum and mineral exploration activity may take place 

provided that they are subject to controls consistent with the 

management plan for the reserve (much of the production in 

the Cooper Basin is sourced from the Innamincka Regional 

Reserve). 

Part of Block CO98-E lies within the Innamincka 

Regional Reserve, and part of Blocks CO98- H, I, J and K lie 

within the Strzelecki Regional Reserve (Fig. 9). 

Mineral and petroleum exploration licence applications 

for areas within Regional Reserves are processed by PIRSA 

but are referred to the Minister for Environment, Heritage 

and Aboriginal Affairs (MEHAA) for comment. 

Exploration work programs are discussed with DEHAA 

(Department for Environment, Heritage and Aboriginal 

Affairs) as a matter of policy. In the case of production 

tenements, approval must be given by the MEHAA. Failing 

Ministerial agreement, the issue is referred to the Governor 

for decision. 

In all other respects exploration and production is carried 

out under the provisions of the Petroleum Act and 

Regulations. 

Parts of the Cooper Basin (Fig. 9) are listed as wetlands 

of international significance under the Ramsar Convention 

(the 1971 Convention on Wetlands of International 

Importance). The Coongie Lakes and part of the Coopers 

Creek system have also been included in the Register of the 

National Estate (Fig. 9). 

European heritage 

A number of sites of European heritage significance such 

as historic buildings and structures and geological 

monuments occur in the region. These are indicated on the 

Environmental Sensitivity Maps available from PIRSA. 

The majority of the sites are small and easily avoided by 

exploration activities. 

Aboriginal heritage 

In South Australia it is an offence to disturb or destroy 

Aboriginal sites, objects or remains. Standard procedures for 

determining the presence of Aboriginal heritage prior to the 

commencement of activities have been determined. These 

procedures involve consulting with the relevant Aboriginal 

organisation and maintaining a watch for sites, objects or 

remains during activities. Generally the sites are no larger 

than a few hundred square metres and are easily avoided. 

Since the inception of the Aboriginal Heritage Act in 1988, 

there have been no conflicts between Aboriginal heritage 

sites and exploration or production activities in South 

Australia. 

Commonwealth Native Title Act 1993 

The Native Title Act 1993 was passed by Federal 

Parliament on 22 December 1993. The lengthy and complex 

Act provides statutory recognition and protection for the 

concept of native title as recognised by the High Court in the 

case of Mabo v Queensland in 1992. Native title means 

rights held by indigenous inhabitants of Australia at and 

since the time of European settlement - it differs from 

conventional titles. The nature of native title rights vary 

from group to group according to laws and customs, 

however there must be a sufficient and relevant connection 

to the land in question, continuous since 1836 in South 

Australia. Native title may include the right to camp or 

travel across land, rights to hunt, fish, gather food and take 

materials (timber, bark, ochre etc.) from the land. 

Applications by Aboriginal claimants are recorded in the 

Register of Native Title Claims. The National Native Title 

Tribunal (NNTT) makes determinations on applications 

under the Act. A National Native Title Register comprising 

a record of all approved determinations made by the NNTT, 

Federal Court, High Court, other Courts or Tribunals and 

recognised State/Territory arbitral bodies. 

The Premier of South Australia declared in April 1994 

that SA would enact State legislation to ensure that State 

laws were consistent with the Commonwealth’s Racial 

Discrimination Act and as far as appropriate, the Native 

Title Act, while retaining the option to challenge the Native 

Title Act in whole or in part to make it more workable and 

less complex. Late in 1994, a package of four Native Title 

Bills was introduced into the SA House of Assembly and 

were all passed. 

In 1995 a ‘safety net’ clause was introduced into the 

Petroleum Act which gives a licensee first right to any 

licence which may be terminated due to no fault of the 

licensee. 

Licence holders are encouraged to develop a dialogue 

with regard to Aboriginal Heritage and related matters, with 

Aboriginal people having associations with their licence 

area. 

Following passage of the Commonwealth Native Title 

Amendment Act, the South Australian Government is 

considering establishment of a legislative response. A 

number of options are available under the new 

Commonwealth legislation to develop alternate State 

procedures to handle Native Title matters. A public 

announcement of the State’s response is likely later in 1998. 

Current Native Title Applications in the Cooper Basin 

region are shown on Figure 10. 

Environmental regulation 

Environmental issues pertinent to petroleum exploration 

are well managed in SA, primarily through proper 

operational planning in the initial stages. In order to ensure 

that activities are undertaken in a manner which avoids or 

minimises environmental impacts, several documents are 

required before approval to commence operations is given. 

First a Declaration of Environmental Factors (DEF) is 

required from the licensee. This is the licensee’s assessment 

of the environmental impact of the proposed activity. A 

Code of Environmental Practice is also required by 

regulation. The code describes procedures that the 

proponent will adopt during the planning, field management 

and monitoring phases of the operation. 

Santos Ltd. and their joint venture partners, who are the 

major oil and gas producers within the Eromanga and 

Cooper Basin, have developed Codes of Environmental 

17

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Practice for exploration and production. The codes provide 

guidance to licensees on environmental issues that need to 

be taken into consideration in planning and undertaking 

exploration activities. These codes are currently being 

revised in a move towards an outcomes based approach. 

However in the interim they provide a standard acceptable to 

the Government. A company may either adopt these Codes 

or use its own Codes of Environmental Practice subject to 

approval by PIRSA. 

PIRSA is able to assist licensees by providing examples 

of the documentation and advising on their scope. To date 

there have been no significant concerns raised with regard to 

requirements to minimise the environmental impacts of their 

operations. 

The Codes are required to be reviewed regularly (at least 

every 3 years) to ensure techniques are up-to-date. All 

documentation is subject to regulation. A revision of the 

Petroleum Act is currently under way and any future 

documentation and operations will need to ensure the three 

prime objectives of exploration which are: 

1. undertake an appropriate planning and 

assessment process, 

2. avoid or minimise short to medium term 

impacts, 

3. avoid all long term impacts. 

19

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APPENDIX 1 – BLOCK SUMMARIES 

CO98-A 

Area 4316 km 2 

1.066 million acres 

Distance to Moomba 220 km 

Nearest producing field Fly Lake-Brolga gas field (160 km) 

Seismic surveys: 

Record Survey No. lines Total km 

1 60 ER01 1 60.8 

2 61 ER01 4 22.9 

3 62 ER02 44 184.8 

4 63 CP01 13 132.9 

5 79 ER01 1 3.5 

Total no. of lines 63 lines 

Total line km of seismic 404.9 km 

Previous drilling: 

Well Year Total depth Primary Status 

drilled (m) objective 

None drilled 

CO98-A seismic lines 

Survey Line km 

60 ER01 60-BM 60.8 

61 ER01 61-BM 15.4 

61 ER01 61-BM11 2.3 

61 ER01 61-BM17A 3.7 

61 ER01 61-BM24 .5 

62 ER02 62-B24J 3.3 

62 ER02 62-B24K 1.1 

62 ER02 62-B24L 1.7 

62 ER02 62-B24M 3.3 

62 ER02 62-B24N 3.3 

62 ER02 62-B25P 0.7 

62 ER02 62-B25R 3.1 

62 ER02 62-B26B 0.2 

62 ER02 62-B26C 3.3 

62 ER02 62-B26D 3.3 

62 ER0 2 62-B26E 3.3 

62 ER0 2 62-B26F 3.3 

62 ER0 2 62-B26G 3.4 

62 ER0 2 62-B26H 3.4 

62 ER0 2 62-B26J 3.3 

62 ER0 2 62-B26K 3.3 

62 ER0 2 62-B27B 3.4 

62 ER0 2 62-B27C 3.3 

62 ER0 2 62-B27D 3.3 

62 ER0 2 62-B27E 3.4 

62 ER0 2 62-B27F 3.4 

62 ER0 2 62-B27G 2.6 

62 ER0 2 62-B27H 3.4 


62 ER0 2 62-B29A 1.7 

62 ER0 2 62-B29B 18.5 

62 ER0 2 62-B29C 9.6 

62 ER0 2 62-B32A 3.3 

62 ER0 2 62-B32B 3.3 

62 ER0 2 62-B32C 1.3 

62 ER0 2 62-B32G 1.6 

62 ER0 2 62-B32H 3.3 

62 ER0 2 62-B32J 3.3 

62 ER0 2 62-B32K 1.7 

62 ER0 2 62-B33A 3.3 

62 ER0 2 62-B33J 3.3 

62 ER0 2 62-B33K 1.6 

62 ER0 2 62-B34A 3.3 

62 ER0 2 62-B34B 3.1 

62 ER0 2 62-B35A 3.1 

62 ER0 2 62-B35B 3.4 

62 ER0 2 62-BR17 12.0 

62 ER0 2 62-BR18 33.3 

62 ER0 2 62-BR30 1.2 

62 ER0 2 62-BR31 3.4 

63 CP0 1 63-BR24 3.1 

63 CP0 1 63-BR29 16.5 

63 CP0 1 63-BR31A 3.3 

63 CP0 1 63-BR31B 3.3 

63 CP0 1 63-BR31C 3.3 

63 CP0 1 63-BR31D 3.2 

63 CP0 1 63-BR31E 1.6 

63 CP0 1 63-BR44A 46.0 

63 CP0 1 63-BR44B 0.6 

63 CP0 1 63-BR45 6.3 

63 CP0 1 63-BR46 25.6 

63 CP0 1 63-BR47 13.2 

63 CP0 1 63-BR50 6.9 

79 ER01 79-QAG 3.5 

21

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CO98-B 




Nearest producing field Keleary oil field (110 km) 

Seismic lines: 


1 60 ER01 1 24.8 

2 62 ER02 1 5.7 

3 63 CP01 14 307.9 

4 65 CP01 1 17.6 

5 79 ER01 2 94.7 

6 84 CP12 2 58.1 

Total no. of lines 21 lines 

Total line km of seismic 508.7 km 




Putamurdie 1 1963 1,952.5 Cooper/ Abandoned 

Eromanga - 

Oil 

CO98-B seismic lines 


60 ER0 1 60-BC 24.8 

62 ER02 62-BR18 5.7 

63 CP0 1 63-BR18 33.0 

63 CP0 1 63-BR44B 20.7 

63 CP0 1 63-BR45 69.4 

63 CP0 1 63-BR46 7.8 

63 CP0 1 63-BR47 25.7 

63 CP0 1 63-BR48 12.1 

63 CP0 1 63-BR49 26.8 

63 CP0 1 63-BR50 12.2 

63 CP0 1 63-BR51 13.3 

63 CP0 1 63-BR52 13.6 

63 CP0 1 63-BR53 31.9 

63 CP0 1 63-BR54 16.0 

63 CP0 1 63-BR55 12.7 

63 CP0 1 63-BR56 12.7 

65 CP0 1 65-LH 17.6 

79 ER01 79-QAG 35.2 

79 ER01 79-QAM 59.5 

84 CP12 84-THR 36.4 

84 CP12 84-TKA 21.7 

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CO98-C 




Nearest producing field Keleary oil field (73 km) 



