COOPER–EROMANGA BASIN - Petroleum · The first Cooper Basin oil was discovered in Tirrawarra 1 in...

COOPER–EROMANGA

BASIN

COOPER–EROMANGA

BASIN

EXPLORATION OPPORTUNITIES

BLOCKS CO98A–K

October 1998

COOPER 99

COOPER BASIN

EXPLORATION OPPORTUNITY

BLOCKS CO98-A to K

Compiled by

Elinor AlexanderPetroleum Group

OCTOBER 1998

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

© Department of Primary Industries and Resources South Australia, 1998This 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 RESOURCESSOUTH AUSTRALIA

REPORT BOOK 98/00029

COOPER BASIN EXPLORATION OPPORTUNITYBLOCKS 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 regionhas been under licence continuously since 1954 and is currently held by Santos and partners – PELs 5 & 6 cover 67 000 km2.Since 1954, Santos and joint venture partners have drilled over 1200 exploration, appraisal and development wells. At 30September 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 gaswas 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 lineand 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 ofLPG were sold.

On 28 February 1999, PELs 5&6 expire and the South Australian Government has decided that the Cooper Basin, exclusive ofproduction (and potentially retention) tenements will be made available for competitive bidding. In order to facilitate thisprocess, reviews of the legislative regime, data issues and a review of the necessity of access to existing processing plant andassociated infrastructure have been conducted.

The opening of the Cooper Basin to competitive bidding provides a unique opportunity for explorers. Advantages includeestablished infrastructure and markets, proven play concepts, high wildcat discovery rates, access to detailed data and agovernment 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 blocksbefore the expiry of PELs 5 & 6 is designed to ensure a smooth transition by minimising delays in new exploration in theCooper Basin.

Applications may be made for any or all of the areas CO98-A to K. Licences are offered on the basis of the most competitivework program. In the event that more than one area is offered to an applicant for licence, there is no obligation for the applicantto accept any or all of the offers. In addition, applications for this first release of acreage will in no way prejudice successfulapplications 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 3204C/o Director, Petroleum Group Facsimile: IAC 61 8 8463 3229PIRSA Website: www.mines.sa.gov.au/petrolGPO Box 1671,Adelaide, SA, 5001AUSTRALIA

Applications should be accompanied by a proposed five year work program, a map of the area applied for, a $2 240 applicationfee and details of the technical and financial resources of the applicant (an application form and summary guidelines areincluded in Appendix 3).

4

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

Block Area Last Drilled No. wells Seismic Line Basins and targetskm2 Acres (x 106) km

CO-98A 4316 1.066 - 0 405 Eromanga, Simpson and Warburton Basins, oilCO-98B 4315 1.066 1963 1 508 Eromanga and Warburton Basin, oilCO-98C 4987 1.232 1989 9 2336 Eromanga, Cooper and Warburton Basin, oilCO-98D 4891 1.208 1984 2 1263 Eromanga, Simpson and Warburton Basins, oilCO-98E 1365 0.337 1997 11 2499 Eromanga, Cooper and Warburton Basins, oilCO-98F 2964 0.732 1967 2 1745 Eromanga, Cooper and Warburton Basins, oilCO-98G 2878 0.711 1991 3 2365 Eromanga, Cooper and Warburton Basins, oilCO-98H 1884 0.465 1996 7 2014 Eromanga, Cooper and Warburton Basins, oilCO-98I 2703 0.668 1996 1 1689 Eromanga, Cooper and Warburton Basins, oilCO-98J 3893 0.962 1987 5 3019 Eromanga, Cooper and Warburton Basins, oilCO-98K 5236 1.294 1970 4 1619 Eromanga, Cooper and Warburton Basins, oil

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

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Fig. 1. Cooper Basin location.

EXPLORATION HISTORY

The Cooper Basin forms the most significant element ofAustralia’s largest onshore oil and gas province (Fig. 1).Petroleum exploration commenced in the region in 1954with the granting of OEL 7 to R. Bristowe on behalf ofSantos. Early exploration targeted the Cambro-Ordovicianand in 1959 Innamincka 1 was drilled, following areflection-refraction survey carried out over InnaminckaDome with Delhi Petroleum as operator. Additionalreflection surveys over the ensuing years led to the discoveryof gas in the Permian section in Gidgealpa 2 in 1963 andthree years later the ‘giant’ Moomba gas field wasdiscovered. One third of South Australia’s Cooper Basingas reserves are in the Moomba and neighbouring Big Lakefields. The decision to generate the bulk of South Australia’selectricity from natural gas ensured the economic viabilityof constructing and operating the Moomba–Adelaidepipeline, and gas was first supplied to Adelaide in 1969.PELs 5 and 6 were granted to Delhi and Santos in 1969 toreplace OELs 20 and 21. During 1973 an agreement wassigned by the Cooper Basin Producers to supply gas for theNew South Wales market and a pipeline was constructedlinking Moomba and Sydney.

The first Cooper Basin oil was discovered in Tirrawarra1 in 1970. The Tirrawarra field contains 80 per cent ofknown oil reserves in the SA region. Eromanga Basin oilwas discovered in 1977 with an uneconomic flow fromPoolowanna 1 (Poolowanna Trough) and the first economicoil flow was recorded from Strzelecki 3 in the followingyear. In order to market newly discovered oil and existinggas liquids, the Cooper Basin Liquids Project was initiatedin 1980 and completed in stages from 1982 to 1984 at a costof $1.4 billion. The project involved the construction of ahigh vapour pressure liquids pipeline from Moomba to aprocessing plant and storage and loading facilities at PortBonython, as well as field development, oil collection andcrude stabilisation facilities at Moomba.

Shipments of crude oil and condensate commenced in1983 and LPG handling facilities were commissioned inJuly 1984. The establishment of these facilities enabled theCooper Basin Producers to bring the wet gas reservoirs intoproduction, which further enhanced production flexibility.In 1991 condensate production from Port Bonython wasreplaced by a full range naphtha, which has a greater marketvalue.

In 1991 a contract was signed for the sale of natural gasby the South–West Queensland Producers to SouthAustralia. The gas is delivered to the South Australianmarket via a 190 km pipeline constructed by the Producers tolink the Queensland gas fields with the Moomba processingfacility and Moomba–Adelaide natural gas pipeline. Anagreement was finalised between Santos on behalf of theCooper Basin Producers and ICI in 1994 to supply ethanefrom Moomba to a petrochemical plant in Botany Bay. Apipeline was constructed and supply commenced in June1996.

Since 1963, a total of 229 billion cubic metres (8.2 tcf) ofrecoverable raw gas and 6.9 million cubic metres (43.9million stocktank barrels) of recoverable oil have beendiscovered in the Cooper and Eromanga Basins in SouthAustralia.

GEOLOGICAL SUMMARY

Eromanga Basin

The Eromanga Basin covers one million squarekilometres of central-eastern Australia and contains themulti-aquifer system of the Great Artesian Basin. Itunconformably overlies the Cooper and Warburton Basins.Eromanga Basin stratigraphy can be divided into threesequences – lower non-marine, marine and uppernon-marine (Fig. 2). Exploration is concentrated on theproductive lower non-marine sequence.

The lowermost unit of the Eromanga Basin is the Early toMiddle Jurassic Poolowanna Formation, which consists ofinterbedded siltstone, sandstone and coal, deposited in highsinuosity fluvial and floodplain environments. PoolowannaFormation intertongues with and is overlain by low sinuosityfluvial deposits of the Hutton and Algebuckina Sandstones.Basinward lateral equivalents of the Algebuckina Sandstoneare Hutton Sandstone, Birkhead Formation, AdoriSandstone, Westbourne Formation, Namur Sandstone andMurta Formation. The Hutton, Adori and NamurSandstones are similar in lithology and facies to theAlgebuckina but with an additional volcaniclasticcomponent in minor amounts.

Middle to Late Jurassic Birkhead Formation consists ofinterbedded siltstone, coal and sandstone, Westbourne

6

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Cadna-owie Formation

Mackunda Formation

Oodnadatta Formation

Mount Howie

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Coorikiana Sst.

Bulldog Shale

Millyera Formation and equivalent

Yandruwantha Sand

Namba Formation

Eyre Formation

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Formation consists of interbedded siltstone and sandstone ofLate Jurassic age. Murta Formation and McKinlay Memberoverlie and intertongue with the Namur Sandstone andconsist of thinly interbedded siltstone, shale, sandstonedeposited in a large lake which extended throughout theCooper Basin region. The McKinlay Member is a lacustrineshoreface facies.

Cadna-owie Formation records the transition into openmarine conditions during the Early Cretaceous and consistsof interbedded sandstone, siltstone and claystone with minorcarbonate. The fluvio-deltaic Wyandra Sandstone Memberis developed at the top of the Cadna-owie Formation. Thecontact between sandstones of the upper Cadna-owieFormation (Wyandra Sandstone Member) and overlyingmarine shales of the Bulldog Shale or WallumbillaFormation approximates a prominent seismic reflector - theC horizon – which is mappable across the entire EromangaBasin (Fig. 3). Formations of the Early Cretaceous (Aptianto Albian) are of secondary interest to petroleum explorationin the area and are not discussed in detail. The marinesuccession is overlain by the rapidly deposited uppernon-marine sequence (Winton Formation) which consists ofcoal, floodplain and low sinuosity channel deposits.

A period of erosion and deep weathering in the LateCretaceous caused by a switch in drainage from the Cooperregion to the Ceduna Depocentre on the rifted southernmargin of the continent was followed by deposition of thenon-marine Cainozoic Lake Eyre Basin. The modernlandscape was formed during the Pliocene-Quaternary.

Simpson Basin

Non-marine Triassic sandstone, siltstone and shale of theSimpson Basin have been split into two formations. TheWalkandi Formation is the older unit and consists ofvaricoloured interbedded shale, siltstone and minorsandstone. Pedogenic structures indicate fluctuation of thewater table on a flood plain which was cut by high sinuosityfluvial channels. Walkandi Formation has been correlatedwith the Tinchoo Formation in the Cooper Basin, althoughTriassic palynological data are poor.

Walkandi Formation is conformably overlain by LateTriassic Peera Peera Formation which consists ofcarbonaceous shale, coal and thin sandstone interbedsdeposited in a high sinuosity fluvial environment. The PeeraPeera Formation is correlated with the Cuddapan Formationin the Cooper Basin region based on well preserved,distinctive palynomorphs.

Cooper Basin

The intracratonic Cooper Basin represents a LateCarboniferous to Triassic depositional episode. It liesunconformably over early Palaeozoic sediments of theWarburton Basin and is overlain disconformably by theEromanga Basin (Fig. 4). Three major troughs(Patchawarra, Nappamerri and Tenappera) are separated bystructural ridges (Gidgealpa-Merrimelia-Innamincka (GMI)and Murteree) associated with the reactivation ofnorthwest-directed thrust faults in the underlying WarburtonBasin. These troughs contain up to 2500 m ofPermo-Carboniferous to Triassic sedimentary fill overlainby as much as 1300 m of Jurassic to Tertiary cover.

The Cooper Basin unconformably overlies WarburtonBasin sediments. The Late Carboniferous to Early Permianformations comprise, in ascending order, the MerrimeliaFormation and Tirrawarra Sandstone which comprise aglaciofluvial system deposited on glacially sculpted flatlying to deformed Warburton Basin sediments and volcanicsand intrusives. The Tirrawarra Sandstone represents lowsinuosity fluvial to proglacial outwash deposits overlain bypeat swamp, floodplain and high sinuosity fluvial facies ofthe Patchawarra Formation.

Two lacustrine shale units (Murteree and RoseneathShales) with intervening fluvio-deltaic sediments (Epsilonand Daralingie Formations) were deposited during a phaseof continued subsidence. Early Permian uplift led to erosionof the Daralingie Formation and underlying units frombasement highs.

8

98-0015

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EROMANGA BASIN

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Fig. 4. Cooper Basin stratigraphy.

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

Floodplain, peat swamp and high sinuosity fluvial faciesof the Late Permian Toolachee Formation were deposited onthe Daralingie unconformity surface and are overlainconformably by Late Permian to Early Triassic ArraburyFormation. The uppermost coal, approximating the topPermian is mapped as the ‘P’ seismic horizon (Fig. 5). TheArrabury Formation comprise floodplain and channel faciesof the Callamurra, Paning and Wimma Sandstone Members,which are overlain by the Early Triassic Tinchoo Formation.

In the northern Patchawarra Trough, the Cooper Basin islocally overlain by the Middle to Late Triassic CuddapanFormation. Deposition in the region was terminated at theend of the Early Triassic with slight but widespreaddeformation, regional tilt and erosion.

Warburton Basin

The Cooper Basin is unconformably underlain bysediments and volcanics of the eastern Warburton Basin(Fig. 6). Warburton Basin sediments range from Cambrianto Ordovician; Devonian sediments have not beenintersected in the Cooper Basin region of South AustraliaThe eastern Warburton Basin is essentially a fold beltdeformed during the Late Devonian-Carboniferous AliceSprings Orogeny intruded by mid-Carboniferous granitoidsand subsequently buried to depths ranging from 1300 m toalmost 4000 m.

The eastern Warburton Basin contains a basal suite ofacid-intermediate volcanics, tuff and agglomerate(Mooracoochie Volcanics), overlain by dolomitised shelfallimestone historically assigned to the basal KalladeinaFormation. A Middle to Late Cambrian carbonate shelfdeveloped in the Coongie-Cuttapirie area, with a slope to theeast. Several depositional sequences have been identified inthe Kalladeina Formation typically with deep water shalesoverlain progressively by shallow water carbonate andclastic deposits. The Pando and Innamincka Formationscontinue this trend to shallow water depths as part of adeltaic complex with an extensive marine shelf sand. Blackshale of the Dullingari Group with rare graptolites wasdeposited in the deep water Larapintine Sea which extendedthrough the Warburton and Amadeus Basins to the CanningBasin.

Middle to Late Ordovician shale and siltstone constitutethe last preserved deposits of the eastern Warburton Basin.Early-Middle Carboniferous granitic intrusives (Big LakeSuite) beneath the Nappamerri and Wooloo Troughs wereresponsible for localised silicification and contactmetamorphism of Cambrian country rock. A weatheredzone up to 150 m thick has altered Warburton Basin strataand the granites in particular, immediately beneath theCooper Basin unconformity. The unconformity at the top ofthe Warburton Basin is mapped as the ‘Z’ seismic horizon(Fig. 7).

Structural style superimposed by compressionaldeformation during the Alice Springs Orogeny followsarcuate northeasterly trends imposed by northwest-directedthrust faults. Wrench fault zones have been mappedseismically in the Titan-Charo-Yanta area on the northwestflank of the Patchawarra Trough. Complex folding andfaulting occur in some parts of the basin, but in many regionsthe Early Palaeozoic is almost flat lying.

PETROLEUM GEOLOGY

Reservoirs

Eromanga Basin

Principal reservoirs are good to excellent reservoirquality Hutton and Namur Sandstones (porosities up to 25%,permeability up to 2500 mD). Oil is also reservoired in fairto excellent quality sandstones in the Poolowanna andBirkhead Formations, McKinlay Member and MurtaFormation. The Algebuckina Sandstone is a major artesianaquifer. The Cadna-owie Formation (Wyandra SandstoneMember) forms a significant oil reservoir in Queensland,however economic hydrocarbons have yet to be discoveredin this unit within SA.

Simpson Basin

Sandstone beds within the Walkandi and Peera PeeraFormation may form reservoirs in the eastern SimpsonBasin. Where deeply buried in the Poolowanna Trough tothe west, porosity and permeability have been severelyreduced by silica overgrowths.

Cooper Basin

Multi-zone high sinuosity fluvial sandstones form poorto good quality reservoirs. The main gas reservoirs occurprimarily within the Patchawarra Formation (porosities upto 23.8%, average 10.5% and permeability up to 2500 mD)and Toolachee Formation (porosities up to 25.3%, average12.4% and permeability up to 1995 mD). Shoreface anddelta distributary sands of the Epsilon and DaralingieFormations are also important reservoirs. Oil is produced

10

AGE

OR

DO

VIC

IAN

Early

Mid-Late

CA

MB

RIA

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Late

Middle

Early

PROTEROZOIC

CARBONACEOUS–CRETACEOUS

InnaminckaFormation

ROCK UNITCOOPER–EROMANGA BASINS

DULLINGARI

GROUP

MooracoochieVolcanics

KalladeinaFormation

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PandoFm.

Jena

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Fig. 6. Warburton Basin stratigraphy.