1 57 ER01 5 36.6 

2 58 ER02 1 65.9 

3 60 ER01 3 60.6 

4 66 ER01 1 25.9 

5 79 ER01 3 139.1 

6 81 CP05 12 223.0 

7 83 CPXX1 1 0.0 

8 84 CP12 4 34.4 

9 85 CP11 35 640.8 

10 85 CP21 9 109.8 

11 85 CPXX1 2 2.0 

12 85 CPXX2 4 3.9 

13 85 CPXX3 3 4.0 

14 86 CP11 4 50.1 

15 86 CP21 18 326.4 

16 86 CPXX1 2 2.9 

17 87 CP21 15 191.7 

18 87 CPXX1 1 1.2 

19 88 CP01 24 211.4 

20 88 CPXX1 4 8.8 

21 95 CP01 10 121.1 

22 96 CP01 9 76.4 

Total no. of lines: 166 lines 

Total line km of seismic: 2336.0 km 




Haddon Downs 1 

1986 2,011.9 Eromanga - Abandoned 

Oil 

Potiron 1 1988 2,171.7 Hutton - Oil Abandoned 

James 1 1988 2,548.4 Hutton/ Suspended 

Poolowanna - oil 

Oil 

Araburg 1 1989 2,394.5 Hutton/ Abandoned 

Nappamerri - 

Oil 

CO98-C seismic lines 


57 ER01 57HAD-A1 10.5 

57 ER01 57HAD-A2 0.4 

57 ER01 57HAD-A3 7.6 

57 ER01 7HAD-B 16.3 

57 ER01 57HAD-C 1.6 

58 ER02 58NAPP-A 65.9 

60 ER01 60-BC 21.7 

60 ER01 60-BC 25.6 

60 ER01 60-RAIN 13.4 

66 ER01 66-NH 25.9 

79 ER01 79-QAE 65.8 

79 ER01 79-QAM 40.7 


79 ER01 79-QAN 32.6 

81 CP05 81-QJL 19.9 

81 CP05 81-QJM 22.1 

81 CP05 81-QJN 25.3 

81 CP05 81-QJP 20.6 

81 CP05 81-QKK 14.4 

81 CP05 81-QKL 25.3 

81 CP05 81-QKM 17.0 

81 CP05 81-QKN 17.2 

81 CP05 81-QKP 12.4 

81 CP05 81-QKQ 26.1 

81 CP05 81-QKR 13.7 

81 CP05 81-QKS 9.0 

83 CPXX1 83-NJR 0.0 

84 CP12 84-TKA 31.8 

84 CP12 84-TNL 1.2 

84 CP12 84-TRH 0.8 

84 CP12 84-TRK 0.6 

85 CP11 85-YMF 3.5 

85 CP11 85-YMG 10.4 

85 CP11 85-YMH 10.1 

85 CP11 85-YMM 20.4 

85 CP11 85-YXD 17.0 

85 CP11 85-YXE 15.5 

85 CP11 85-YXF 21.0 

85 CP11 85-YXG 14.5 

85 CP11 85-YXH 14.0 

85 CP11 85-YXJ 5.0 

85 CP11 85-YXK 1.0 

85 CP11 85-YXL 19.0 

85 CP11 85-YXM 11.0 

85 CP11 85-YXN 11.0 

85 CP11 85-YXP 11.0 

85 CP11 85-YXQ 10.0 

85 CP11 85-YXR 10.4 

85 CP11 85-YXS 10.5 

85 CP11 85-YXT 10.0 

85 CP11 85-YXX 10.0 

85 CP11 85-YXY 10.0 

85 CP11 85-YXZ 10.0 

85 CP11 85-YYA 12.0 

85 CP11 85-YYB 29.9 

85 CP11 85-YYC 41.6 

85 CP11 85-YYD 26.9 

85 CP11 85-YYE 34.5 

85 CP11 85-YYF 9.0 

85 CP11 85-YYF 25.4 

85 CP11 85-YYG 38.2 

85 CP11 85-YYH 22.0 

85 CP11 85-YYJ 30.1 

85 CP11 85-YYK 38.0 

85 CP11 85-YYL 22.7 

85 CP11 85-YYM 35.5 

25


85 CP21 85-ZFH 8.9 

85 CP21 85-ZFJ 15.4 

85 CP21 85-ZFK 22.1 

85 CP21 85-ZFL 13.8 

85 CP21 85-ZFN 1.9 

85 CP21 85-ZFP 11.4 

85 CP21 85-ZFQ 11.3 

85 CP21 85-ZFR 11.6 

85 CP21 85-ZFS 13.5 

85 CPXX1 85-XMA 1.0 

85 CPXX1 85-XMB 1.0 

85 CPXX2 85-YZZ 1.0 

85 CPXX2 85-ZAA 1.0 

85 CPXX2 85-ZAB 1.0 

85 CPXX2 85-ZAC 0.9 

85 CPXX3 85-ZEE 1.0 

85 CPXX3 85-ZFT 2.0 

85 CPXX3 85-ZFW 1.0 

86 CP11 86-AFE 42.7 

86 CP11 86-AJX 2.0 

86 CP11 86-AJY 1.0 

86 CP11 86-AJZ 4.4 

86 CP21 86-AFD 41.4 

86 CP21 86-AFF 20.8 

86 CP21 86-AFG 8.5 

86 CP21 86-AFH 19.6 

86 CP21 86-AFJ 8.5 

86 CP21 86-AFK 8.5 

86 CP21 86-AFL 28.9 

86 CP21 86-AFM 9.8 

86 CP21 86-AFN 16.8 

86 CP21 86-AFP 25.8 

86 CP21 86-AFQ 33.8 

86 CP21 86-AFR 37.9 

86 CP21 86-AFS 10.5 

86 CP21 86-AFT 31.6 

86 CP21 86-AGX 3.9 

86 CP21 86-AGY 6.3 

86 CP21 86-AGZ 4.5 

86 CP21 86-AHA 9.3 

86 CPXX1 86-ZWP 1.9 

86 CPXX1 86-ZWQ 1.0 

87 CP21 87-BEP 9.1 

87 CP21 87-BEQ 8.5 

87 CP21 87-BER 9.0 

87 CP21 87-BES 9.0 

87 CP21 87-BET 6.5 

87 CP21 87-BGA 9.0 

87 CP21 87-BGB 9.0 

87 CP21 87-BGC 10.5 

87 CP21 87-BGD 14.0 

87 CP21 87-BGE 17.4 

87 CP21 87-BGF 14.1 

26 


87 CP21 87-BGG 13.6 

87 CP21 87-BGH 8.5 

87 CP21 87-BGJ 32.7 

87 CP21 87-BGK 20.9 

87 CPXX1 87-FFA 1.2 

88 CP01 88-BTP 9.0 

88 CP01 88-BTQ 6.8 

88 CP01 88-BTR 11.1 

88 CP01 88-BTS 10.9 

88 CP01 88-BTT 9.0 

88 CP01 88-BTW 9.0 

88 CP01 88-BTX 7.5 

88 CP01 88-BTY 5.5 

88 CP01 88-BTZ 16.2 

88 CP01 88-BWA 19.3 

88 CP01 88-BWB 2.0 

88 CP01 88-BWB 10.6 

88 CP01 88-BWC 9.5 

88 CP01 88-BWD 8.8 

88 CP01 88-BWE 8.8 

88 CP01 88-BWF 7.4 

88 CP01 88-BXE 5.4 

88 CP01 88-BXF 7.5 

88 CP01 88-BXG 7.9 

88 CP01 88-BXH 13.0 

88 CP01 88-BXJ 5.2 

88 CP01 88-BXK 4.2 

88 CP01 88-BXL 5.4 

88 CP01 88-BXM 11.7 

88 CPXX1 88-FSF 0.7 

88 CPXX1 88-FSH 3.9 

88 CPXX1 88-FSJ 2.3 

88 CPXX1 88-FSK 1.8 

95 CP01 95-FQN 6.0 

95 CP01 95-FQP 7.5 

95 CP01 95-FQQ 3.0 

95 CP01 95-FQQ 17.9 

95 CP01 95-FQR 25.0 

95 CP01 95-FQS 16.5 

95 CP01 95-FQT 18.0 

95 CP01 95-FQW 13.6 

95 CP01 95-FQX 6.4 

95 CP01 95-FQY 7.2 

96 CP01 96-GRJ 13.4 

96 CP01 96-GRK 13.0 

96 CP01 96-GRL 4.2 

96 CP01 96-GRM 14.4 

96 CP01 96-GRN 8.2 

96 CP01 96-GRP 8.1 

96 CP01 96-GRQ 8.1 

96 CP01 96-GSF 6.0 

96 CP01 96-GSG 1.1

CO98-D 



Distance to Moomba 160 

Nearest producing field Fly Lake-Brolga gas field (100 km) 

Seismic: 


1 61 ER01 2 36.4 

2 61 ER02 11 191.4 

3 62 ER02 57 532.1 

4 79 PE01 2 17.6 

5 82 CP01 13 374.0 

6 82 CP42 1 2.4 

7 83 CP31 9 72.8 

8 84 CP12 3 36.5 






Pandieburra 1 1963 2,210.7 Palaeozoic Abandoned 

Koonchera 1 1984 2,088.5 Eromanga - Abandoned 

Oil 

CO98-D seismic lines 


61 ER01 61-BM 35.3 

61 ER01 61-BM31 1.1 

61 ER02 61GAS-C3 56.6 

61 ER02 61GAS-I 24.5 

61 ER02 61GAS-J 51.6 

61 ER02 61GAS-K1 19.0 

61 ER02 61GAS-K2 4.6 

61 ER02 61GAS-U 6.4 

61 ER02 61GAS-V 6.5 

61 ER02 61GAS-W 6.4 

61 ER02 61GAS-X 3.3 

61 ER02 61GAS-Y 6.5 

61 ER02 61GAS-Z 6.1 

62 ER02 62-B15A 23.0 

62 ER02 62-B15B 18.2 

62 ER02 62-B16A 11.5 

62 ER02 62-B16B 25.2 

62 ER02 62-B19A 9.2 

62 ER02 62-B19B 8.2 

62 ER02 62-B19C 11.2 

62 ER02 62-B19D 5.5 

62 ER02 62-B22A 3.4 

62 ER02 62-B22B 3.4 

62 ER02 62-B22C 3.3 

62 ER02 62-B22H 2.6 

62 ER02 62-B22J 3.3 

62 ER02 62-B22K 3.4 


62 ER02 62-B22L 1.7 

62 ER02 62-B24C 3.3 

62 ER02 62-B24G 3.4 

62 ER02 62-B24H 3.3 

62 ER02 62-B25A 3.4 

62 ER02 62-B25B 3.3 

62 ER02 62-B25C 3.3 

62 ER02 62-B25G 3.4 

62 ER02 62-B25H 3.3 

62 ER02 62-B25K 1.1 

62 ER02 62-B25L 1.7 

62 ER02 62-B25M 3.3 

62 ER02 62-B25N 3.2 

62 ER02 62-B25P 2.6 

62 ER02 62-B26A 3.4 

62 ER02 62-B26B 3.2 

62 ER02 62-B27A 3.3 

62 ER02 62-B40A 6.0 

62 ER02 62-B40B 6.1 

62 ER02 62-BR11 15.7 

62 ER02 62-BR12 12.4 

62 ER02 62-BR13 21.2 

62 ER02 62-BR14 9.2 

62 ER02 62-BR17 36.7 

62 ER02 62-BR18 28.5 

62 ER02 62-BR2 12.2 

62 ER02 62-BR20 21.6 

62 ER02 62-BR21 5.4 

62 ER02 62-BR30 2.1 

62 ER02 62-BR36 5.0 

62 ER02 62-BR37 20.8 

62 ER02 62-BR38 11.6 

62 ER02 62-BR39 14.4 

62 ER02 62-BR4 36.3 

62 ER02 62-BR41 4.9 

62 ER02 62-BR42 10.5 

62 ER02 62-BR43 14.3 

62 ER02 62-BR5 9.3 

62 ER02 62-BR6 5.8 

62 ER02 62-BR7A 9.7 

62 ER02 62-BR8A 18.1 

62 ER02 62-BR8B 7.1 

62 ER02 62-BR9 6.1 

79 PE01 79-WDB 8.8 

79 PE01 79-WDB 8.8 

82 CP01 82-QNA 56.4 

82 CP01 82-QNB 84.8 

82 CP01 82-QNC 39.8 

82 CP01 82-QND 32.7 

82 CP01 82-QNE 11.0 

82 CP01 82-QNF 7.8 

82 CP01 82-QNG 16.2 

82 CP01 82-QNH 21.0 

27

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82 CP01 82-QNJ 21.0 

82 CP01 82-QNK 20.2 

82 CP01 82-QNL 12.0 

82 CP01 82-QNM 33.6 

82 CP01 82-QNN 17.5 

82 CP42 82-LMG 2.4 

83 CP31 83-NGK 15.9 

83 CP31 83-NGL 10.9 

83 CP31 83-NGM 5.6 

83 CP31 83-NGN 7.1 

83 CP31 83-NGP 7.1 

83 CP31 83-NGQ 7.1 

83 CP31 83-NGR 6.4 

83 CP31 83-NQY 3.2 

83 CP31 83-NQZ 9.5 

84 CP12 84-SFR 29.3 

84 CP12 84-SFS 6.1 

84 CP12 84-SGB 1.2 

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Nearest producing field Keleary and Telopea PPLs lie in 

block area 



1 58 ER02 1 8.3 

2 63 CP01 3 21.5 

3 66 ER01 4 83.6 

4 67 CP01 3 46.7 

5 69 CPXX1 1 0.0 

6 70 CP01 4 48.2 

7 70 CP08 2 24.2 

8 73 CP01 2 23.5 

9 78 CP01 7 185.1 

10 79 CP01 5 50.0 

11 80 CP02 22 263.0 

12 80 PEXX2 1 0.8 

13 81 CP04 23 208.9 

14 83 CP31 9 61.3 

15 84 CP12 9 118.6 

16 84 CPXX5 3 6.7 

17 85 CP11 8 73.4 

18 85 CP21 7 60.5 

19 85 CPXX1 1 1.0 

20 87 CP21 3 2.8 

21 88 CP01 10 37.2 

22 88 CPXX1 1 3.7 

23 89 CP01 3 18.8 

24 91 CP11 20 131.0 

25 92 CP01 2 5.3 

26 94 CP01 10 58.1 

27 94 CP10 5 29.7 

28 94 CP21 6 22.8 

29 95 CP01 6 44.4 

30 95 CP05 2 8.0 

31 96 CP01 39 539.9 

32 96 CP02 47 237.0 

33 97 CP01 20 221.1 






Paning 1 1980 3,181.5 Cooper Oil & Abandoned 

Gas 

Kenny 1 1984 3,038.5 Eromanga - Abandoned 

Oil 

Walkillie 1 1984 2,748.6 Eromanga - Abandoned 

Oil 

Keleary 1 1991 2,634.3 Tinchoo - Oil Producer 

Keleary 2 1994 2,533.5 Tinchoo - Oil Producer 

Telopea 1 1994 2,747.2 Birkhead/ Producer 

Hutton/ 

Poolowanna - 

Oil 

Caraway 1 1995 2,729.8 Birkhead/ Abandoned 

Hutton/ 

Tinchoo - Oil 

Telopea 2 1995 2,727.9 Tinchoo - Oil Producer 

Reg Sprigg 1 1996 2,542.9 Basal Hutton/ Suspended 

Birkhead/ 

Poolowanna - 

Oil 

Streeton 1 1997 2,852.9 Confidential Abandoned 

CO98-E seismic lines 


58 ER02 58NAPP-A 8.3 

63 CP01 63-PE1 8.1 

63 CP01 63-PE3 12.8 

63 CP01 63-PE6 0.6 

66 ER01 66-NF 27.5 

66 ER01 66-NG 21.8 

66 ER01 66-NI 18.2 

66 ER01 66-NK 16.1 

67 CP01 67-RP 11.3 

67 CP01 67-RQ 21.7 

67 CP01 67-RR 13.7 

69 CPXX1 69-ODL 0.0 

70 CP01 70-FTA 17.4 

70 CP01 70-FTB 19.9 

70 CP01 70-FTQ2 7.7 

70 CP01 70-FTR 3.2 

70 CP08 70-FDH 6.5 

70 CP08 70-FDI 17.7 

73 CP01 73-EAD 12.0 

73 CP01 73-EBM 11.5 

78 CP01 78-JPL 49.2 

78 CP01 78-JPM 34.9 

78 CP01 78-JPR 37.9 

78 CP01 78-JPS 16.9 

78 CP01 78-JPT 22.5 

78 CP01 78-JPU 17.8 

78 CP01 78-JPV 5.9 

79 CP01 79-JUH 11.8 

79 CP01 79-JUJ 15.1 

79 CP01 79-JUK 9.9 

79 CP01 79-JUL 5.7 

79 CP01 79-JUM 7.5 

80 CP02 80-JXN 26.7 

80 CP02 80-JXP 1.8 

80 CP02 80-JXR 10.3 

80 CP02 80-JXS 8.4 

80 CP02 80-JXT 13.1 

80 CP02 80-JXW 14.5 

80 CP02 80-JXX 8.5 

80 CP02 80-JXY 10.0 

80 CP02 80-JXZ 23.0 

80 CP02 80-JYA 12.0 

80 CP02 80-JYB 34.0 

80 CP02 80-JYC 8.9 

80 CP02 80-JYE 9.0 

80 CP02 80-JYF 7.6 

80 CP02 80-JYG 8.5 

80 CP02 80-JYH 9.1 

80 CP02 80-JYH 15.2 

80 CP02 80-JYJ 4.3 

80 CP02 80-JYT 17.4 

80 CP02 80-JYW 9.7 

31


80 CP02 80-JZA 4.2 

80 CP02 80-JZB 6.9 

80 PEXX2 80-QFH 0.8 

81 CP04 81-KNW 0.8 

81 CP04 81-KNX 0.9 

81 CP04 81-KQA 16.0 

81 CP04 81-KQB 27.8 

81 CP04 81-KQC 21.3 

81 CP04 81-KQD 13.4 

81 CP04 81-KQE 3.5 

81 CP04 81-KQF 0.7 

81 CP04 81-KQF 15.0 

81 CP04 81-KQG 25.4 

81 CP04 81-KQH 22.0 

81 CP04 81-KQJ 10.5 

81 CP04 81-KQK 5.5 

81 CP04 81-KQL 14.4 

81 CP04 81-KQM 5.3 

81 CP04 81-KQN 1.9 

81 CP04 81-KQP 7.7 

81 CP04 81-KQQ 0.1 

81 CP04 81-KQR 4.6 

81 CP04 81-KQS 5.1 

81 CP04 81-KQT 3.8 

81 CP04 81-KQW 0.4 

81 CP04 81-KQW 2.7 

83 CP31 83-NEJ 0.1 

83 CP31 83-NZH 4.4 

83 CP31 83-NZJ 4.4 

83 CP31 83-NZK 3.0 

83 CP31 83-NZL 3.0 

83 CP31 83-NZM 3.1 

83 CP31 83-NZP 16.4 

83 CP31 83-NZQ 14.3 

83 CP31 83-NZR 12.6 

84 CP12 84-THW 12.5 

84 CP12 84-THX 9.8 

84 CP12 84-THY 15.0 

84 CP12 84-THZ 15.4 

84 CP12 84-TNG 8.5 

84 CP12 84-TNH 8.6 

84 CP12 84-TNJ 11.2 

84 CP12 84-TNK 11.1 

84 CP12 84-TNL 26.5 

84 CPXX5 84-XAY 1.1 

84 CPXX5 84-XAZ 3.7 

84 CPXX5 84-XBB 1.8 

85 CP11 85-YMF 13.9 

85 CP11 85-YMG 4.0 

85 CP11 85-YMH 3.6 

85 CP11 85-YMM 7.1 

85 CP11 85-YYW 19.0 

85 CP11 85-YYX 7.6 

32 


85 CP11 85-YYY 8.6 

85 CP11 85-YYZ 9.6 

85 CP21 85-ZFG 8.3 

85 CP21 85-ZFH 7.5 

85 CP21 85-ZFJ 12.3 

85 CP21 85-ZFP 8.8 

85 CP21 85-ZFQ 7.8 

85 CP21 85-ZFR 6.7 

85 CP21 85-ZFS 9.2 

85 CPXX1 85-XMC 1.0 

87 CP21 87-BEP 0.9 

87 CP21 87-BEQ 1.5 

87 CP21 87-BET 0.5 

88 CP01 88-BTQ 1.2 

88 CP01 88-BTS 0.1 

88 CP01 88-BWF 1.4 

88 CP01 88-BWH 6.1 

88 CP01 88-BWJ 6.8 

88 CP01 88-BWK 5.1 

88 CP01 88-BWL 3.9 

88 CP01 88-BWP 1.6 

88 CP01 88-BWQ 2.3 

88 CP01 88-BWR 8.9 

88 CPXX1 88-FSL 3.7 

89 CP01 89-CGW 8.1 

89 CP01 89-CGX 7.6 

89 CP01 89-CGY 3.1 

91 CP11 91-DFE 13.7 

91 CP11 91-DFF 8.1 

91 CP11 91-DFG 11.6 

91 CP11 91-DFH 10.1 

91 CP11 91-DGF 2.0 

91 CP11 91-DGG 5.1 

91 CP11 91-DGH 4.4 

91 CP11 91-DGJ 4.4 

91 CP11 91-DGK 4.4 

91 CP11 91-DGL 4.7 

91 CP11 91-DGM 4.4 

91 CP11 91-DGN 4.4 

91 CP11 91-DGP 7.6 

91 CP11 91-DGQ 8.9 

91 CP11 91-DGR 5.8 

91 CP11 91-DGS 5.8 

91 CP11 91-DGZ 13.1 

91 CP11 91-DHA 7.1 

91 CP11 91-DHB 3.9 

91 CP11 91-DHC 1.5 

92 CP01 92-DZD 0.4 

92 CP01 92-DZE 4.9 

94 CP01 94-EXP 5.5 

94 CP01 94-EXQ 6.2 

94 CP01 94-EXR 6.3 

94 CP01 94-EXS 6.3


94 CP01 94-EXT 8.9 

94 CP01 94-EXW 4.0 

94 CP01 94-EXX 7.0 

94 CP01 94-EXY 3.1 

94 CP01 94-EXZ 4.6 

94 CP01 94-EYA 6.0 

94 CP10 94-FCY 4.8 

94 CP10 94-FCZ 4.5 

94 CP10 94-FDA 4.4 

94 CP10 94-FDB 6.0 

94 CP10 94-FDC 10.0 

94 CP21 94-FJM 1.5 

94 CP21 94-FJN 3.1 

94 CP21 94-FJP 3.1 

94 CP21 94-FJQ 3.3 

94 CP21 94-FJR 3.7 

94 CP21 94-FJX 8.1 

95 CP01 95-FSN 7.8 

95 CP01 95-FSP 10.2 

95 CP01 95-FSQ 7.7 

95 CP01 95-FSR 6.9 

95 CP01 95-FSS 5.9 

95 CP01 95-FST 5.9 

95 CP05 95-FYK 3.1 

95 CP05 95-FYL 4.9 

96 CP01 96-GJG 31.0 

96 CP01 96-GJH 26.0 

96 CP01 96-GJJ 34.2 

96 CP01 96-GJK 28.0 

96 CP01 96-GJN 2.1 

96 CP01 96-GJP 5.2 

96 CP01 96-GJQ 7.9 

96 CP01 96-GJR 10.2 

96 CP01 96-GJS 13.1 

96 CP01 96-GJT 15.0 

96 CP01 96-GJW 32.6 

96 CP01 96-GJX 30.0 

96 CP01 96-GJY 23.1 

96 CP01 96-GJZ 17.2 

96 CP01 96-GKA 23.1 

96 CP01 96-GKB 20.1 

96 CP01 96-GKC 23.1 

96 CP01 96-GKD 27.8 

96 CP01 96-GKE 20.1 

96 CP01 96-GKF 16.5 

96 CP01 96-GRR 4.6 

96 CP01 96-GRS 2.7 

96 CP01 96-GRT 3.5 

96 CP01 96-GRW 6.3 

96 CP01 96-GRX 5.4 

96 CP01 96-GSF 8.1 

96 CP01 96-GSG 16.5 

96 CP01 96-HHC 11.1 


96 CP01 96-HHD 6.6 

96 CP01 96-HHE 11.7 

96 CP01 96-HHF 9.6 

96 CP01 96-HHG 3.6 

96 CP01 96-HHH 8.0 

96 CP01 96-HHJ 6.9 

96 CP01 96-HHK 5.4 

96 CP01 96-HHL 4.9 

96 CP01 96-HHM 4.5 

96 CP01 96-HHN 8.5 

96 CP01 96-HHP 5.6 

96 CP02 96-RS200 3.0 

96 CP02 96-RS204 3.0 

96 CP02 96-RS208 3.0 

96 CP02 96-RS212 3.0 

96 CP02 96-RS216 3.0 

96 CP02 96-RS220 3.0 

96 CP02 96-RS224 3.5 

96 CP02 96-RS232 3.5 

96 CP02 96-RS236 3.5 

96 CP02 96-RS240 3.5 

96 CP02 96-RS244 3.5 

96 CP02 96-RS248 3.5 

96 CP02 96-RS252 3.5 

96 CP02 96-RS256 3.5 

96 CP02 96-RS260 3.5 

96 CP02 96-RS264 4.1 

96 CP02 96-RS268 4.1 

96 CP02 96-RS272 4.1 

96 CP02 96-RS276 4.1 

96 CP02 96-RS280 4.1 

96 CP02 96-RS284 4.1 

96 CP02 96-RS288 4.1 

96 CP02 96-RS292 4.1 

96 CP02 96-RS296 4.1 

96 CP02 96-RS300 4.1 

96 CP02 96-RS304 4.1 

96 CP02 96-RS308 4.1 

96 CP02 96-RS312 4.1 

96 CP02 96-RS316 4.1 

96 CP02 96-RS320 4.1 

96 CP02 96-RS324 4.1 

96 CP02 96-RS636 8.7 

96 CP02 96-RS644 8.7 

96 CP02 96-RS652 8.7 

96 CP02 96-RS660 8.7 

96 CP02 96-RS668 8.7 

96 CP02 96-RS676 8.7 

96 CP02 96-RS684 8.7 

96 CP02 96-RS692 8.7 

96 CP02 96-RS700 8.7 

96 CP02 96-RS708 8.7 

96 CP02 96-RS716 8.7 

33


96 CP02 96-RS724 7.0 

96 CP02 96-RS732 7.0 

96 CP02 96-RS740 4.4 

96 CP02 96-RS748 4.2 

97 CP01 97-HMH 5.6 

97 CP01 97-HMJ 12.3 

97 CP01 97-HMK 6.0 

97 CP01 97-HML 16.5 

97 CP01 97-HMM 18.6 

97 CP01 97-HMN 15.2 

97 CP01 97-HMP 12.8 

97 CP01 97-HMQ 18.0 

97 CP01 97-HMR 3.2 

97 CP01 97-HMR 27.3 

97 CP01 97-HMS 18.0 

97 CP01 97-HMT 18.0 

97 CP01 97-HPK 0.6 

97 CP01 97-HXG 1.9 

97 CP01 97-HXH 2.1 

97 CP01 97-HYT 7.5 

97 CP01 97-HYW 7.1 

97 CP01 97-HYX 8.0 

97 CP01 97-HYY 11.0 

97 CP01 97-HYZ 11.6 

34

CO98-F 




Nearest producing field Leleptian gas field (60 km) 

Seismic lines: 