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principally from low sinuosity fluvial sands within theTirrawarra Sandstone (porosities up to 18.8%, average11.1% and permeability up to 329 mD). Towards the marginof the Cooper Basin, oil is also produced from thePatchawarra Formation.

The Callamurra Member of the Arrabury Formation isconventionally regarded as a regional seal but neverthelesscontains economic oil and gas reservoirs in some areas and isa leaky seal in others. Low sinuosity fluvial sandstones ofthe Paning and Wimma Sandstone Members form economicoil and gas reservoirs and high sinuosity fluvial sandstone ofthe Tinchoo Formation reservoir oil. As yet, there have beenno economic oil or gas fields discovered in the CuddapanFormation in South Australia.

Warburton Basin

Fractures in brittle siltstones (e.g. Dullingari Group inLycosa 1) are capable of storing commercial oil and gas.Fracture patterns and their relation to pre-Cooper andpost-Cooper Basin structure are currently being studied byPIRSA and NCPGG.

Pando Formation sandstone has surprisingly highporosity (~10%) in view of its low stratigraphic position. Itis glauconitic and zircon-rich and consequently has a highgamma ray response. Moolalla 1 gas is reservoired in thisformation which extends from Pando in the west to Moombain the northeast.

Basal and middle Kalladeina Formation dolomitesrepresent shelf limestones exposed to meteoric diagenesisduring marine lowstands. Although minor gas shows havebeen recorded, porosity prediction has proved elusive, thedolomites and associated karst breccias proving tight whendrilled.

Sturt 6 oil was produced from weathered tuff whichforms an extensive unit beneath the southwest CooperBasin. The tuff, together with underlying agglomerate andlava, comprises the Mooracoochie Volcanics. Both the oiland gas originated from Permian source rocks.

Source Rocks

Both Cooper and Eromanaga Basin mature source rockshave actively contributed to oil accumulations in the region.Each oil accumulation needs to be considered on its meritswith respect to the extent of ‘mixing’ from Permian andMesozoic sources.

Eromanga Basin

Oil originated either in the Eromanga or the CooperBasin or a mixture of both. Although it is recognised thatBirkhead and Murta Formation sources exist, there is stillconsiderable debate as to their extent and relativecontribution.

Potential source rocks of Jurassic and Early Cretaceousage contain Type II to Type III organic matter and have beenshown to have maturities within the ‘oil window’ (onset ofoil generation between vitrinite reflectance 0.65-0.7%).Significant suppression of Ro has been detected in someEromanga Basin source rocks. Average TOC and pyrolysisyields are slightly lower for Eromanga source rockscompared to Permian source rocks. However, the BirkheadFormation contains the most hydrogen-rich organic matterand has an average TOC of 2.5% and S2 pyrolysis yield of

10.8 kg/tonne. The Poolowanna Formation shows fair togood source richness; the Westbourne Formation exhibitsmainly fair source richness.

Hydrocarbon extracts of Jurassic potential source rocksare paraffinic and waxy and similar to those from Permiansediments. This lack of distinction probably reflects onlyminor changes in organic facies and/or maturation historiesor alternatively, reflects oil staining/contamination ofEromanga source rocks by migrat ing Permianhydrocarbons.

Oils in Cretaceous reservoirs are often geochemicallydistinct from those in Jurassic reservoirs. They are typicallylight (45° API gravity), non-waxy, low sulphur, paraffiniccrudes although waxy oils do occur. In Dullingari field,Murta Formation oils are thought to be locally sourced fromCretaceous source rocks.

The marine Cretaceous sequence contains good potentialsource rocks, however it is considered immature forhydrocarbon generation. Clearly, more work needs to bedone in order to distinguish local Eromanga Basin sourcing.

Simpson Basin

The Peera Peera Formation is rich in organic matter inthe Poolowanna Trough to the west (TOC up to 5%) and isconsidered to be gas-prone, with modest oil generativepotential.

Cooper Basin

Permian coal measures and shales are the principalhydrocarbon source rocks in the region and are dominatedby Type III kerogens derived from higher plantassemblages. Oils and condensates are typically medium tolight (30 to 60° API) and paraffinic, with low to high waxcontents. Most Permian oils in Permian reservoirs containsignificant dissolved gas and show no evidence of waterwashing. Gas composition is closely related tomaturity/depth with drier gas occurring towards basindepocentres although there is strong geological control onhydrocarbon composition.

The Patchawarra Trough contains the bulk of the oil andwet gas reserves consistent with local source rocks being inthe ‘oil window’ while the hot Nappamerri Trough(40–50°C/km), underlain in part by granite, is overmatureand contains mainly dry gas.

Permian source rocks have average TOC and S2pyrolysis yields of 3.9% and 6.9 kg/tonne, respectively(excluding coals). Locally, the Toolachee Formation is therichest source unit. The Patchawarra Formation isconsidered the other major source unit especially the lowershales and coals. The lacustrine Murteree and RoseneathShales appear to have little source potential.

Together, the petrographic and geochemical evidencesupport coals and associated DOM as the effective sourcerocks capable of generating gas and minor oil, albeit in lowyields. At maturity levels between 0.7-0.95% Ro, initialgeneration from the richer facies has led to partial filling ofreservoirs with wet gas and oil. There is a sharp onset ofsignificant hydrocarbon accumulation when the sourcereaches a maturity of 0.95% Ro.

Thin, laterally discontinuous coals represent the bestsource rocks of the upper Nappamerri Group whilst shales

12

tend to be organically lean. Kerogen in formations of thelower Nappamerri Group tends to be oxidised and sourcerocks are humic-rich and gas-prone.

Warburton Basin

Source rock quality of samples principally from theKalladeina Formation is poor to fair. With the exception ofanomalously low maturity indices from Kalladeina 1, thesuccession below 3000 m is late-mature to post-mature foroil. Organic matter is mainly Type II kerogen derived frommarine algal/bacterial precursors.

Seals and Plays

Where the regional seal is thin or absent multiple oil andgas pools are stacked in coaxial Permian-Mesozoicstructures and may occur from as low as the PatchawarraFormation to as high as the Murta Formation. Locally,Permian oil has migrated into Warburton Basin reservoirs onthe basin margin and gas has migrated into fracturedOrdovician reservoirs fringing the Allunga Trough.

Eromanga Basin

Trapping mechanisms are dominantly structural(anticlines with four–way dip closure or drapes overpre-existing highs) with a stratigraphic component (e.g.Hutton–Birkhead transition, Poolowanna facies, McKinlayMember and Murta Formation). Eromanga structures inSouth Australia are rarely filled to spill with oil – net oilcolumns are relatively thin compared to the height underclosure (due to poor sealing characteristics). Seals consist ofintraformational siltstones and shales of the Poolowanna,Birkhead and Murta Formations – no economichydrocarbons have been discovered in SA above the MurtaFormation. Where these units are absent, potential sealsinclude Bulldog Shale and Wallumbilla Formation.

Cooper Basin

Anticlinal and faulted anticlinal traps have been relied onas proven exploration targets but potential remains high fordiscoveries in stratigraphic and sub-unconformity traps,especially where the Permian sediments are truncated by theoverlying Eromanga Basin succession. Economic oil andgas are reservoired in the Nappamerri Group, paradoxically

regarded as a regional seal to the Cooper Basin.Intraformational shale and coal form local seals in the majorreservoir units. Beneath the Daralingie Unconformity aretwo important early Permian regional seals - the Roseneathand Murteree Shales. The Roseneath Shale is the top seal ofthe Epsilon Formation and the Murteree Shale seals thePatchawarra Formation.

Warburton Basin

Cooper Basin reservoirs, source rocks and seals havebeen juxtaposed against elevated ridges of Warburton Basinrock by faulting or by original deposition. These ridges arepotential lateral seals but may also be reservoirs. Ridges arecomposed of sandstone, shale, carbonate and volcanic units,which are fresh to severely altered by weathering anddiagenesis (but not metamorphism). Dips vary fromhorizontal to vertical, and units range from massive toslightly to pervasively fractured, with weak to strongfaulting and folding. Their competence as lateral seals isdependent upon a combination of lithologic and structuralfactors.

Potential traps in the Warburton Basin include largehanging wall anticlines associated with northeasterlytrending thrust faults and upthrown fault blocks on wrenchfault zones.