1 61 ER02 1 13.1 

2 62 ER02 3 55.8 

3 63 CP01 1 2.9 

4 64 CP01 1 18.4 

5 65 CP01 2 88.9 

6 66 ER01 8 109.4 

7 67 CP01 3 28.4 

8 69 CP04 15 132.5 

9 76 CP01 1 8.6 

10 77 CP01 4 37.7 

11 81 CP04 5 30.0 

13 82 CP02 3 71.9 

14 82 CP42 5 38.5 

15 83 CP31 2 14.1 

16 84 CP12 25 489.9 

17 85 CP11 9 80.7 

18 87 CP11 5 39.7 

19 87 CP21 2 2.2 

20 88 CP01 18 102.0 

21 89 CP01 3 4.1 

22 91 CP11 2 3.5 

23 92 CP01 13 186.9 

24 95 CP01 11 88.8 

25 97 CP01 1 2.1 






Kalladeina 1 1967 3,761.5 Cambrian Abandoned 

Hoolendinnie 1 1998 1,850.1 Confidential Abandoned 

CO98-F seismic lines 


61 ER02 61GAS-Q 13.1 

62 ER02 62-BR6 9.6 

62 ER02 62-BR7B 30.1 

62 ER02 62-BR8B 16.1 

63 CP01 63-AN 2.9 

64 CP01 64-CV 18.4 

65 CP01 65-FV 80.1 

65 CP01 65-FY 8.9 

66 ER01 66-MA 32.1 

66 ER01 66-MB 33.8 

66 ER01 66-MC 1.1 

66 ER01 66-MC 8.7 

66 ER01 66-MD 15.2 

66 ER01 66-MH 7.1 

66 ER01 66-MI 2.8 

66 ER01 66-NE 8.6 


67 CP01 67-SJ 9.8 

67 CP01 67-SK 17.3 

67 CP01 67-SR 1.3 

69 CP04 69-PWT 1.2 

69 CP04 70-PWU 22.5 

69 CP04 70-PWV 19.3 

69 CP04 70-PWW 6.8 

69 CP04 70-PWW 11.8 

69 CP04 70-PWX 1.8 

69 CP04 70-PWX 5.6 

69 CP04 70-PWZ 11.5 

69 CP04 70-PXA 1.9 

69 CP04 70-PXB 6.9 

69 CP04 70-PXI 1.3 

69 CP04 70-PXJ 6.6 

69 CP04 70-PXK 17.7 

69 CP04 70-PXL 9.3 

69 CP04 0-PXM 8.1 

76 CP01 76-JEL 8.6 

77 CP01 77-JLM 5.3 

77 CP01 77-JLN 16.7 

77 CP01 77-JLP 8.5 

77 CP01 77-JLQ 7.2 

81 CP04 81-KRF 30.3 

81 CP04 81-KRG 16.4 

81 CP04 81-KRL 16.0 

81 CP04 81-KRM 16.1 

81 CP04 81-KRN 16.3 

82 CP01 82-QNC 5.2 

82 CP01 82-QND 7.2 

82 CP01 82-QNF 6.4 

82 CP01 82-QNG 2.7 

82 CP01 82-QNM 8.5 

82 CP02 81-KRE 29.3 

82 CP02 1-KRH 25.7 

82 CP02 81-KRK 16.9 

82 CP42 82-LME 21.5 

82 CP42 82-LMF 1.5 

82 CP42 82-LNG 6.0 

82 CP42 82-LNH 6.8 

82 CP42 82-LNJ 2.7 

83 CP31 83-NQT 13.6 

83 CP31 83-NQW 0.5 

84 CP12 84-SFR 40.3 

84 CP12 84-SFS 5.8 

84 CP12 84-SFS 56.2 

84 CP12 84-SFT 3.4 

84 CP12 84-SFT 66.3 

84 CP12 84-SFW 69.2 

84 CP12 84-SFX 22.3 

84 CP12 84-SFX 22.3 

84 CP12 84-SFY 1.8 

84 CP12 84-SFY 3.9 

35

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84 CP12 84-SFY 20.4 

84 CP12 84-SFZ 2.3 

84 CP12 84-SGA 39.1 

84 CP12 84-SGB 35.6 

84 CP12 84-SGC 22.1 

84 CP12 84-SGD 16.2 

84 CP12 84-TRZ 8.3 

84 CP12 84-TSA 8.3 

84 CP12 84-TSB 8.3 

84 CP12 84-TSC 8.3 

84 CP12 84-TSD 8.3 

84 CP12 84-TSE 6.7 

84 CP12 84-TSF 6.7 

84 CP12 84-TSG 6.4 

84 CP12 84-TZN 1.7 

85 CP11 85-XGZ 20.1 

85 CP11 85-XHA 20.0 

85 CP11 85-XHB 15.8 

85 CP11 85-XHC 0.1 

85 CP11 85-XHD 0.1 

85 CP11 85-XHH 17.3 

85 CP11 5-XHJ 3.4 

85 CP11 85-ZGW 1.2 

85 CP11 85-ZHB 2.7 

87 CP11 87-BAS 13.0 

87 CP11 87-BAT 1.2 

87 CP11 87-BAW 10.2 

87 CP11 87-BAX 8.6 

87 CP11 87-BAY 6.7 

87 CP21 87-APM 1.4 

87 CP21 87-APN 0.9 

88 CP01 88-BKY 4.8 

88 CP01 88-BKZ 7.7 

88 CP01 88-BLA 5.4 

88 CP01 88-BLB 5.5 

88 CP01 88-BLE 7.8 

88 CP01 88-BLF 12.0 

88 CP01 88-BLG 2.3 

88 CP01 88-BLG 3.7 

88 CP01 88-BPT 3.7 

88 CP01 88-BST 0.2 

88 CP01 88-BTA 14.4 

88 CP01 88-BTB 4.1 

88 CP01 88-BTC 5.4 

88 CP01 88-BTD 5.5 

88 CP01 88-BTE 7.8 

88 CP01 88-BTF 7.0 

88 CP01 88-WRK 2.5 

88 CP01 88-WRK 2.5 

89 CP01 89-CALW 0.2 

89 CP01 89-CAM 3.5 

89 CP01 89-CAN 0.4 


91 CP11 91-CXL 0.2 

91 CP11 91-CXM 3.4 

92 CP01 92-CKS 28.2 

92 CP01 92-CKT 22.2 

92 CP01 92-CKW 18.6 

92 CP01 92-CKX 24.6 

92 CP01 92-CKY 24.5 

92 CP01 92-CKZ 6.5 

92 CP01 92-CKZ 8.1 

92 CP01 92-CLA 1.4 

92 CP01 92-CLA 2.0 

92 CP01 92-CLA 9.4 

92 CP01 92-CLB 20.1 

92 CP01 92-CLC 13.3 

92 CP01 92-CLD 8.1 

95 CP01 95-FRA 1.9 

95 CP01 95-FRB 2.3 

95 CP01 95-FRB 7.8 

95 CP01 95-FRC 10.4 

95 CP01 95-FRD 8.7 

95 CP01 95-FRE 10.2 

95 CP01 95-FRF 9.3 

95 CP01 95-FRG 7.8 

95 CP01 95-FRH 7.8 

95 CP01 95-FRJ 14.9 

95 CP01 95-FRK 7.6 

97 CP01 97-HPY 2.1 

37

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CO98-G 




Nearest producing field Sturt-Taloola-Tantanna oil fields 

(37 km), Jack Lake gas field (47 km) 



1 61 ER01 3 18.5 

2 63 CP01 1 32.0 

3 64 CP01 5 95.7 

4 65 CP01 3 38.6 

5 66 ER01 5 49.5 

6 67 CP01 2 56.8 

7 69 CP04 7 76.8 

8 69 ER01 1 7.5 

9 70 CP09 9 44.7 

10 76 CP01 2 10.9 

11 77 CP01 2 12.7 

12 82 CP02 4 64.1 

13 84 CP12 15 113.8 

14 84 CP32 4 33.6 

15 85 CP11 36 878.8 

16 85 CP21 2 4.2 

17 85 CP51 2 3.6 

18 86 CP11 2 2.9 

19 86 CP21 9 145.9 

20 87 CP11 6 43.6 

21 87 CP21 6 48.9 

22 88 CP01 22 258.4 

23 89 CP01 29 204.6 

24 90 CP08 7 36.7 

25 91 CP11 7 46.5 

26 95 CP01 6 36.0 



Previous drilling 



Lhotsky 1 1988 1,931.2 Eromanga - Abandoned 

Oil 

Lycium 1 1989 2,250.0 Poolowanna - Water well 

Oil 

Kuenpinnie 1 1991 2,607.3 Upper Abandoned 

Patchawarra - 

Gas 

CO98-G seismic lines 


61 ER01 61-MMK 10.7 

61 ER01 61-MMK12 1.7 

61 ER01 61-MMKS 6.0 

63 CP01 63-AL 32.0 

64 CP01 64-CE 4.7 

64 CP01 64-CU 48.7 

64 CP01 64-CV 8.5 

64 CP01 64-CW 19.4 

64 CP01 64-CX 14.5 

65 CP01 65-FV 9.4 


65 CP01 65-FW 27.1 

65 CP01 65-FX 2.1 

66 ER01 66-MB 29.9 

66 ER01 66-MC 1.4 

66 ER01 66-ME 8.1 

66 ER01 66-MF 5.7 

66 ER01 66-MI 4.5 

67 CP01 67-SR 21.9 

67 CP01 67-ST 34.8 

69 CP04 70-PWW 2.8 

69 CP04 70-PWW 14.4 

69 CP04 70-PWZ 4.6 

69 CP04 70-PXA 12.5 

69 CP04 70-PXB 1.6 

69 CP04 70-PXB 39.9 

69 CP04 70-PXK 0.9 

69 ER01 70-LAF3 7.5 

70 CP09 70-MAA 0.7 

70 CP09 70-MAB 3.2 

70 CP09 70-MAE 11.4 

70 CP09 70-MAF 1.3 

70 CP09 70-MAF 7.0 

70 CP09 70-MAG 3.3 

70 CP09 70-MAI 5.9 

70 CP09 70-MAJ 3.1 

70 CP09 70-MAK 8.7 

76 CP01 76-JDB 4.8 

76 CP01 76-JEL 6.0 

77 CP01 77-JLN 9.2 

77 CP01 77-JLP 3.5 

82 CP02 81-KRD 15.5 

82 CP02 81-KRE 16.8 

82 CP02 81-KRH 18.5 

82 CP02 81-KRK 13.4 

84 CP12 84-SFX 4.7 

84 CP12 84-SFY 6.9 

84 CP12 84-SFY 23.0 

84 CP12 84-SFZ 1.8 

84 CP12 84-SFZ 33.9 

84 CP12 84-SGB 0.6 

84 CP12 84-SGB 29.1 

84 CP12 84-SGC 1.7 

84 CP12 84-TRZ 1.8 

84 CP12 84-TSA 1.8 

84 CP12 84-TSB 2.6 

84 CP12 84-TSC 2.1 

84 CP12 84-TSD 2.1 

84 CP12 84-TZP 0.1 

84 CP12 84-TZQ 1.5 

84 CP32 84-TZZ 0.0 

84 CP32 84-XAB 0.9 

84 CP32 84-XAC 24.6 

84 CP32 84-XAE 8.1 

39


85 CP11 5-XHA 34.0 

85 CP11 85-XHB 49.9 

85 CP11 85-XHC 57.8 

85 CP11 85-XHD 57.5 

85 CP11 85-XHE 60.7 

85 CP11 85-XHF 52.2 

85 CP11 85-XHG 40.5 

85 CP11 85-XHH 30.8 

85 CP11 85-XHJ 27.7 

85 CP11 85-XQG 26.7 

85 CP11 85-XQH 9.6 

85 CP11 85-XQJ 12.1 

85 CP11 85-XRD 14.0 

85 CP11 85-XRE 21.4 

85 CP11 85-XRF 2.5 

85 CP11 85-XRG 21.6 

85 CP11 85-ZGL 24.9 

85 CP11 85-ZGM 49.5 

85 CP11 85-ZGN 26.2 

85 CP11 85-ZGP 20.2 

85 CP11 85-ZGQ 26.1 

85 CP11 85-ZGR 18.2 

85 CP11 85-ZGS 10.0 

85 CP11 85-ZGT 9.7 

85 CP11 85-ZGW 37.5 

85 CP11 85-ZHB 9.2 

85 CP11 85-ZHC 6.5 

85 CP11 85-ZHD 6.4 

85 CP11 85-ZHE 9.9 

85 CP11 85-ZHF 6.6 

85 CP11 85-ZHG 6.6 

85 CP11 85-ZHH 25.6 

85 CP11 85-ZHL 12.1 

85 CP11 85-ZHN 9.3 

85 CP11 85-ZLQ 11.2 

85 CP21 85-ZKM 2.1 

85 CP21 85-ZKM 2.1 

85 CP51 85-ZKN 1.8 

85 CP51 85-ZKN 1.8 

86 CP11 86-AEW 2.8 

86 CP11 86-AEX 0.2 

86 CP21 86-ZGX 7.5 

86 CP21 86-ZGY 7.4 

86 CP21 86-ZGZ 22.2 

86 CP21 86-ZHA 10.4 

86 CP21 86-ZHJ 25.1 

86 CP21 86-ZHK 12.8 

86 CP21 86-ZHM 17.7 

86 CP21 86-ZHP 18.0 

86 CP21 86-ZHQ 24.9 

87 CP11 87-BAT 13.9 

87 CP11 87-BAW 7.3 

87 CP11 87-BAX 8.3 

40 


87 CP11 87-BAY 9.7 

87 CP11 87-BCM 2.3 

87 CP11 87-BCS 2.1 

87 CP21 87-APJ 7.9 

87 CP21 87-APK 9.0 

87 CP21 87-APL 6.1 

87 CP21 87-APM 9.7 

87 CP21 87-APN 8.1 

87 CP21 87-APP 8.0 

88 CP01 88-BNW 3.7 

88 CP01 88-BPW 5.8 

88 CP01 88-BPX 0.6 

88 CP01 88-BRC 10.5 

88 CP01 88-BRD 3.4 

88 CP01 88-BRD 10.7 

88 CP01 88-BRE 9.7 

88 CP01 88-BRG 10.1 

88 CP01 88-BRH 20.1 

88 CP01 88-BSR 12.6 

88 CP01 88-BSS 25.6 

88 CP01 88-BST 24.4 

88 CP01 88-BSW 15.4 

88 CP01 88-BSX 26.5 

88 CP01 88-BSY 13.7 

88 CP01 88-BSZ 22.7 

88 CP01 88-BTB 7.9 

88 CP01 88-BTC 12.6 

88 CP01 88-BTD 1.5 

88 CP01 88-BTE 1.2 

88 CP01 88-BYM 12.6 

88 CP01 88-BYN 7.1 

89 CP01 89-BZK 0.0 

89 CP01 89-BZL 1.8 

89 CP01 89-BZM 7.5 

89 CP01 89-BZN 8.9 

89 CP01 89-BZP 4.3 

89 CP01 89-BZQ 6.3 

89 CP01 89-BZR 14.1 

89 CP01 89-BZS 7.8 

89 CP01 89-BZT 13.2 

89 CP01 89-BZW 12.1 

89 CP01 89-BZX 10.0 

89 CP01 89-BZY 9.4 

89 CP01 89-BZZ 7.9 

89 CP01 89-CAA 7.5 

89 CP01 89-CBG 9.7 

89 CP01 89-CBH 8.0 

89 CP01 89-CBJ 5.6 

89 CP01 89-CBK 13.8 

89 CP01 89-CBL 6.4 

89 CP01 89-CBM 3.7 

89 CP01 89-CBN 3.6 

89 CP01 89-CBP 7.2


89 CP01 89-CBQ 5.8 

89 CP01 89-CBQD 6.4 

89 CP01 89-CBR 3.9 

89 CP01 89-CBS 6.3 

89 CP01 89-CBT 8.4 

89 CP01 89-CEX 2.3 

89 CP01 89-CEY 2.3 

90 CP08 90-CJT 4.0 

90 CP08 90-CJTD 4.0 

90 CP08 90-CJW 4.0 

90 CP08 90-CJX 4.0 

90 CP08 90-CKM 8.5 

90 CP08 90-CKN 4.6 

90 CP08 90-CKP 7.5 

91 CP11 91-CXH 11.2 

91 CP11 91-CXJ 11.6 

91 CP11 91-CXK 6.1 

91 CP11 91-CXL 7.0 

91 CP11 91-CXL 7.2 

91 CP11 91-CXM 3.2 

91 CP11 91-DDE 0.1 

95 CP01 95-FQZ 10.5 

95 CP01 95-FRA 9.2 

95 CP01 95-FRB 0.4 

95 CP01 95-FRJ 8.8 

95 CP01 95-FYB 3.7 

95 CP01 95-FYC 3.5 

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CO98-H 




Nearest producing field Daralingie gas field (28 km), 

Sturt-Taloola-Tantanna oil 

fields (35 km) 



1 63 CP01 1 11.3 

2 64 CP01 11 204.1 

3 65 CP01 3 31.4 

4 67 CP01 5 45.9 

5 68 CP01 7 43.2 

6 69 CP02 1 9.1 

7 70 CP09 4 30.1 

8 76 CP01 3 38.3 

9 77 CP01 1 4.3 

10 78 CP01 1 9.5 

11 79 CP01 1 2.1 

12 82 CP02 23 249.4 

13 82 CP42 2 7.4 

14 84 CP32 14 133.0 

15 85 CP11 15 75.2 

16 85 CP21 14 399.4 

17 86 CP31 22 139.2 

18 87 CP11 14 123.6 

19 88 CP01 23 246.7 

20 89 CP01 3 10.2 

21 90 CP08 5 27.0 

22 91 CP03 4 11.6 

23 91 CP11 11 65.8 

24 92 CP01 2 18.3 

25 94 CP21 4 38.8 

26 95 CP01 7 39.8 






Pando 1 1966 1,933.3 Cooper - Gas Abandoned 

Pando 2 1969 1,895.5 Cooper - Abandoned 

Oil & Gas 

Pando North 1 1970 1,969.0 Cooper - Abandoned 

Oil/Gas 

Pintari 1 1987 1,792.8 Eromanga - Abandoned 

Oil 

Pando South 1 1992 1,848.6 Birkhead/ Abandoned 

Hutton - Oil 

Jaspa 1 1996 1,772.4 Namur - Oil Abandoned 

Barra 1 1996 2,106.7 Patchawarra - Abandoned 

Gas 

CO98-H seismic lines 


63 CP01 63-AP 11.3 

64 CP01 64-BD 8.6 

64 CP01 64-BK 20.9 

64 CP01 64-CC 13.6 

64 CP01 64-CC 28.2 

64 CP01 64-CD 36.2 


64 CP01 64-CE 8.5 

64 CP01 64-CJ 16.5 

64 CP01 64-CL 32.2 

64 CP01 64-CM 17.5 

64 CP01 64-CN 7.6 

64 CP01 64-CP 14.2 

65 CP01 65-FK 20.2 

65 CP01 65-FQ 9.1 

65 CP01 65-FV 2.1 

67 CP01 67-QA 4.9 

67 CP01 67-QG 5.7 

67 CP01 67-QH 11.7 

67 CP01 67-QX 2.6 

67 CP01 67-RI 20.9 

68 CP01 68-TB 8.1 

68 CP01 68-TH 6.2 

68 CP01 68-TI 17.2 

68 CP01 68-TJ 3.1 

68 CP01 68-TK 5.0 

68 CP01 68-TN 3.3 

68 CP01 68-TQ 0.3 

69 CP02 69-PWK 9.1 

70 CP09 70-MAB 5.0 

70 CP09 70-MAC 6.6 

70 CP09 70-MAD 7.9 

70 CP09 70-MAH 10.6 

76 CP01 76-JDA 9.8 

76 CP01 76-JDF 24.1 

76 CP01 76-JDG 4.4 

77 CP01 77-JLG 4.3 

78 CP01 78-JNA 9.5 

79 CP01 79-JSS 2.1 

82 CP02 82-MCN 0.8 

82 CP02 82-MCP 3.2 

82 CP02 82-MCR 4.3 

82 CP02 82-MCT 6.0 

82 CP02 82-MCW 7.9 

82 CP02 82-MCX 10.6 

82 CP02 82-MCY 36.0 

82 CP02 82-MCZ 5.3 

82 CP02 82-MDA 7.5 

82 CP02 82-MDB 14.1 

82 CP02 82-MDC 9.3 

82 CP02 82-MDD 9.6 

82 CP02 82-MDE 16.2 

82 CP02 82-MDF 3.2 

82 CP02 82-MDH 3.9 

82 CP02 82-MDK 6.0 

82 CP02 82-MDL 4.7 

82 CP02 82-MDN 11.5 

82 CP02 82-MDP 3.0 

82 CP02 82-MDQ 14.9 

43


82 CP02 82-MDR 23.8 

82 CP02 82-MDS 17.4 

82 CP02 82-MDT 30.1 

82 CP42 82-LQG 2.9 

82 CP42 82-LQJ 4.5 

84 CP32 84-SHX 37.1 

84 CP32 84-SHY 5.4 

84 CP32 84-SHZ 14.7 

84 CP32 84-SJA 6.6 

84 CP32 84-SJB 4.9 

84 CP32 84-SJC 2.1 

84 CP32 84-SJD 1.8 

84 CP32 84-SJE 1.2 

84 CP32 84-SJF 0.0 

84 CP32 84-SJG 2.6 

84 CP32 84-SJH 16.0 

84 CP32 84-XAA 12.0 

84 CP32 84-XAD 20.4 

84 CP32 84-XAE 8.2 

85 CP11 85-XGA 3.7 

85 CP11 85-XGB 2.7 

85 CP11 85-XGD 2.8 

85 CP11 85-XQM 9.7 

85 CP11 85-XQZ 1.2 

85 CP11 85-XRA 3.6 

85 CP11 85-XRC 5.9 

85 CP11 85-XRD 9.1 

85 CP11 85-XRE 6.6 

85 CP11 85-XRG 11.9 

85 CP11 86-ZMD 1.8 

85 CP11 86-ZME 4.5 

85 CP11 86-ZMF 7.2 

85 CP11 86-ZMG 2.3 

85 CP11 86-ZMH 2.5 

85 CP21 85-XKJ 7.2 

85 CP21 85-XKK 10.0 

85 CP21 85-XKL 17.0 

85 CP21 85-XKM 50.1 

85 CP21 85-XKN 46.9 

85 CP21 85-XKP 34.4 

85 CP21 85-XKQ 17.8 

85 CP21 85-XKR 27.5 

85 CP21 85-XKS 34.5 

85 CP21 85-XKT 30.5 

85 CP21 85-XKW 37.9 

85 CP21 85-XKX 35.5 

85 CP21 85-XKY 28.0 

85 CP21 85-XKZ 22.0 

86 CP31 86-ZPM 3.7 

86 CP31 86-ZPN 5.3 

86 CP31 86-ZPP 12.0 

86 CP31 86-ZPQ 17.0 

86 CP31 86-ZPR 7.9 

44 


86 CP31 86-ZPS 6.0 

86 CP31 86-ZPT 3.6 

86 CP31 86-ZPW 10.4 

86 CP31 86-ZPX 5.7 

86 CP31 86-ZPY 6.3 

86 CP31 86-ZPZ 6.5 

86 CP31 86-ZQA 7.0 

86 CP31 86-ZQB 7.0 

86 CP31 86-ZQC 7.0 

86 CP31 86-ZQD 7.0 

86 CP31 86-ZQX 0.6 

86 CP31 86-ZQY 2.9 

86 CP31 86-ZSP 6.0 

86 CP31 86-ZSQ 4.4 

86 CP31 86-ZSR 3.5 

86 CP31 86-ZST 4.6 

86 CP31 86-ZSW 5.0 

87 CP11 87-ATD 12.0 

87 CP11 87-ATE 12.0 

87 CP11 87-ATF 12.0 

87 CP11 87-ATG 12.0 

87 CP11 87-ATH 21.5 

87 CP11 87-BDC 1.7 

87 CP11 87-BDD 7.8 

87 CP11 87-BDE 7.9 

87 CP11 87-BDF 4.4 

87 CP11 87-BDG 3.0 

87 CP11 87-BDH 1.0 

87 CP11 87-BDJ 1.9 

87 CP11 87-BDK 10.0 

87 CP11 87-BDL 16.4 

88 CP01 88-BNZ 0.6 

88 CP01 88-BPA 9.4 

88 CP01 88-BPB 1.0 

88 CP01 88-BPC 4.7 

88 CP01 88-BPD 7.0 

88 CP01 88-BPE 10.1 

88 CP01 88-BRK 0.8 

88 CP01 88-BRL 12.5 

88 CP01 88-BRN 1.4 

88 CP01 88-BSB 19.9 

88 CP01 88-BSC 12.1 

88 CP01 88-BSD 21.4 

88 CP01 88-BSE 21.6 

88 CP01 88-BSH 10.1 

88 CP01 88-BSJ 10.1 

88 CP01 88-BSK 15.0 

88 CP01 88-BSL 9.9 

88 CP01 88-BSM 14.8 

88 CP01 88-BSN 11.0 

88 CP01 88-BSP 26.7 

88 CP01 88-BSQ 18.0 

88 CP01 88-BXC 4.5


88 CP01 88-BXD 4.0 

89 CP01 89-BZB 0.0 

89 CP01 89-CHF 5.1 

89 CP01 89-CHG 5.1 

90 CP08 90-CMC 6.0 

90 CP08 90-CMD 6.0 

90 CP08 90-CME 5.0 

90 CP08 90-CMF 5.0 

90 CP08 90-CMG 5.0 

91 CP03 91-CYW 2.2 

91 CP03 91-CYX 3.3 

91 CP03 91-CYY 4.9 

91 CP03 91-CZA 1.1 

91 CP11 91-CYK 8.5 

91 CP11 91-CYL 9.4 

91 CP11 91-CYM 6.6 

91 CP11 91-CYN 8.5 

91 CP11 91-CYP 5.3 

91 CP11 91-CYQ 4.7 

91 CP11 91-CYR 4.2 

91 CP11 91-CYS 3.1 

91 CP11 91-CYT 0.9 

91 CP11 91-CZB 7.3 

91 CP11 91-DAN 7.3 

92 CP01 92-DHT 11.1 

92 CP01 92-DHW 7.2 

94 CP21 94-FGH 12.7 

94 CP21 94-FGJ 8.7 

94 CP21 94-FGK 0.1 

94 CP21 94-FGP 17.3 

95 CP01 95-FMX 10.5 

95 CP01 95-FMY 6.0 

95 CP01 95-FMZ 6.0 

95 CP01 95-FNA 3.1 

95 CP01 95-FNB 1.0 

95 CP01 95-FQM 10.0 

95 CP01 95-FXC 3.2 

45

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CO98-I 




Nearest producing field Wancoocha oil and gas field (38 km) 