A thick impermeable weathered profile on the topWarburton unconformity surface forms a semi-regional sealand 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 instratigraphic and sub-unconformity traps, which havereceived increasing interest in the past five years. Pinchoutplays along the margins of the Cooper Basin have beentested with commercial success. 3D seismic will have acritical role to play in delineating more subtle traps in thefuture.

Remaining South Australian Cooper–Eromangareserves estimated by Santos at 1 January 1997 were 2534 PJof sales gas, 5.08 x 106 t of LPG, 5.61 x 106 kL ofcondensate, 5.33 x 106 kL of crude oil and 349 PJ of ethane.Undiscovered reserves of hydrocarbons have also beenestimated by PIRSA, the Bureau of Resource Sciences(BRS) and Stratigraphic Research International AS(APRAS) to predict the undiscovered potential of theCooper and Eromanga Basins. Results are summarisedbelow. For more detail, refer to The Petroleum Geology ofSA – Volume 4, Cooper Basin.

Cooper Basin gas

The present discovered recoverable raw gas reserves (asat 1/1/98) of the basin are 229 billion cubic metres (8.2 TCF)comprising 129 billion cubic metres (4.6 TCF) of producedgas and 101 billion cubic metres (3.6 TCF) of gas yet to beproduced from known discoveries. The average recoveryfactor for gas fields is 64%. There have been 121 CooperBasin gas fields discovered in South Australia to 1/1/98 from298 new field wildcats.

13

Cenozoic

LAKE EYRE

BASIN

COOPER

BASIN

WARBURTON

BASIN

Jurassic-Cretaceous

Permo-Triassic

Cambro-Ordovician

EROMANGA

BASIN

1000

2000

3000

metres

Source rock Shale

Gas Sandstone

Oil Carbonate98-1407

Fig. 8. Hydrocarbon plays schematic.

Cooper–Eromanga Basin oil

The present recoverable oil reserves (as at 1/1/98) of thebasin are 6.9 million cubic metres (43.9 MMSTB)comprising 4.6 million cubic metres (29.1 MMSTB) ofproduced oil and 2.3 million cubic metres (14.8 MMSTB) ofoil yet to be produced from known discoveries. Thecombined average primary and secondary recovery factorfor oil fields is 21%. More than 80% of the oil reserves arecontained in the Tirrawarra Field. There have been 25Cooper oil fields discovered in South Australia up to 1/1/98from 297 new field wildcats. In the overlying EromangaBasin, there have been 33 oil fields discovered from 293wildcats (to 1/1/93).

Results

Potential (undiscovered) resources should not becompared to traditional Proved, Probable and Possiblereserves in known discoveries. Undiscovered resources arecalculated to give a quantitative indication of the potential ofthe basin, and require considerable exploration to establishtheir existence. The results of methods considered to bereasonably reliable are summarised below.

Some of the potential attributed to the Cooper Basin mayhave already been discovered in the Eromanga Basin. Thecurrent discovered recoverable oil reserves of the EromangaBasin in the Cooper Basin region are 14.5 million cubicmetres (92.5 mmstb).

INFRASTRUCTURE AND MARKETS

Production Facilities

A total of 5090 km of pipeline have been laid to gasmarkets in SA and NSW and to the liquids load out facility atPort Bonython. Key pipelines are listed in Table 4 andshown on Figure 1.

Gas emerges at the wellhead at pressures up to25000 kPa and temperatures up to 120°C. Gas fromindividual wells passes via field gathering systems(flowlines) to satellite stations which separate gas, free waterand condensate. Evaporation ponds are used for waterdisposal. The essentially water-free gas and condensate passto the Moomba treatment plant through trunklines. Crudeoil is transported by either pipeline or truck to the Moombaplant. Currently, nine oil and eleven gas satellites are in

14

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)

Table 4. Major Cooper Basin pipelines

PL Pipeline name Operator Product Length Pipe diam. MAOP Construction(km) (mm) KPa Period

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

+ 12 laterals various 1969–90

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

operat ion in the Cooper and Eromanga Basins.Approximately 1010 km of trunklines and 1135 m offlowlines have been laid to date in the region.

At the Moomba plant free condensate and water areinitially removed from the raw gas at the slug catchers. Thegas then proceeds to the Benfield unit to ensure that nogreater than 3% by volume of CO2 remains in the sales gasstream. The gas is dehydrated at molecular sieves before itproceeds to the liquid recovery plant where 100% of theremaining condensate, 98% of the LPG (C3 and C4) and75% of the ethane are removed, leaving sales gas forAdelaide and Sydney with a heating value %.5 megajoulesper cubic metre. The plant has been designed to process 25.4x 106 m3 (902 mmcf) of raw gas and 6000 kL (42 000 bbl) ofcondensate and crude oil per day. Condensate, LPG, crudeand some ethane are transported as a ‘cocktail’ via a pipelineto Port Bonython where they are separated and marketed.

The feedstock delivered to Port Bonython is firstsampled, filtered and metered to determine flow rates andcomposition. It is then pumped through a series offractionating towers to separate ethane (which is used as fuelgas for the plant), propane, butane, light naphtha,intermediate naphtha, heavy naphtha, and reduced crude.Once cooled to ambient temperatures, the naphtha andreduced crude fractions are pumped to the blending sectionwhere they are mixed in precise ratios. The resulting twoproducts, ‘naphtha’ and ‘crude oil’ are sent to storage tanksto await shipping.

One destination for Cooper–Eromanga crude oil andcondensate is the refinery at Port Stanvac, which suppliespetroleum products mainly for the South Australian market.The refinery commenced operations in 1963 and theadjacent lubricating oil refinery began operations in 1976.The refinery does not have sufficient capacity to produce allthe State’s requirements for motor spirit, and some must beimported from interstate. The main refinery products fromPort Stanvac are LPG, solvents, motor gasoline, jet fuel,kerosene, diesel, lube oil base stocks for Australian andoverseas markets, fuel oil and bitumen.

Mini-refinery technology has proven itself viable in theEromanga Basin at Eromanga in southwest Queensland,where the company, Inland Oil Refiners has been operatingsince 1985. The Eromanga mini refinery has a throughputcapacity of 1500 barrels of crude per day and receivesfeedstock from a number of Eromanga Basin oil fields,including the Inland oilfield, discovered by the company in1994. The principal product is diesel, which is truckedacross western Queensland to regional centres formarketing. Other products include automotive distillate, jetfuel, high quality kerosenes and specialised products forMount Isa Mines. Heavy residues are processed in Brisbane.

A mini-refinery located adjacent to the Port Bonythonliquids plant produces 95 kL/day (600 bbl/day) of gasolineby refining naptha feedstock from the liquids plant. Themini-refinery supplies the northern Spencer Gulf region.

Services in the Cooper Basin

The northern part of South Australia is sparselypopulated and relatively undeveloped due to its remotenessand harsh climate. The main primary industry in the regionis cattle which are run on large pastoral leases. Eco-tourism

is a growing industry in the region. The township ofInnamincka is located 65 km from Moomba and offers ahotel, general store and light aircraft airstrip. The Birdsvilleand Strzelecki Tracks are unsealed, but provide access forheavy vehicle transport in the region.

Accommodation and support facilities are located atMoomba, a fly in-fly out camp operated by the Cooper BasinJoint Venture. Access to these facilities is by arrangementwith Santos Ltd. The Moomba Camp can accommodate 450people, with an additional 150 beds mothballed. A full rangeof support services is available at Moomba includinglogging, wireline, fraccing, cementing, transport, fuelsupply, aviation and emergency services. The sealed airstripis 1720 m long and able to accept medium-sized jets.

Groundwater, extracted from the Great Artesian Basinaquifer system, is critical for petroleum operations in theregion. There are two major aquifers, the lower occurswithin the Algebuckina Sandstone and Cadna-owieFormation and provides hot (up to 100°C) good quality(TDS 1000 mg/l) artesian water. The upper aquifercomprises the Winton and Mackunda Formations andproduces poorer quality water but is shallower.

Markets

A free market was introduced in 1988 for all oil andcondensate produced in Australia. There is no restriction onimports or exports of crude oil or refined petroleumproducts. A similar regime has applied since 1991 for LPG.Markets for crude oil and condensate exist in SouthAustralia and Australia and low sulphur light crude oils finda ready domestic and overseas market.

Ex-field natural gas prices in SA are freely negotiatedbetween buyer and seller. As a consequence of a gas reformprocess in Australia, regulatory policy impediments to thefree trade in gas are being removed and the rights of accessto gas transmission and reticulation pipelines have beenprovided, and direct negotiations between consumers andproducers facilitated. The deliverability of a right of accessto upstream facilities is also currently being reviewed.

The Australian Gas Association study of futureAustralian gas supplies and demand forecasts that anAustralian gas grid would be economic early next century.South Australia, with Moomba as a potential hub, is ideallyplaced to be a supplier to this grid when it eventuates.

EXPLORATION ACCESS

National Parks and Reserves

A number of National Parks and Reserves have beencreated to conserve the best examples of vegetation andlandforms in the region (Fig. 9). There are three types ofSouth Australian reserves including Conservation Parks,National Parks and Regional Reserves. The conditions ofaccess vary from park to park, based upon the type of reserveclassification, the activity proposed and its likely impact onthe environment. Access for petroleum exploration andproduction is allowed in all parks in the Cooper Basin regionand in all regional reserves in the state. Access issues intothe Coongie Lakes Control Zone are currently under review.

15

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Innamincka and Strzelecki RegionalReserves

These Regional Reserves provide for the conservation ofwildlife 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 placeprovided that they are subject to controls consistent with themanagement plan for the reserve (much of the production inthe Cooper Basin is sourced from the Innamincka RegionalReserve).

Part of Block CO98-E lies within the InnaminckaRegional Reserve, and part of Blocks CO98- H, I, J and K liewithin the Strzelecki Regional Reserve (Fig. 9).

Mineral and petroleum exploration licence applicationsfor areas within Regional Reserves are processed by PIRSAbut are referred to the Minister for Environment, Heritageand Aboriginal Affairs (MEHAA) for comment.Exploration work programs are discussed with DEHAA(Department for Environment, Heritage and AboriginalAffairs) as a matter of policy. In the case of productiontenements, approval must be given by the MEHAA. FailingMinisterial agreement, the issue is referred to the Governorfor decision.

In all other respects exploration and production is carriedout under the provisions of the Petroleum Act andRegulations.

Parts of the Cooper Basin (Fig. 9) are listed as wetlandsof international significance under the Ramsar Convention(the 1971 Convention on Wetlands of InternationalImportance). The Coongie Lakes and part of the CoopersCreek system have also been included in the Register of theNational Estate (Fig. 9).

European heritage

A number of sites of European heritage significance suchas historic buildings and structures and geologicalmonuments occur in the region. These are indicated on theEnvironmental Sensitivity Maps available from PIRSA.The majority of the sites are small and easily avoided byexploration activities.

Aboriginal heritage

In South Australia it is an offence to disturb or destroyAboriginal sites, objects or remains. Standard procedures fordetermining the presence of Aboriginal heritage prior to thecommencement of activities have been determined. Theseprocedures involve consulting with the relevant Aboriginalorganisation and maintaining a watch for sites, objects orremains during activities. Generally the sites are no largerthan 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 heritagesites and exploration or production activities in SouthAustralia.

Commonwealth Native Title Act 1993

The Native Title Act 1993 was passed by FederalParliament on 22 December 1993. The lengthy and complexAct provides statutory recognition and protection for theconcept of native title as recognised by the High Court in the

case of Mabo v Queensland in 1992. Native title meansrights held by indigenous inhabitants of Australia at andsince the time of European settlement - it differs fromconventional titles. The nature of native title rights varyfrom group to group according to laws and customs,however there must be a sufficient and relevant connectionto the land in question, continuous since 1836 in SouthAustralia. Native title may include the right to camp ortravel across land, rights to hunt, fish, gather food and takematerials (timber, bark, ochre etc.) from the land.Applications by Aboriginal claimants are recorded in theRegister of Native Title Claims. The National Native TitleTribunal (NNTT) makes determinations on applicationsunder the Act. A National Native Title Register comprisinga record of all approved determinations made by the NNTT,Federal Court, High Court, other Courts or Tribunals andrecognised State/Territory arbitral bodies.

The Premier of South Australia declared in April 1994that SA would enact State legislation to ensure that Statelaws were consistent with the Commonwealth’s RacialDiscrimination Act and as far as appropriate, the NativeTitle Act, while retaining the option to challenge the NativeTitle Act in whole or in part to make it more workable andless complex. Late in 1994, a package of four Native TitleBills was introduced into the SA House of Assembly andwere all passed.

In 1995 a ‘safety net’ clause was introduced into thePetroleum Act which gives a licensee first right to anylicence which may be terminated due to no fault of thelicensee.

Licence holders are encouraged to develop a dialoguewith regard to Aboriginal Heritage and related matters, withAboriginal people having associations with their licencearea.

Following passage of the Commonwealth Native TitleAmendment Act, the South Australian Government isconsidering establishment of a legislative response. Anumber of options are available under the newCommonwealth legislation to develop alternate Stateprocedures to handle Native Title matters. A publicannouncement of the State’s response is likely later in 1998.

Current Native Title Applications in the Cooper Basinregion are shown on Figure 10.

Environmental regulation

Environmental issues pertinent to petroleum explorationare well managed in SA, primarily through properoperational planning in the initial stages. In order to ensurethat activities are undertaken in a manner which avoids orminimises environmental impacts, several documents arerequired before approval to commence operations is given.First a Declaration of Environmental Factors (DEF) isrequired from the licensee. This is the licensee’s assessmentof the environmental impact of the proposed activity. ACode of Environmental Practice is also required byregulation. The code describes procedures that theproponent will adopt during the planning, field managementand monitoring phases of the operation.

Santos Ltd. and their joint venture partners, who are themajor oil and gas producers within the Eromanga andCooper Basin, have developed Codes of Environmental

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

Practice for exploration and production. The codes provideguidance to licensees on environmental issues that need tobe taken into consideration in planning and undertakingexploration activities. These codes are currently beingrevised in a move towards an outcomes based approach.However in the interim they provide a standard acceptable tothe Government. A company may either adopt these Codesor use its own Codes of Environmental Practice subject toapproval by PIRSA.

PIRSA is able to assist licensees by providing examplesof the documentation and advising on their scope. To datethere have been no significant concerns raised with regard torequirements to minimise the environmental impacts of theiroperations.

The Codes are required to be reviewed regularly (at leastevery 3 years) to ensure techniques are up-to-date. Alldocumentation is subject to regulation. A revision of thePetroleum Act is currently under way and any futuredocumentation and operations will need to ensure the threeprime objectives of exploration which are:

1. undertake an appropriate planning andassessment process,

2. avoid or minimise short to medium termimpacts,

3. avoid all long term impacts.

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

APPENDIX 1 – BLOCK SUMMARIES

CO98-A

Area 4316 km2 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 60.82 61 ER01 4 22.93 62 ER02 44 184.84 63 CP01 13 132.95 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 Statusdrilled (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

Survey Line km

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

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

CO98-B



Nearest producing field Keleary oil field (110 km)

Seismic lines:


1 60 ER01 1 24.82 62 ER02 1 5.73 63 CP01 14 307.94 65 CP01 1 17.65 79 ER01 2 94.76 84 CP12 2 58.1

Total no. of lines 21 lines

Total line km of seismic 508.7 km

Previous drilling:


Putamurdie 1 1963 1,952.5 Cooper/ AbandonedEromanga -Oil

CO98-B seismic lines

Survey Line km

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

23

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

CO98-C



Nearest producing field Keleary oil field (73 km)

Seismic surveys:


1 57 ER01 5 36.62 58 ER02 1 65.93 60 ER01 3 60.64 66 ER01 1 25.95 79 ER01 3 139.16 81 CP05 12 223.07 83 CPXX1 1 0.08 84 CP12 4 34.49 85 CP11 35 640.810 85 CP21 9 109.811 85 CPXX1 2 2.012 85 CPXX2 4 3.913 85 CPXX3 3 4.014 86 CP11 4 50.115 86 CP21 18 326.416 86 CPXX1 2 2.917 87 CP21 15 191.718 87 CPXX1 1 1.219 88 CP01 24 211.420 88 CPXX1 4 8.821 95 CP01 10 121.122 96 CP01 9 76.4

Total no. of lines: 166 lines

Total line km of seismic: 2336.0 km

Previous drilling:


Haddon Downs 11986 2,011.9 Eromanga - Abandoned

OilPotiron 1 1988 2,171.7 Hutton - Oil AbandonedJames 1 1988 2,548.4 Hutton/ Suspended