Seismic surveys 


1 62 ER01 8 34.3 

2 63 ER01 2 8.1 

3 64 CP01 3 47.1 

4 65 CP01 9 163.7 

5 65 CP02 1 27.2 

6 66 ER01 1 18.5 

7 67 CP01 7 45.8 

8 69 CP01 2 1.1 

9 69 CP02 15 190.0 

10 70 CP05 8 74.5 

11 79 CP01 4 47.5 

12 82 CP02 8 90.2 

13 82 CP42 6 66.3 

14 83 CP21 13 66.7 

15 84 CP32 8 160.4 

16 85 CP11 2 4.7 

17 85 CP21 25 161.3 

18 87 CP11 4 3.4 

19 89 CP01 6 17.9 

20 93 CP01 6 28.4 

21 94 CP21 9 49.5 

22 95 CP01 6 131.7 

23 96 CP01 13 250.4 






Pampari 1 1996 1,531.6 Namur - Oil Abandoned 

CO98-I seismic lines 


62 ER01 62-MI 1.7 

62 ER01 62-MI 19.9 

62 ER01 62-MI102 2.2 

62 ER01 62-MI105E 1.1 

62 ER01 62-MI105N 1.5 

62 ER01 62-MI96 0.8 

62 ER01 62-MIW102A 5.5 

62 ER01 62-MIW102B 1.7 

63 ER01 63-BL 4.0 

63 ER01 63-MIW102A 4.2 

64 CP01 64-BC 7.4 

64 CP01 64-CC 1.8 

64 CP01 64-CN 37.9 

65 CP01 65-ET 20.6 

65 CP01 65-EU 29.7 

65 CP01 65-EV 21.8 


65 CP01 65-FC 22.0 

65 CP01 65-FD 11.9 

65 CP01 65-FH 21.6 

65 CP01 65-FI 21.3 

65 CP01 65-FJ 7.6 

65 CP01 65-FZ 7.3 

65 CP02 65-PB 27.2 

66 ER01 66-MJ 18.5 

67 CP01 67-QI 6.8 

67 CP01 67-QR 10.4 

67 CP01 67-QY 8.8 

67 CP01 67-QZ 7.1 

67 CP01 67-RB 4.2 

67 CP01 67-RF 0.4 

67 CP01 67-RH 8.1 

69 CP01 69-VC 0.1 

69 CP01 69-VK 1.0 

69 CP02 69-PVU 0.7 

69 CP02 69-PVV 20.8 

69 CP02 69-PVZ 6.8 

69 CP02 69-PWA 6.5 

69 CP02 69-PWB 13.7 

69 CP02 69-PWC 3.4 

69 CP02 69-PWD 26.5 

69 CP02 69-PWE 5.6 

69 CP02 69-PWG 2.9 

69 CP02 69-PWH 9.0 

69 CP02 69-PWI 15.9 

69 CP02 69-PWJ 25.4 

69 CP02 69-PWL 27.9 

69 CP02 69-PWM 5.6 

69 CP02 69-PWN 19.1 

70 CP05 70-PXO 8.8 

70 CP05 70-PXQ 12.2 

70 CP05 70-PXS 13.6 

70 CP05 70-PXT 1.2 

70 CP05 70-PXV 15.3 

70 CP05 70-PXW 11.3 

70 CP05 70-PXX 9.8 

70 CP05 70-PXY 2.3 

79 CP01 79-JSN 32.7 

79 CP01 79-JSU 9.2 

79 CP01 79-JSV 1.9 

79 CP01 79-JSW 3.7 

82 CP02 82-MBY 16.3 

82 CP02 82-MBZ 5.7 

82 CP02 82-MCA 14.2 

82 CP02 82-MCB 10.1 

82 CP02 82-MCE 8.7 

82 CP02 82-MCF 12.6 

82 CP02 82-MCG 14.3 

47


82 CP02 82-MCH 8.2 

82 CP42 82-LQN 7.6 

82 CP42 82-LQP 15.3 

82 CP42 82-LQQ 7.6 

82 CP42 82-LQR 7.4 

82 CP42 82-LQS 21.6 

82 CP42 82-LQW 6.7 

83 CP21 83-SBQ 15.4 

83 CP21 83-SBR 2.6 

83 CP21 83-SBS 2.7 

83 CP21 83-SBT 4.1 

83 CP21 83-SCP 5.6 

83 CP21 83-SCQ 5.3 

83 CP21 83-SCR 5.0 

83 CP21 83-SCS 4.5 

83 CP21 83-SDS 4.3 

83 CP21 83-SDT 0.1 

83 CP21 83-SDW 1.6 

83 CP21 83-SDX 1.5 

83 CP21 84-SDZ 14.0 

84 CP32 84-SJH 20.2 

84 CP32 84-SJJ 33.6 

84 CP32 84-SJK 37.2 

84 CP32 84-SJL 11.2 

84 CP32 84-SJM 24.6 

84 CP32 84-SJN 11.4 

84 CP32 84-SJP 10.9 

84 CP32 84-TZY 11.2 

85 CP11 85-XGA 0.3 

85 CP11 85-XGC 4.5 

85 CP21 85-XKN 2.7 

85 CP21 85-XKP 13.6 

85 CP21 85-XKY 8.4 

85 CP21 85-XLA 14.5 

85 CP21 85-XLB 13.6 

85 CP21 85-XLC 3.9 

85 CP21 85-XLD 3.5 

85 CP21 85-XLE 8.0 

85 CP21 85-XLF 16.0 

85 CP21 85-XLG 16.0 

85 CP21 85-XLH 10.0 

85 CP21 85-XLJ 10.0 

85 CP21 85-XLK 10.0 

85 CP21 85-XLL 10.0 

85 CP21 85-XLM 3.1 

85 CP21 85-XLN 3.0 

85 CP21 85-XLP 2.8 

85 CP21 85-XLQ 2.5 

85 CP21 85-XLR 0.9 

85 CP21 85-XLT 0.9 

85 CP21 85-XLW 0.8 

85 CP21 85-XLX 1.0 

48 


85 CP21 85-YNS 1.6 

85 CP21 85-YNW 2.0 

85 CP21 85-YNX 2.6 

87 CP11 87-BDS 0.0 

87 CP11 87-BDT 1.4 

87 CP11 87-BDW 1.5 

87 CP11 87-BDY 0.4 

89 CP01 89-CFM 3.2 

89 CP01 89-CFN 3.3 

89 CP01 89-CFQ 8.7 

89 CP01 89-CFX 2.1 

89 CP01 89-CFY 0.3 

89 CP01 89-CFZ 0.4 

93 CP01 93-EKL 4.2 

93 CP01 93-EKM 2.8 

93 CP01 93-EKN 3.4 

93 CP01 93-EKP 2.1 

93 CP01 93-EKQ 1.9 

93 CP01 93-EKT 14.1 

94 CP21 94-FFD 6.6 

94 CP21 94-FFE 3.7 

94 CP21 94-FFF 2.0 

94 CP21 94-FFH 5.1 

94 CP21 94-FFJ 5.0 

94 CP21 94-FFK 4.9 

94 CP21 94-FFL 4.8 

94 CP21 94-FFM 11.0 

94 CP21 94-FFN 6.2 

95 CP01 95-FNG 0.2 

95 CP01 95-FNJ 0.3 

95 CP01 95-FXB 41.2 

95 CP01 95-FXC 34.9 

95 CP01 95-FXD 29.9 

95 CP01 95-FXE 25.2 

96 CP01 96-GKG 21.3 

96 CP01 96-GKH 20.6 

96 CP01 96-GKJ 33.0 

96 CP01 96-GKK 20.3 

96 CP01 96-GKL 15.5 

96 CP01 96-GKM 6.9 

96 CP01 96-GKN 18.8 

96 CP01 96-GKP 21.4 

96 CP01 96-GKQ 20.7 

96 CP01 96-GKR 8.7 

96 CP01 96-GKS 20.6 

96 CP01 96-GKT 26.9 

96 CP01 96-GKW 15.7

CO98-J 




Nearest producing field Limestone Creek-Biala oil 

fields (34 km) 