Poolowanna - oilOil

Araburg 1 1989 2,394.5 Hutton/ AbandonedNappamerri -Oil

CO98-C seismic lines

Survey Line km

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

Survey Line km

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

Survey Line km

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

Survey Line km

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

26

CO98-D


Distance to Moomba 160

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

Seismic:


1 61 ER01 2 36.42 61 ER02 11 191.43 62 ER02 57 532.14 79 PE01 2 17.65 82 CP01 13 374.06 82 CP42 1 2.47 83 CP31 9 72.88 84 CP12 3 36.5



Previous drilling:


Pandieburra 1 1963 2,210.7 Palaeozoic AbandonedKoonchera 1 1984 2,088.5 Eromanga - Abandoned

Oil

CO98-D seismic lines

Survey Line km

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

Survey Line km

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

Survey Line km

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

CO98-E



Nearest producing field Keleary and Telopea PPLs lie inblock area

Seismic surveys:


1 58 ER02 1 8.32 63 CP01 3 21.53 66 ER01 4 83.64 67 CP01 3 46.75 69 CPXX1 1 0.06 70 CP01 4 48.27 70 CP08 2 24.28 73 CP01 2 23.59 78 CP01 7 185.110 79 CP01 5 50.011 80 CP02 22 263.012 80 PEXX2 1 0.813 81 CP04 23 208.914 83 CP31 9 61.315 84 CP12 9 118.616 84 CPXX5 3 6.717 85 CP11 8 73.418 85 CP21 7 60.519 85 CPXX1 1 1.020 87 CP21 3 2.821 88 CP01 10 37.222 88 CPXX1 1 3.723 89 CP01 3 18.824 91 CP11 20 131.025 92 CP01 2 5.326 94 CP01 10 58.127 94 CP10 5 29.728 94 CP21 6 22.829 95 CP01 6 44.430 95 CP05 2 8.031 96 CP01 39 539.932 96 CP02 47 237.033 97 CP01 20 221.1



Previous drilling:


Paning 1 1980 3,181.5 Cooper Oil & AbandonedGas

Kenny 1 1984 3,038.5 Eromanga - AbandonedOil

Walkillie 1 1984 2,748.6 Eromanga - AbandonedOil

Keleary 1 1991 2,634.3 Tinchoo - Oil ProducerKeleary 2 1994 2,533.5 Tinchoo - Oil ProducerTelopea 1 1994 2,747.2 Birkhead/ Producer

Hutton/Poolowanna -Oil

Caraway 1 1995 2,729.8 Birkhead/ AbandonedHutton/Tinchoo - Oil

Telopea 2 1995 2,727.9 Tinchoo - Oil ProducerReg Sprigg 1 1996 2,542.9 Basal Hutton/ Suspended

Birkhead/Poolowanna -Oil

Streeton 1 1997 2,852.9 Confidential Abandoned

CO98-E seismic lines

Survey Line km

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

Survey Line km

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

Survey Line km

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

32

Survey Line km

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

Survey Line km

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

Survey Line km

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 13.12 62 ER02 3 55.83 63 CP01 1 2.94 64 CP01 1 18.45 65 CP01 2 88.96 66 ER01 8 109.47 67 CP01 3 28.48 69 CP04 15 132.59 76 CP01 1 8.610 77 CP01 4 37.711 81 CP04 5 30.013 82 CP02 3 71.914 82 CP42 5 38.515 83 CP31 2 14.116 84 CP12 25 489.917 85 CP11 9 80.718 87 CP11 5 39.719 87 CP21 2 2.220 88 CP01 18 102.021 89 CP01 3 4.122 91 CP11 2 3.523 92 CP01 13 186.924 95 CP01 11 88.825 97 CP01 1 2.1



Previous drilling:


Kalladeina 1 1967 3,761.5 Cambrian AbandonedHoolendinnie 1 1998 1,850.1 Confidential Abandoned

CO98-F seismic lines

Survey Line km

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

Survey Line km

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

Survey Line km

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

Survey Line km

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

Survey Line km

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

Survey Line km

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

38

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

CO98-G



Nearest producing field Sturt-Taloola-Tantanna oil fields(37 km), Jack Lake gas field (47 km)

Seismic surveys:


1 61 ER01 3 18.52 63 CP01 1 32.03 64 CP01 5 95.74 65 CP01 3 38.65 66 ER01 5 49.56 67 CP01 2 56.87 69 CP04 7 76.88 69 ER01 1 7.59 70 CP09 9 44.710 76 CP01 2 10.911 77 CP01 2 12.712 82 CP02 4 64.113 84 CP12 15 113.814 84 CP32 4 33.615 85 CP11 36 878.816 85 CP21 2 4.217 85 CP51 2 3.618 86 CP11 2 2.919 86 CP21 9 145.920 87 CP11 6 43.621 87 CP21 6 48.922 88 CP01 22 258.423 89 CP01 29 204.624 90 CP08 7 36.725 91 CP11 7 46.526 95 CP01 6 36.0



Previous drilling


Lhotsky 1 1988 1,931.2 Eromanga - AbandonedOil

Lycium 1 1989 2,250.0 Poolowanna - Water wellOil

Kuenpinnie 1 1991 2,607.3 Upper AbandonedPatchawarra -Gas

CO98-G seismic lines

Survey Line km

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

Survey Line km

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

Survey Line km

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

Survey Line km

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

40

Survey Line km

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

CO98-H



Nearest producing field Daralingie gas field (28 km),Sturt-Taloola-Tantanna oilfields (35 km)

Seismic surveys:


1 63 CP01 1 11.32 64 CP01 11 204.13 65 CP01 3 31.44 67 CP01 5 45.95 68 CP01 7 43.26 69 CP02 1 9.17 70 CP09 4 30.18 76 CP01 3 38.39 77 CP01 1 4.310 78 CP01 1 9.511 79 CP01 1 2.112 82 CP02 23 249.413 82 CP42 2 7.414 84 CP32 14 133.015 85 CP11 15 75.216 85 CP21 14 399.417 86 CP31 22 139.218 87 CP11 14 123.619 88 CP01 23 246.720 89 CP01 3 10.221 90 CP08 5 27.022 91 CP03 4 11.623 91 CP11 11 65.824 92 CP01 2 18.325 94 CP21 4 38.826 95 CP01 7 39.8



Previous drilling:


Pando 1 1966 1,933.3 Cooper - Gas AbandonedPando 2 1969 1,895.5 Cooper - Abandoned

Oil & GasPando North 1 1970 1,969.0 Cooper - Abandoned

Oil/GasPintari 1 1987 1,792.8 Eromanga - Abandoned

OilPando South 1 1992 1,848.6 Birkhead/ Abandoned

Hutton - OilJaspa 1 1996 1,772.4 Namur - Oil AbandonedBarra 1 1996 2,106.7 Patchawarra - Abandoned

Gas

CO98-H seismic lines

Survey Line km

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

Survey Line km

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

Survey Line km

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

Survey Line km

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

44

Survey Line km

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

CO98-I



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

Seismic surveys


1 62 ER01 8 34.32 63 ER01 2 8.13 64 CP01 3 47.14 65 CP01 9 163.75 65 CP02 1 27.26 66 ER01 1 18.57 67 CP01 7 45.88 69 CP01 2 1.19 69 CP02 15 190.010 70 CP05 8 74.511 79 CP01 4 47.512 82 CP02 8 90.213 82 CP42 6 66.314 83 CP21 13 66.715 84 CP32 8 160.416 85 CP11 2 4.717 85 CP21 25 161.318 87 CP11 4 3.419 89 CP01 6 17.920 93 CP01 6 28.421 94 CP21 9 49.522 95 CP01 6 131.723 96 CP01 13 250.4



Previous drilling:


Pampari 1 1996 1,531.6 Namur - Oil Abandoned

CO98-I seismic lines

Survey Line km

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

Survey Line km

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

Survey Line km

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

Survey Line km

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

48

CO98-J



Nearest producing field Limestone Creek-Biala oilfields (34 km)

Seismic surveys:


1 62 ER01 7 39.22 63 ER01 5 148.83 64 CP01 1 13.04 65 CP01 10 127.25 67 CP01 8 93.26 68 CP01 10 78.17 69 CP01 28 356.88 69 CP02 12 116.09 70 CP05 3 11.010 75 CP01 4 12.111 76 CP01 9 119.412 79 CP01 4 14.813 81 CP06 8 43.314 82 CP02 18 205.315 82 CP05 5 12.716 82 CP42 3 16.617 83 CP21 30 158.218 83 CP22 12 63.219 83 CPXX1 1 2.120 84 CP32 11 217.321 85 CP21 38 470.722 85 CP41 14 115.523 86 CP21 6 48.424 87 CP21 4 31.225 88 CP01 5 21.726 89 CP01 7 5.527 91 CP11 1 0.528 92 CP01 9 62.929 93 CP01 13 52.830 94 CP01 10 19.931 94 CP21 12 74.432 95 CP01 10 128.933 96 CP01 17 138.4



Previous drilling


Kobarie 1 1970 1,686.7 Cooper - gas AbandonedTilparee 1A 1971 2,148.5 Cooper - gas AbandonedKumbarie 1 1984 1,773.9 Eromanga - Abandoned

oil & gasMulga 2 1985 1,905.0 Eromanga - Abandoned

oilWuroopie 1 1987 2,045.2 Cooper - gas Abandoned

CO98-J seismic lines

Survey Line km

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

Survey Line km

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

49

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

Survey Line km

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

Survey Line km

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

Survey Line km

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

Survey Line km

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

52

Survey Line km

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

Survey Line km

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

54

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��

��

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��

��

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$�%�& ��

'��

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

CO98-K



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

Seismic surveys:


1 62 ER01 9 90.82 63 ER01 4 16.23 64 CP01 2 10.04 65 CP01 5 92.65 65 CP02 6 120.96 66 ER01 3 35.87 67 CP01 6 65.88 69 CP01 9 123.59 69 CP02 21 309.710 70 CP05 9 99.311 82 CP02 13 190.412 83 CP21 1 0.913 84 CP32 10 192.814 84 CP42 1 28.815 85 CP21 25 241.5



Previous drilling:


Tinga 1968 2,301.8 Cooper - gas AbandonedTingana 1

Weena 1 1970 1,644.0 Cooper - gas AbandonedGurra 1 1970 1,428.2 Cooper - gas AbandonedCherri 1 1970 1,400.8 Cooper oil/ Abandoned

gas

CO98-K seismic lines

Survey Line km

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

Survey Line km

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

Survey Line km

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 Explorationand Production System—South Australia), a comprehensiverelational database containing a range of technical datarelevant to the petroleum industry. PEPS-SA is beingcontinually developed and is available for purchase. Thekey data element is the petroleum well, of which there are~1600 in SA. For each well there may be thousands ofattributes. There are eight key modules comprising 99 datasets (see below).

Data are supplied with a PEPS-SA menu-drivenwindows system. For clients without Paradox, a copy ofParadox Runtime and software to query and export the dataare provided.

PEPS-SA® (Spatial)

Bundled with the attribute data are Mapinfo spatialdatasets. Viewing this data in a mapping package allows thegeoscientist to turn on and off various layers of interest,zoom in and out etc, to allow the generation of a custom builtbase map which can be printed.

There are more than 60 separate layers, ranging fromgeneral topographic data such as state boundaries, coastline,national parks and restricted areas, road, railways andvarious tenements, through to geologic layers such as basinoutlines, well locations, seismic lines, seismic horizons,tectonic provinces, and many more.

The PEPS-SA attribute and spatial data are bundledtogether as one package on CD-ROM which costs $3000.Update of PEPS-SA twice a year costs an additional $300per year.

Contact Alan Sansome Ph: (08) 8463 3221,Fax: (08) 8463 3229,

e-mail: [email protected]

Core Photos

The department has recently scanned all petroleum corephotographs and the thumbnail images are present in thedata package if you receive the CD-ROM version. Full sizeimages are approximately 1500 pixels by 1000 pixels by 256colours. The total set contains over 1900 images andoccupies 1.4 Gigabytes. These are available for purchase($250) on CD-ROM (3 disks) together with viewingsoftware. The software links the photo to the attribute data.



Well Logs (Petlog)

The digital open hole well log database includes fieldand edit tapes, and higher resolution data includingdipmeter, FMS (Formation Microscanner), array sonic andVSP (Vertical Seismic Profile). These data are nowavailable in a variety of formats and media includingCD-ROM.

Data are available as:

• basic validated data as originally supplied in digitalformat, EDIT or FIELD processing

• fully verified and merged digital data, or datadigitised from analogue source.

PIRSA will provide quotes on application for well logs.



Seismic Shotpoint Database

This is a comprehensive digital data set of shotpointlocations and associated attribute data from ~611 surveyscarried out in the State and adjacent waters to 40°S latitudebetween 1955 and 1997. These data are maintained in

57

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

Production CO2; crude oil; crude oil production summary; crude oil test data; crude unit oil; enhanced oil recovery gas injectionvolumes; gas field reservoir data; Katnook gas production; oil field reservoir data; raw gas deliverability; raw gasproduction 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); waterratio (gas); water ratio history (gas); average gas rates (gas); gas rate history (gas); completion days (gas, oil); oil cutdecline (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.

ArcInfo where complex GIS analysis and modelling can beperformed with other digital data sets. The index to thesedata and summary information are also available in PEPS.

Digital data are available for purchase in various formatson exabyte tape or diskette. Hard copy maps can be preparedfor any area at any scale.

Contact Dave Cockshell Ph: (08) 8463 3233,Fax: (08) 8463 3229,


Seismic Mapping

A program commenced in 1989 to consolidate open filebasic and interpreted data into coherent data sets. The aimwas to prepare regional interpretations of basin structure toattract explorers into prospective basins with vacant acreage.This program is nearing completion for the major onshoreand large areas of the offshore basins.

Cooper Basin Folio

This folio is the culmination of an extensive seismicmapping and interpretation of the Cooper and EromangaBasins in SA. Whilst this folio is restricted to the immediatearea of PELs 5 and 6, regional datasets covering theEromanga and Cooper Basins in SA, Queensland, NSW andthe NT have been prepared as part of the NationalGeoscience Mapping Accord.

• Volume 1 of the Cooper Basin Folio contains keyseismic depth structure maps, formation isopachsand structural elements.

• Volume 2 contains geological datasets includinglithofacies maps and maturity maps of key sourceintervals (depths to oil and gas windows).

All data are available in digital format and aresupplemented by individual technical reports available fromPIRSA. Each volume of the folio costs $1999, includingpostage and packing. In addition, individual hard copy mapscan be purchased from $100 each, however discounts areavailable if map sets are purchased.

Stack Seismic Data

Archive processed data in SEG-y format are available for4474 seismic lines from the existing PEL 5 and 6 area. Inmost 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 12Exabyte Tapes. All data has had SP/CDP relationshipsembedded in the EBCIDIC header, and supporting attributedata relating to the line and data files. Approximately 10 %of all the data has been verified as correct and readable in theGeoquest IESX.

Contact Dave Cockshell Ph: (08) 8463 3233,Fax: (08) 8463 3229,


Core Library

Confidential and open file drillhole samples obtainedfrom company and departmental petroleum, stratigraphic

and mineral exploration are stored at the PIRSA CoreLibrary. Over 3 million metres of core and cuttings from24 000 drillholes are currently stored. The Core Library islocated at 23 Conyngham St, Glenside. Viewing facilitiesare fully enclosed. All open file samples are available forinspection and sampling is permitted. Forty-eight hoursnotice is required.

Contact Brian Logan Ph: (08) 8379 9574,Fax: (08) 8338 1925,

e-mail [email protected]

Petroleum Tenements

An A4 size petroleum tenement map, including a listingof tenement, holder(s) and interests, expiry date and area, isprepared quarterly and is free on request.

Contact Mario Collela Ph: (08) 8463 3209,Fax: (08) 8463 3229,


All tenements granted, surrendered or cancelled arepublished in the South Australian Government Gazetteissued weekly from the State Information Centre, 25Grenfell St, Adelaide. These notices are also widelypublicised in the business, investment and resources sectorsof the local and international press, as well as by circulationto listed exploration companies, stockbrokers, etc.

Aeromagnetic Database

A digital database of aeromagnetic survey boundarieshas been compiled and gives the location of all airbornesurveys over South Australia and adjacent waters.