1 62 ER01 7 39.2 

2 63 ER01 5 148.8 

3 64 CP01 1 13.0 

4 65 CP01 10 127.2 

5 67 CP01 8 93.2 

6 68 CP01 10 78.1 

7 69 CP01 28 356.8 

8 69 CP02 12 116.0 

9 70 CP05 3 11.0 

10 75 CP01 4 12.1 

11 76 CP01 9 119.4 

12 79 CP01 4 14.8 

13 81 CP06 8 43.3 

14 82 CP02 18 205.3 

15 82 CP05 5 12.7 

16 82 CP42 3 16.6 

17 83 CP21 30 158.2 

18 83 CP22 12 63.2 

19 83 CPXX1 1 2.1 

20 84 CP32 11 217.3 

21 85 CP21 38 470.7 

22 85 CP41 14 115.5 

23 86 CP21 6 48.4 

24 87 CP21 4 31.2 

25 88 CP01 5 21.7 

26 89 CP01 7 5.5 

27 91 CP11 1 0.5 

28 92 CP01 9 62.9 

29 93 CP01 13 52.8 

30 94 CP01 10 19.9 

31 94 CP21 12 74.4 

32 95 CP01 10 128.9 

33 96 CP01 17 138.4 



Previous drilling 



Kobarie 1 1970 1,686.7 Cooper - gas Abandoned 

Tilparee 1A 1971 2,148.5 Cooper - gas Abandoned 

Kumbarie 1 1984 1,773.9 Eromanga - Abandoned 

oil & gas 

Mulga 2 1985 1,905.0 Eromanga - Abandoned 

oil 

Wuroopie 1 1987 2,045.2 Cooper - gas Abandoned 

CO98-J seismic lines 


62 ER01 62-MI 4.3 

62 ER01 62-MI 13.4 

62 ER01 62-MI109E 0.4 

62 ER01 62-MI109N 1.8 

62 ER01 62-MI121E 1.0 


62 ER01 62-MI121N 0.9 

62 ER01 62-MI122 17.4 

63 ER01 63-BL 30.8 

63 ER01 63-BL 39.3 

63 ER01 63-BLR 5.8 

63 ER01 63-DT 13.3 

63 ER01 63-DT 59.7 

64 CP01 64-BA 13.0 

65 CP01 65-EQ 16.6 

65 CP01 65-ES 7.8 

65 CP01 65-ES 27.0 

65 CP01 65-ET 30.2 

65 CP01 65-EY 9.6 

65 CP01 65-EZ 9.7 

65 CP01 65-FA 6.9 

65 CP01 65-FI 9.3 

65 CP01 65-FJ 2.1 

65 CP01 65-FO 8.1 

67 CP01 67-QJ 23.1 

67 CP01 67-QK 16.1 

67 CP01 67-QL 24.1 

67 CP01 67-QM 14.5 

67 CP01 67-QN 4.4 

67 CP01 67-QZ 2.5 

67 CP01 67-RA 4.8 

67 CP01 67-RH 3.6 

68 CP01 68-UE 6.4 

68 CP01 68-UF 16.2 

68 CP01 68-UG 10.2 

68 CP01 68-UH 12.9 

68 CP01 68-UI 0.9 

68 CP01 69-UR 9.2 

68 CP01 69-US 8.7 

68 CP01 69-UY 5.1 

68 CP01 69-UZ 1.5 

68 CP01 69-VA 7.0 

69 CP01 69-VB 24.1 

69 CP01 69-VD 15.9 

69 CP01 69-VE 25.8 

69 CP01 69-VJ 18.5 

69 CP01 69-VK 22.2 

69 CP01 69-VN 10.5 

69 CP01 69-VO 4.4 

69 CP01 69-VT 4.1 

69 CP01 69-VU 16.9 

69 CP01 69-VV 15.3 

69 CP01 69-VW 13.2 

69 CP01 69-WD 8.0 

69 CP01 69-WF 5.2 

69 CP01 69-WG 6.1 

69 CP01 69-WH 7.2 

69 CP01 69-WI 8.8 

69 CP01 69-WJ 10.4 

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69 CP01 69-WK 4.6 

69 CP01 69-WM 32.9 

69 CP01 69-WN 3.2 

69 CP01 69-XD 11.6 

69 CP01 69-XE 15.3 

69 CP01 69-XF 3.2 

69 CP01 69-XG 11.2 

69 CP01 69-XH 12.2 

69 CP01 69-XI 28.1 

69 CP01 69-XL 8.0 

69 CP01 69-XM 9.7 

69 CP02 69-PVT 30.9 

69 CP02 69-PVU 7.3 

69 CP02 69-PVW 5.6 

69 CP02 69-PVX 4.7 

69 CP02 69-PVY 11.3 

69 CP02 69-PVZ 9.2 

69 CP02 69-PWA 7.9 

69 CP02 69-PWC 8.5 

69 CP02 69-PWD 7.1 

69 CP02 69-PWE 8.0 

69 CP02 69-PWG 7.5 

69 CP02 69-PWH 7.8 

70 CP05 70-PXT 3.0 

70 CP05 70-PXU 5.6 

70 CP05 70-PZE 2.4 

75 CP01 75-JCF 2.7 

75 CP01 75-JCG 4.7 

75 CP01 75-JCH 4.4 

75 CP01 75-JCN 0.3 

76 CP01 76-JFY 4.4 

76 CP01 76-JFZ 1.9 

76 CP01 76-JGC 15.6 

76 CP01 76-JGD 40.5 

76 CP01 76-JGE 16.3 

76 CP01 76-JGF 7.9 

76 CP01 76-JGG 19.9 

76 CP01 76-JGH 1.7 

76 CP01 76-JGJ 11.2 

79 CP01 79-JSM 1.3 

79 CP01 79-JSP 0.8 

79 CP01 79-JST 5.4 

79 CP01 79-JTD 7.3 

81 CP06 81-KWA 7.1 

81 CP06 81-KWB 5.8 

81 CP06 81-KWC 5.9 

81 CP06 81-KWD 6.2 

81 CP06 81-KWE 3.4 

81 CP06 81-KWF 2.4 

81 CP06 81-KWH 6.2 

81 CP06 81-KWJ 6.1 

82 CP02 82-MBM 0.0 


82 CP02 82-MBN 7.5 

82 CP02 82-MBP 9.3 

82 CP02 82-MBQ 0.6 

82 CP02 82-MBQ 14.9 

82 CP02 82-MBR 14.7 

82 CP02 82-MBS 13.9 

82 CP02 82-MBT 10.8 

82 CP02 82-MBW 21.4 

82 CP02 82-MBX 12.7 

82 CP02 82-MBZ 21.1 

82 CP02 82-MCB 7.6 

82 CP02 82-MCC 0.8 

82 CP02 82-MCD 0.7 

82 CP02 82-MCE 13.5 

82 CP02 82-MCF 4.8 

82 CP02 82-MCL 18.4 

82 CP02 82-MCM 32.7 

82 CP05 82-LSN 0.2 

82 CP05 82-LSP 2.9 

82 CP05 82-LSQ 4.4 

82 CP05 82-LST 2.3 

82 CP05 82-LSW 2.9 

82 CP42 82-LQP 2.3 

82 CP42 82-LQT 10.2 

82 CP42 82-LQW 4.2 

83 CP21 83-LZB 5.1 

83 CP21 83-NBA 0.9 

83 CP21 83-NBC 2.9 

83 CP21 83-NBD 2.9 

83 CP21 83-NBE 4.3 

83 CP21 83-SCP 3.2 

83 CP21 83-SCQ 2.4 

83 CP21 83-SCR 2.5 

83 CP21 83-SCS 3.4 

83 CP21 83-SCT 12.5 

83 CP21 83-SCW 11.2 

83 CP21 83-SCX 4.3 

83 CP21 83-SCY 4.3 

83 CP21 83-SCZ 3.8 

83 CP21 83-SDE 3.6 

83 CP21 83-SDF 6.4 

83 CP21 83-SDG 3.1 

83 CP21 83-SDH 4.0 

83 CP21 83-SDJ 4.3 

83 CP21 83-SDK 0.9 

83 CP21 83-SDK 5.3 

83 CP21 83-SDL 2.2 

83 CP21 83-SDM 2.2 

83 CP21 83-SDS 6.9 

83 CP21 83-SDT 4.0 

83 CP21 83-SDW 3.9 

83 CP21 83-SDX 3.0 

51


83 CP21 83-SEA 4.1 

83 CP21 84-SDY 17.6 

83 CP21 84-SDZ 22.9 

83 CP22 83-LYZ 4.2 

83 CP22 83-NBF 6.8 

83 CP22 83-NBH 2.8 

83 CP22 83-NBJ 2.5 

83 CP22 83-NBK 6.1 

83 CP22 83-NBL 3.0 

83 CP22 83-NBM 3.3 

83 CP22 83-NBN 5.2 

83 CP22 83-NBP 3.8 

83 CP22 83-NBQ 2.0 

83 CP22 83-NBQ 10.0 

83 CP22 83-NBT 13.5 

83 CPXX1 83-NHC 2.1 

84 CP32 84-STN 8.2 

84 CP32 84-STP 6.7 

84 CP32 84-STQ 5.5 

84 CP32 84-STR 6.0 

84 CP32 84-STS 6.1 

84 CP32 84-STT 3.9 

84 CP32 84-SWX 58.4 

84 CP32 84-SWY 47.8 

84 CP32 84-SWZ 38.5 

84 CP32 84-SXA 35.0 

84 CP32 84-TJP 1.3 

85 CP21 85-XLM 4.9 

85 CP21 85-XLN 5.1 

85 CP21 85-XLP 5.2 

85 CP21 85-XLQ 4.9 

85 CP21 85-XLR 5.1 

85 CP21 85-XLS 7.0 

85 CP21 85-XLT 5.1 

85 CP21 85-XLW 5.2 

85 CP21 85-XLX 5.0 

85 CP21 85-XWJ 12.0 

85 CP21 85-XWN 7.5 

85 CP21 85-XZY 4.5 

85 CP21 85-XZZ 68.0 

85 CP21 85-YAA 12.5 

85 CP21 85-YAB 22.7 

85 CP21 85-YAC 8.5 

85 CP21 85-YAD 8.5 

85 CP21 85-YAE 5.6 

85 CP21 85-YAF 8.6 

85 CP21 85-YAJ 1.9 

85 CP21 85-YAK 7.8 

85 CP21 85-YAL 8.5 

85 CP21 85-YAM 5.5 

85 CP21 85-YAN 35.8 

85 CP21 85-YAP 9.3 

85 CP21 85-YAQ 9.3 

52 


85 CP21 85-YAR 36.2 

85 CP21 85-YAS 8.5 

85 CP21 85-YAT 13.9 

85 CP21 85-YAZ 10.0 

85 CP21 85-YBA 11.8 

85 CP21 85-YBB 13.5 

85 CP21 85-YBC 14.8 

85 CP21 85-YBD 38.8 

85 CP21 85-YBE 36.3 

85 CP21 85-YET 1.5 

85 CP21 85-YEW 0.9 

85 CP21 85-YEX 0.5 

85 CP41 85-XTS 12.0 

85 CP41 85-XTT 1.5 

85 CP41 85-XTW 16.8 

85 CP41 85-XTX 9.9 

85 CP41 85-XTY 7.0 

85 CP41 85-XTZ 7.4 

85 CP41 85-XWA 12.5 

85 CP41 85-XWB 6.0 

85 CP41 85-XWC 6.0 

85 CP41 85-XWD 7.9 

85 CP41 85-XWE 7.9 

85 CP41 85-XWF 6.9 

85 CP41 85-XWG 6.9 

85 CP41 85-XWH 6.9 

86 CP21 86-ADF 10.8 

86 CP21 86-ADG 7.9 

86 CP21 86-ZSL 6.7 

86 CP21 86-ZSM 7.3 

86 CP21 86-ZSN 7.9 

86 CP21 86-ZSS 7.8 

87 CP21 87-ARK 6.0 

87 CP21 87-ARL 7.1 

87 CP21 87-ARM 6.0 

87 CP21 87-ARP 12.1 

88 CP01 88-BJP 2.9 

88 CP01 88-BJR 1.5 

88 CP01 88-BJS 0.6 

88 CP01 88-BJZ 4.8 

88 CP01 88-BKA 11.8 

89 CP01 89-CCM 0.1 

89 CP01 89-CCN 1.7 

89 CP01 89-CCP 0.3 

89 CP01 89-CCQ 0.0 

89 CP01 89-CCQD 0.1 

89 CP01 89-CCR 1.5 

89 CP01 89-CCS 1.7 

91 CP11 91-CYA 0.5 

92 CP01 92-DJR 3.9 

92 CP01 92-DJS 9.8 

92 CP01 92-DJT 6.2 

92 CP01 92-DJW 8.4


92 CP01 92-DJX 4.7 

92 CP01 92-DKC 6.3 

92 CP01 92-DKD 7.1 

92 CP01 92-DKE 6.4 

92 CP01 92-DKF 10.0 

93 CP01 93-EJY 2.6 

93 CP01 93-EKB 0.4 

93 CP01 93-EKC 1.0 

93 CP01 93-EKD 4.7 

93 CP01 93-EKE 6.4 

93 CP01 93-EKF 5.7 

93 CP01 93-EKG 6.1 

93 CP01 93-EKH 4.0 

93 CP01 93-EKJ 2.0 

93 CP01 93-EKJ 4.0 

93 CP01 93-EKK 4.6 

93 CP01 93-ELT 6.2 

93 CP01 93-ELW 5.1 

94 CP01 94-EYR 3.5 

94 CP01 94-EYS 1.6 

94 CP01 94-EYT 2.6 

94 CP01 94-EYW 1.6 

94 CP01 94-EYW 3.7 

94 CP01 94-EYX 4.5 

94 CP01 94-EYY 0.1 

94 CP01 94-EYZ 0.3 

94 CP01 94-EZA 1.0 

94 CP01 94-EZB 1.1 

94 CP21 94-FFD 7.9 

94 CP21 94-FFF 9.9 

94 CP21 94-FFG 6.5 

94 CP21 94-FFH 6.8 

94 CP21 94-FFJ 5.0 

94 CP21 94-FFK 3.6 

94 CP21 94-FFL 3.7 

94 CP21 94-FFN 4.1 

94 CP21 94-FFP 6.4 

94 CP21 94-FFQ 6.1 

94 CP21 94-FFR 7.5 

94 CP21 94-FFS 6.9 

95 CP01 95-FLY 3.2 

95 CP01 95-FLZ 4.9 

95 CP01 95-GEZ 9.1 

95 CP01 95-GFA 21.3 

95 CP01 95-GFB 17.1 

95 CP01 95-GFC 30.1 

95 CP01 95-GFD 8.2 

95 CP01 95-GFE 13.4 

95 CP01 95-GFF 5.8 

95 CP01 95-GFG 15.9 

96 CP01 96-GHE 1.4 

96 CP01 96-GHF 5.2 

96 CP01 96-GHG 9.1 


96 CP01 96-GHH 3.8 

96 CP01 96-GHJ 3.1 

96 CP01 96-GHK 3.0 

96 CP01 96-GNF 17.7 

96 CP01 96-GNG 8.4 

96 CP01 96-GNH 8.3 

96 CP01 96-GNJ 9.3 

96 CP01 96-GNK 9.2 

96 CP01 96-GNL 9.0 

96 CP01 96-GNM 8.1 

96 CP01 96-GNN 8.1 

96 CP01 96-GNP 9.3 

96 CP01 96-GNQ 16.1 

96 CP01 96-GNR 9.0 

53

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CO98-K 




Nearest producing field Wancoocha oil and gas field (79 km) 



1 62 ER01 9 90.8 

2 63 ER01 4 16.2 

3 64 CP01 2 10.0 

4 65 CP01 5 92.6 

5 65 CP02 6 120.9 

6 66 ER01 3 35.8 

7 67 CP01 6 65.8 

8 69 CP01 9 123.5 

9 69 CP02 21 309.7 

10 70 CP05 9 99.3 

11 82 CP02 13 190.4 

12 83 CP21 1 0.9 

13 84 CP32 10 192.8 

14 84 CP42 1 28.8 

15 85 CP21 25 241.5 






Tinga 1968 2,301.8 Cooper - gas Abandoned 

Tingana 1 

Weena 1 1970 1,644.0 Cooper - gas Abandoned 

Gurra 1 1970 1,428.2 Cooper - gas Abandoned 

Cherri 1 1970 1,400.8 Cooper oil/ Abandoned 

gas 

CO98-K seismic lines 


62 ER01 62-MI 60.9 

62 ER01 62-MI51N 0.7 

62 ER01 62-MI70E 1.4 

62 ER01 62-MI70N 1.5 

62 ER01 62-MI87 9.0 

62 ER01 62-MI90E 1.1 

62 ER01 62-MI90N 1.1 

62 ER01 62-MI95 1.8 

62 ER01 62-MIW102B 13.4 

63 ER01 63-BL 0.0 

63 ER01 63-MIW102B 7.7 

63 ER01 63-MIW5S 2.5 

63 ER01 63-MIW9S 6.0 

64 CP01 64-CN 8.4 

64 CP01 64-CS 1.6 

65 CP01 65-EW 27.0 

65 CP01 65-FC 28.0 

65 CP01 65-FE 10.6 

65 CP01 65-FF 15.1 


65 CP01 65-FG 11.8 

65 CP02 65-PA 8.9 

65 CP02 65-PB 27.3 

65 CP02 65-PD 27.3 

65 CP02 65-PE 20.4 

65 CP02 65-PF 22.0 

65 CP02 65-PG 15.0 

66 ER01 66-MJ 3.9 

66 ER01 66-MK 14.1 

66 ER01 66-MM 17.8 

67 CP01 67-QI 4.7 

67 CP01 67-QJ 25.9 

67 CP01 67-QR 14.7 

67 CP01 67-RB 6.2 

67 CP01 67-RF 4.6 

67 CP01 67-RG 9.7 

69 CP01 69-VC 15.2 

69 CP01 69-VD 10.6 

69 CP01 69-VF 13.5 

69 CP01 69-VG 22.5 

69 CP01 69-VH 27.5 

69 CP01 69-VI 11.3 

69 CP01 69-VL 16.7 

69 CP01 69-VM 5.6 

69 CP01 69-XH 0.6 

69 CP02 69-PVA 12.0 

69 CP02 69-PVB 48.1 

69 CP02 69-PVC 10.5 

69 CP02 69-PVD 10.3 

69 CP02 69-PVE 10.5 

69 CP02 69-PVF 30.3 

69 CP02 69-PVG 5.6 

69 CP02 69-PVH 6.4 

69 CP02 69-PVI 22.9 

69 CP02 69-PVJ 8.8 

69 CP02 69-PVK 12.0 

69 CP02 69-PVL 30.2 

69 CP02 69-PVM 6.4 

69 CP02 69-PVN 12.1 

69 CP02 69-PVO 13.5 

69 CP02 69-PVP 11.5 

69 CP02 69-PVQ 28.4 

69 CP02 69-PVS 11.3 

69 CP02 69-PVT 10.7 

69 CP02 69-PWF 4.0 

69 CP02 69-PWP 4.0 

70 CP05 70-PXX 10.4 

70 CP05 70-PXY 9.2 

70 CP05 70-PXZ 7.3 

70 CP05 70-PZA 24.1 

70 CP05 70-PZB 14.7 

70 CP05 70-PZC 4.8 

55


70 CP05 70-PZD 10.2 

70 CP05 70-PZE 10.6 

70 CP05 70-PZF 8.0 

82 CP02 82-MCB 9.4 

82 CP02 82-MCC 16.2 

82 CP02 82-MCD 22.9 

82 CP02 82-MCE 8.9 

82 CP02 82-MCF 9.7 

82 CP02 82-MCG 15.1 

82 CP02 82-MCH 23.8 

82 CP02 82-MCJ 21.9 

82 CP02 82-MCK 23.7 

82 CP02 82-MCM 1.3 

82 CP02 82-MFA 14.3 

82 CP02 82-MFB 12.6 

82 CP02 82-MFC 10.5 

83 CP21 84-SDZ 0.9 

84 CP32 84-TJE 25.7 

84 CP32 84-TJF 21.5 

84 CP32 84-TJG 45.2 

84 CP32 84-TJH 22.7 

84 CP32 84-TJJ 15.0 

84 CP32 84-TJL 15.0 

84 CP32 84-TJM 14.1 

84 CP32 84-TJN 14.7 

84 CP32 84-TJP 8.5 

84 CP32 84-TJQ 10.4 

84 CP42 84-TJK 28.8 

85 CP21 85-YNA 7.0 

85 CP21 85-YNB 10.3 

85 CP21 85-YNC 7.0 

85 CP21 85-YND 12.0 

85 CP21 85-YNE 13.0 

85 CP21 85-YNF 7.5 

85 CP21 85-YNG 13.0 

85 CP21 85-YNH 9.5 

85 CP21 85-YNJ 22.7 

85 CP21 85-YNK 18.7 

85 CP21 85-YNL 13.2 

85 CP21 85-YNM 5.8 

85 CP21 85-YNN 5.1 

85 CP21 85-YNP 13.7 

85 CP21 85-YNQ 11.0 

85 CP21 85-YNR 11.0 

85 CP21 85-YNS 9.7 

85 CP21 85-YNT 9.0 

85 CP21 85-YNW 3.0 

85 CP21 85-YNX 13.5 

85 CP21 85-YNY 5.0 

85 CP21 85-YNZ 6.0 

85 CP21 85-YPA 4.5 

85 CP21 85-YPB 6.5 

85 CP21 85-YPC 4.0 

56

APPENDIX 2 – DATA 

PEPS-SA ® (Attribute) 

PIRSA has developed PEPS-SA (Petroleum Exploration 

and Production System—South Australia), a comprehensive 

relational database containing a range of technical data 

relevant to the petroleum industry. PEPS-SA is being 

continually developed and is available for purchase. The 

key data element is the petroleum well, of which there are 

~1600 in SA. For each well there may be thousands of 

attributes. There are eight key modules comprising 99 data 

sets (see below). 

Data are supplied with a PEPS-SA menu-driven 

windows system. For clients without Paradox, a copy of 

Paradox Runtime and software to query and export the data 

are provided. 

PEPS-SA ® (Spatial) 

Bundled with the attribute data are Mapinfo spatial 

datasets. Viewing this data in a mapping package allows the 

geoscientist to turn on and off various layers of interest, 

zoom in and out etc, to allow the generation of a custom built 

base map which can be printed. 

There are more than 60 separate layers, ranging from 

general topographic data such as state boundaries, coastline, 

national parks and restricted areas, road, railways and 

various tenements, through to geologic layers such as basin 

outlines, well locations, seismic lines, seismic horizons, 

tectonic provinces, and many more. 

The PEPS-SA attribute and spatial data are bundled 

together as one package on CD-ROM which costs $3000. 

Update of PEPS-SA twice a year costs an additional $300 

per year. 

Contact Alan Sansome Ph: (08) 8463 3221, 

Fax: (08) 8463 3229, 

e-mail: asansome@msgate.mesa.sa.gov.au 

Core Photos 

The department has recently scanned all petroleum core 

photographs and the thumbnail images are present in the 

data package if you receive the CD-ROM version. Full size 

images are approximately 1500 pixels by 1000 pixels by 256 

colours. The total set contains over 1900 images and 

occupies 1.4 Gigabytes. These are available for purchase 

($250) on CD-ROM (3 disks) together with viewing 

software. The software links the photo to the attribute data. 


Fax: (08) 8463 3229, 


Well Logs (Petlog) 

The digital open hole well log database includes field 

and edit tapes, and higher resolution data including 

dipmeter, FMS (Formation Microscanner), array sonic and 

VSP (Vertical Seismic Profile). These data are now 

available in a variety of formats and media including 

CD-ROM. 

Data are available as: 

• basic validated data as originally supplied in digital 

format, EDIT or FIELD processing 

• fully verified and merged digital data, or data 

digitised from analogue source. 

PIRSA will provide quotes on application for well logs. 


Fax: (08) 8463 3229, 


Seismic Shotpoint Database 

This is a comprehensive digital data set of shotpoint 

locations and associated attribute data from ~611 surveys 

carried out in the State and adjacent waters to 40°S latitude 

between 1955 and 1997. These data are maintained in 

Engineering Abandonment's; casing details; formation tests (open & closed); liquid evaluation tests; perforations; treatments; well tests. 

Geology Aromatic hydrocarbons; core analysis; cores including (core photograph thumbnails); cuttings; formation tops; 

hydrocarbon bulk composition; palynology; Rock-Eval; saturated hydrocarbons; source rock extracts; thin sections; 

vitrinite reflectance. 

Geophysics Seismic analog tapes; seismic exabyte tapes (including raw field data and processed data); seismic lines; seismic 

sections; seismic survey marks; seismic survey reports; seismic surveys; surveys and lines; synthetic seismograms, 

permanent survey markers. 

Log data Index to log paper prints; index of digital logs; log codes; log headers and bottom hole temperatures. 

Miscellany Petroleum act; petroleum regulations. Statistics – AGL sales; expenditure; consumer price index; crude oil prices; gas 

pricing, gas sales; liquid sales; petroleum royalties; raw gas; seismic surveys; wells drilled. 

Production CO 2; crude oil; crude oil production summary; crude oil test data; crude unit oil; enhanced oil recovery gas injection 

volumes; gas field reservoir data; Katnook gas production; oil field reservoir data; raw gas deliverability; raw gas 

production summary; raw gas production completion summary; raw gas production. 

Production graphs – Cooper Basin only – production history (gas, oil); decline curve (gas, oil); completions (gas, oil); water 

ratio (gas); water ratio history (gas); average gas rates (gas); gas rate history (gas); completion days (gas, oil); oil cut 

decline (oil); oil cut history (oil); average oil rates (oil); oil rate history (oil); production versus cumulative (gas, oil). 

Tenements PELs; PPLs; PLs; pipeline sections. 

Wells Basic well data — well completion reports. 

57

ArcInfo where complex GIS analysis and modelling can be 

performed with other digital data sets. The index to these 

data and summary information are also available in PEPS. 

Digital data are available for purchase in various formats 

on exabyte tape or diskette. Hard copy maps can be prepared 

for any area at any scale. 

Contact Dave Cockshell Ph: (08) 8463 3233, 

Fax: (08) 8463 3229, 

e-mail: dcockshell@msgate.mesa.sa.gov.au 

Seismic Mapping 

A program commenced in 1989 to consolidate open file 

basic and interpreted data into coherent data sets. The aim 

was to prepare regional interpretations of basin structure to 

attract explorers into prospective basins with vacant acreage. 

This program is nearing completion for the major onshore 

and large areas of the offshore basins. 

Cooper Basin Folio 

This folio is the culmination of an extensive seismic 

mapping and interpretation of the Cooper and Eromanga 

Basins in SA. Whilst this folio is restricted to the immediate 

area of PELs 5 and 6, regional datasets covering the 

Eromanga and Cooper Basins in SA, Queensland, NSW and 

the NT have been prepared as part of the National 

Geoscience Mapping Accord. 

• Volume 1 of the Cooper Basin Folio contains key 

seismic depth structure maps, formation isopachs 

and structural elements. 

• Volume 2 contains geological datasets including 

lithofacies maps and maturity maps of key source 

intervals (depths to oil and gas windows). 

All data are available in digital format and are 

supplemented by individual technical reports available from 

PIRSA. Each volume of the folio costs $1999, including 

postage and packing. In addition, individual hard copy maps 

can be purchased from $100 each, however discounts are 

available if map sets are purchased. 

Stack Seismic Data 

Archive processed data in SEG-y format are available for 

4474 seismic lines from the existing PEL 5 and 6 area. In 

most cases 3 versions of data are available: 

• Filtered Final 

• Filtered Migration 

• Raw Final for each line (where produced). 

PIRSA has a total of some 12300 data files on 12 

Exabyte Tapes. All data has had SP/CDP relationships 

embedded in the EBCIDIC header, and supporting attribute 

data relating to the line and data files. Approximately 10 % 

of all the data has been verified as correct and readable in the 

Geoquest IESX. 

Contact Dave Cockshell Ph: (08) 8463 3233, 

Fax: (08) 8463 3229, 

e-mail: dcockshell@msgate.mesa.sa.gov.au 

Core Library 

Confidential and open file drillhole samples obtained 

from company and departmental petroleum, stratigraphic 

58 

and mineral exploration are stored at the PIRSA Core 

Library. Over 3 million metres of core and cuttings from 

24 000 drillholes are currently stored. The Core Library is 

located at 23 Conyngham St, Glenside. Viewing facilities 

are fully enclosed. All open file samples are available for 

inspection and sampling is permitted. Forty-eight hours 

notice is required. 

Contact Brian Logan Ph: (08) 8379 9574, 

Fax: (08) 8338 1925, 

e-mail blogan@msgate.mesa.sa.gov.au 

Petroleum Tenements 

An A4 size petroleum tenement map, including a listing 

of tenement, holder(s) and interests, expiry date and area, is 

prepared quarterly and is free on request. 

Contact Mario Collela Ph: (08) 8463 3209, 

Fax: (08) 8463 3229, 

e-mail mcollela@msgate.mesa.sa.gov.au 

All tenements granted, surrendered or cancelled are 

published in the South Australian Government Gazette 

issued weekly from the State Information Centre, 25 

Grenfell St, Adelaide. These notices are also widely 

publicised in the business, investment and resources sectors 

of the local and international press, as well as by circulation 

to listed exploration companies, stockbrokers, etc. 

Aeromagnetic Database 

A digital database of aeromagnetic survey boundaries 

has been compiled and gives the location of all airborne 

surveys over South Australia and adjacent waters. 

Contact: Dominic Calandro Ph: (08) 8463 3051, 

Fax: (08) 8463 3040, 

e-mail dcalandro@msgate.mesa.sa.gov.au 

Digital Geological Maps Of South Australia 

SA_DISPLAY — An integrated set of State-wide 

geological, geophysical, geochemical and groundwater 

databases brought together in GIS where they can be 

digitally overlain and interrogated. Available in ArcView 

and MapInfo formats. 

SA_GEOLOGY — A library of digital geological maps 

that provides detailed, up to date GIS coverages of the 

State’s geology. Available in ASCII, ArcInfo, DXF, 

ArcView and MapInfo formats. 

Contact Stephen Bell Ph: (08) 8463 3288, 

Fax: (08) 8463 3268, 

e-mail sbell@msgate.mesa.sa.gov.au 

Miscellaneous Data 

PIRSA holds the largest collection of South Australian 

geoscientific literature, mining and exploration data, dating 

from the 1850s. The data comprises open file company 

exploration reports (including well completion reports), 

PIRSA open file report books, geophysical data including 

seismic sections, government publications, geoscientific 

maps, plans, publications and more. 

Contact Peter Dunne Ph: (08) 8463 3003, 

Fax: (08) 8204 1880 

e-mail pdunne@msgate.mesa.sa.gov.au

Document Storage Centre 

The PIRSA Document Storage Centre is responsible for 

storing and copying all unpublished material. Copies may 

be ordered in paper, microfiche and transparency media. 

The centre strives to complete standard orders within two 

days. 

Contact Peter Dunne Ph: (08) 8463 3003, 

Fax: (08) 8204 1880 

e-mail pdunne@msgate.mesa.sa.gov.au 

Web Site 

To be kept on a more up to date basis on what is 

happening in South Australia, why not visit our web site at 

www.mines.sa.gov.au/petrol 

59

APPENDIX 3 – LICENCE APPLICATION 

FORM AND PROCEDURES 

Review of Petroleum Act 

A Green paper on a review of the Petroleum Act 1940 

was released in 1997 and comments from industry and other 

interested parties received. Comments have been 

considered and Legislation is currently being drafted. It is 

anticipated that the draft Bill will be ready for Industry and 

other interest groups comments in October 1998. 

Key elements to changes in the Petroleum Act include 

implementation of objective regulation, with the willing 

assistance of industry; changes to the issue of tenements 

A draft Bill for a new South Australian Petroleum Act 

has very recently been made available for comment. This 

follows analysis of submissions following release of a 

Discussion Paper in 1996 and a Green paper last year. The 

legislation governing onshore petroleum exploration and 

production in south Australia had not undergone a major 

review since the Petroleum Act was proclaimed in 1940, 

although a number of amendments have been made from 

time to time. This legislation has served as an effective basis 

for regulation of the upstream petroleum industry. It has 

become evident, however, that the existing prescriptive 

regime is becoming less effective as advances are made in 

regulatory practice and community aspirations. The main 

thrust of the proposed legislation is to provide a modern, 

pro-competitive, efficient and flexible basis for 

administration of petroleum exploration and development. 

The objective is to establish a business environment that 

maximises investment opportunities for the exploration 

industry in the State and facilitates the development of 

discoveries. The main features of the Bill are: 

• establishment of a co-regulatory regime focussing 

on achievement of environmental, public safety and 

resource management objectives and reduced 

compliance costs (this is strongly supported by both 

industry and community interest groups); 

• licence allocation and management mechanisms to 

facilitate competition in line with competition policy 

principles; 

• rights of third party access to licensed pipelines 

(where not covered by the national access regime), to 

depleted reservoirs (for gas storage purposes); and to 

pipeline easements; 

• greater security of tenure for licences though 

improved registration procedures; 

• public consultation processes with regard to 

establishment of environmental objectives and for 

significant proposed activities (consistent with 

provisions of the Development Act); 

• reduced risk to Government for liabilities arising 

from the industry’s activities; 

• increased royalties from 2001 and a fee structure 

designed to encourage the adoption by industry of 

management systems to undertake their activities; 

and 

• the ‘grandfathering’ of existing Petroleum 

Exploration and Production Licence rights, with new 

exploration licences having rights to Retention 

60 

Licences but stricter criteria for Production 

Licences. 

The Occupational Health and Safety (OH&S) provision 

of the Petroleum Regulations have been repealed and 

substituted by regulation under the OH&S Act. 

Application 

Although there is no form set by regulation, an 

application for a Petroleum Exploration Licence (PEL) may 

be lodged in accordance with the attached pro forma, and 

should be accompanied by two copies of a plan of the 

application area and accompanied by the prescribed fee 

(which is currently A$ 2240 for each licence applied for). 

An application for a PEL can be lodged at any time over 

any area of the State not currently under a PEL or a 

Petroleum Production Licence (PPL) unless applications for 

the area have been specifically invited and a closing date 

nominated for receipt of applications. 

An application can be made by an individual(s) or a 

company(s) or a combination of an individual(s) or a 

company(s). When a foreign company makes an 

application, the foreign company must be registered as a 

foreign company under the provisions of the Australian 

Corporations Law. Information on registration 

requirements can be supplied on request. 

Technical Qualifications/Experience 

The applicant must submit with the application a 

summary of the technical qualifications of the applicant (or 

consultants/agents of the applicant) to satisfy requirements 

that the applicant is capable of satisfying compliance with 

the Petroleum Act and the terms and conditions of the 

licence. 

Financial Position 

Evidence of the financial position of the applicant is to be 

supplied to demonstrate ability to fulfil the proposed work 

program. Such evidence can be in the form of the latest 

annual report or a verifiable statement from an independent 

accountant/auditor/ financial institution. If financial 

resources are not available for the full five year program, the 

applicant will have to provide evidence that there are 

financial resources available for at least the first licence year 

program prior to the grant of the licence. 

Work Program 

The applicant must submit with the application a 

statement of exploratory operations the applicant proposes 

to carry out in each year of the five year term of the licence, 

including an estimate of exploration expenditure to be 

incurred in each year of the licence. 

A minimum exploratory expenditure for each of the first 

two years of the licence is $16 /km² per year, and $24 /km² 

for each of the remaining three years. 

Award Criteria 

The basic objective in awarding a Petroleum Exploration 

Licence is to select the work program most likely to achieve 

the fullest assessment of the petroleum potential within the 

licence over the initial five year licence term recognising the 

essential role of wells in the discovery of petroleum. Work

program bids will be assessed taking account of the criteria 

listed below. 

The criteria for assessment of work programs, not 

necessarily in order of priority are: 

• The number of wells to be drilled and their timing; 

• The amount and nature of seismic surveying to be 

carried out and its timing; 

• The number of years that an applicant is willing to 

guarantee the work program; 

• Other data acquisition and reprocessing to be carried 

out; 

• The extent to which the proposed work program 

reflects the information available from previous 

exploration; 

• The adequacy of financial resources and technical 

expertise available to the applicant. 

In addition to the above criteria, where work program 

bids are very similar, the benefits of the introduction of new 

explorers into the area may be taken into account. 

It should be noted that there are no criteria limiting the 

number of PELs which may be offered to one applicant 

(although in considering Competition Policy Principles it 

would require major work program benefits to offer more 

than three PELs to the one applicant in the first round of 

bidding). There will be no consideration taken of the 

success of applicants in the various bidding rounds in 

selecting successful applicants. 

Once a licence has been granted, a licensee is obliged to 

carry out the work program stipulated in the year the licence 

is in. Any failure to fulfil the work program for that year 

may, if a genuine ‘force majeure’ case is not proved, may 

result in cancellation of the licence. Variation of licence 

conditions are possible, however this would only generally 

be done where extraordinary cause exists, especially for a 

licence issued for which there were competing bids. 

Santos exploration drilling update 

Santos have amended their drilling program and a well 

may be drilled north of James 1 in Block CO98-C. Should 

this well, or any others proposed in Blocks CO98-A to K 

discover hydrocarbons before expiry of PELs 5&6, the PPL 

area will be excised from the relevant Block. However, 

basic data associated with wells will be available on expiry 

of PELs 5&6 on 1 March 1999. 

61

62 

PEL APPLICATION CHECKLIST 

The following information must be included in the 

licence application: 

1. Complete the attached PRO FORMA and 

include two copies of a plan of the application 

area. 

2. PRO FORMA application must be signed by 

individual applicants and if the application is 

made by a consortium including a company(s) 

the application must be made under the 

company(s) seal. 

3. If applicant is a foreign company, the company 

must be registered as a foreign company under 

the provisions of the Australian Corporations 

Law. 

4. A summary of the technical qualifications of 

the applicant (or consultants/agents of the 

applicant). 

5. Evidence of the financial position of the 

applicant to demonstrate ability to fulfil the 

proposed work program (i.e. the latest annual 

report or a verifiable statement from an 

independent accountant/auditor/ financial 

institution). 

6. A statement of exploratory operations the 

applicant proposes to carry out in each year of the 

five year term of the licence, including an 

estimate of exploration expenditure to be 

incurred in each year of the licence. 

7. The prescribed fee of A$2240 for each licence 

applied for, made payable to Primary Industries 

and Resources SA.

APPLICATION FOR PETROLEUM EXPLORATION LICENCE 

PETROLEUM ACT, 1940 (SECTION 7) 

To the Chief Executive, Department of Primary Industries and Resources South Australia 

I/We,. .............................................................. 

.................................................................. 

.................................................................. 

hereby make application for the grant of a petroleum exploration licence in respect of the area described hereunder [please tick 

block(s) you are applying for]: 

DESCRIPTION OF AREA 

Block Tick here Approximate area 

km2 Acres (million) 

CO98-A � 4316 1.066 

CO98-B � 4315 1.066 

CO98-C � 4987 1.232 

CO98-D � 4891 1.208 

CO98-E � 1365 0.337 

CO98-F � 2964 0.732 

CO98-G � 2878 0.711 

CO98-H � 1884 0.465 

CO98-I � 2703 0.668 

CO98-J � 3893 0.962 

CO98-K � 5236 1.294 

Note each Block is offered as a separate licence and the application fee is currently A$2240 per licence. Details in support of 

the application (see Checklist) and the application fee of $....................... are attached. 

............................................. .............................. 

............................................. .............................. 

Signature of applicants(s). Where application is made by a consortium including a company(s), the application must be made 

under the company(s) seal. 

Dated this ...................................... day of ...................................... 19............ 

CLOSING DATE: 4.00 pm ON 11 MARCH 1999 

SEND APPLICATIONS TO: 

The Chief Executive PIRSA 

C/o Director, Petroleum Group Phone: IAC 61 8 8463 3204 

Primary Industries and Resources SA Facsimile: IAC 61 8 8463 3229 

GPO Box 1671, Adelaide, SA, 5001, AUSTRALIA. 

63

COOPER BASIN EXPLORATION OPPORTUNITY BLOCKS ... - MISA

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