Contact: Dominic Calandro Ph: (08) 8463 3051,Fax: (08) 8463 3040,


Digital Geological Maps Of South Australia

SA_DISPLAY — An integrated set of State-widegeological, geophysical, geochemical and groundwaterdatabases brought together in GIS where they can bedigitally overlain and interrogated. Available in ArcViewand MapInfo formats.

SA_GEOLOGY — A library of digital geological mapsthat provides detailed, up to date GIS coverages of theState’s geology. Available in ASCII, ArcInfo, DXF,ArcView and MapInfo formats.

Contact Stephen Bell Ph: (08) 8463 3288,Fax: (08) 8463 3268,


Miscellaneous Data

PIRSA holds the largest collection of South Australiangeoscientific literature, mining and exploration data, datingfrom the 1850s. The data comprises open file companyexploration reports (including well completion reports),PIRSA open file report books, geophysical data includingseismic sections, government publications, geoscientificmaps, plans, publications and more.

Contact Peter Dunne Ph: (08) 8463 3003,Fax: (08) 8204 1880


58

Document Storage Centre

The PIRSA Document Storage Centre is responsible forstoring and copying all unpublished material. Copies maybe ordered in paper, microfiche and transparency media.The centre strives to complete standard orders within twodays.



Web Site

To be kept on a more up to date basis on what ishappening in South Australia, why not visit our web site atwww.mines.sa.gov.au/petrol

59

Document Storage Centre

The PIRSA Document Storage Centre is responsible forstoring and copying all unpublished material. Copies maybe ordered in paper, microfiche and transparency media.The centre strives to complete standard orders within twodays.



Web Site

To be kept on a more up to date basis on what ishappening in South Australia, why not visit our web site atwww.mines.sa.gov.au/petrol

APPENDIX 3 – LICENCE APPLICATIONFORM AND PROCEDURES

Review of Petroleum Act

A Green paper on a review of the Petroleum Act 1940was released in 1997 and comments from industry and otherinterested parties received. Comments have beenconsidered and Legislation is currently being drafted. It isanticipated that the draft Bill will be ready for Industry andother interest groups comments in October 1998.

Key elements to changes in the Petroleum Act includeimplementation of objective regulation, with the willingassistance of industry; changes to the issue of tenements

A draft Bill for a new South Australian Petroleum Acthas very recently been made available for comment. Thisfollows analysis of submissions following release of aDiscussion Paper in 1996 and a Green paper last year. Thelegislation governing onshore petroleum exploration andproduction in south Australia had not undergone a majorreview since the Petroleum Act was proclaimed in 1940,although a number of amendments have been made fromtime to time. This legislation has served as an effective basisfor regulation of the upstream petroleum industry. It hasbecome evident, however, that the existing prescriptiveregime is becoming less effective as advances are made inregulatory practice and community aspirations. The mainthrust of the proposed legislation is to provide a modern,pro-competitive, efficient and flexible basis foradministration of petroleum exploration and development.The objective is to establish a business environment thatmaximises investment opportunities for the explorationindustry in the State and facilitates the development ofdiscoveries. The main features of the Bill are:

• establishment of a co-regulatory regime focussingon achievement of environmental, public safety andresource management objectives and reducedcompliance costs (this is strongly supported by bothindustry and community interest groups);

• licence allocation and management mechanisms tofacilitate competition in line with competition policyprinciples;

• rights of third party access to licensed pipelines(where not covered by the national access regime), todepleted reservoirs (for gas storage purposes); and topipeline easements;

• greater security of tenure for licences thoughimproved registration procedures;

• public consultation processes with regard toestablishment of environmental objectives and forsignificant proposed activities (consistent withprovisions of the Development Act);

• reduced risk to Government for liabilities arisingfrom the industry’s activities;

• increased royalties from 2001 and a fee structuredesigned to encourage the adoption by industry ofmanagement systems to undertake their activities;and

• the ‘grandfathering’ of existing PetroleumExploration and Production Licence rights, with newexploration licences having rights to Retention

Licences but stricter criteria for ProductionLicences.

The Occupational Health and Safety (OH&S) provisionof the Petroleum Regulations have been repealed andsubstituted by regulation under the OH&S Act.

Application

Although there is no form set by regulation, anapplication for a Petroleum Exploration Licence (PEL) maybe lodged in accordance with the attached pro forma, andshould be accompanied by two copies of a plan of theapplication 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 overany area of the State not currently under a PEL or aPetroleum Production Licence (PPL) unless applications forthe area have been specifically invited and a closing datenominated for receipt of applications.

An application can be made by an individual(s) or acompany(s) or a combination of an individual(s) or acompany(s). When a foreign company makes anapplication, the foreign company must be registered as aforeign company under the provisions of the AustralianCorporations Law. Information on registrat ionrequirements can be supplied on request.

Technical Qualifications/Experience

The applicant must submit with the application asummary of the technical qualifications of the applicant (orconsultants/agents of the applicant) to satisfy requirementsthat the applicant is capable of satisfying compliance withthe Petroleum Act and the terms and conditions of thelicence.

Financial Position

Evidence of the financial position of the applicant is to besupplied to demonstrate ability to fulfil the proposed workprogram. Such evidence can be in the form of the latestannual report or a verifiable statement from an independentaccountant/auditor/ financial institution. If financialresources are not available for the full five year program, theapplicant will have to provide evidence that there arefinancial resources available for at least the first licence yearprogram prior to the grant of the licence.

Work Program

The applicant must submit with the application astatement of exploratory operations the applicant proposesto carry out in each year of the five year term of the licence,including an estimate of exploration expenditure to beincurred in each year of the licence.

A minimum exploratory expenditure for each of the firsttwo years of the licence is $16 /km² per year, and $24 /km²for each of the remaining three years.

Award Criteria

The basic objective in awarding a Petroleum ExplorationLicence is to select the work program most likely to achievethe fullest assessment of the petroleum potential within thelicence over the initial five year licence term recognising theessential role of wells in the discovery of petroleum. Work

60

program bids will be assessed taking account of the criterialisted below.

The criteria for assessment of work programs, notnecessarily in order of priority are:

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

• The amount and nature of seismic surveying to becarried out and its timing;

• The number of years that an applicant is willing toguarantee the work program;

• Other data acquisition and reprocessing to be carriedout;

• The extent to which the proposed work programreflects the information available from previousexploration;

• The adequacy of financial resources and technicalexpertise available to the applicant.

In addition to the above criteria, where work programbids are very similar, the benefits of the introduction of newexplorers into the area may be taken into account.

It should be noted that there are no criteria limiting thenumber of PELs which may be offered to one applicant(although in considering Competition Policy Principles itwould require major work program benefits to offer morethan three PELs to the one applicant in the first round ofbidding). There will be no consideration taken of thesuccess of applicants in the various bidding rounds inselecting successful applicants.

Once a licence has been granted, a licensee is obliged tocarry out the work program stipulated in the year the licenceis in. Any failure to fulfil the work program for that yearmay, if a genuine ‘force majeure’ case is not proved, mayresult in cancellation of the licence. Variation of licenceconditions are possible, however this would only generallybe done where extraordinary cause exists, especially for alicence issued for which there were competing bids.

Santos exploration drilling update

Santos have amended their drilling program and a wellmay be drilled north of James 1 in Block CO98-C. Shouldthis well, or any others proposed in Blocks CO98-A to Kdiscover hydrocarbons before expiry of PELs 5&6, the PPLarea will be excised from the relevant Block. However,basic data associated with wells will be available on expiryof PELs 5&6 on 1 March 1999.

61

62

PEL APPLICATION CHECKLIST

The following information must be included in thelicence application:

1. Complete the attached PRO FORMA andinclude two copies of a plan of the applicationarea.

2. PRO FORMA application must be signed byindividual applicants and if the application ismade by a consortium including a company(s)the application must be made under thecompany(s) seal.

3. If applicant is a foreign company, the companymust be registered as a foreign company underthe provisions of the Australian CorporationsLaw.

4. A summary of the technical qualifications ofthe applicant (or consultants/agents of theapplicant).

5. Evidence of the financial position of theapplicant to demonstrate ability to fulfil theproposed work program (i.e. the latest annualreport or a verifiable statement from anindependent accountant/auditor/ financialinstitution).

6. A statement of exploratory operations theapplicant proposes to carry out in each year of thefive year term of the licence, including anestimate of exploration expenditure to beincurred in each year of the licence.

7. The prescribed fee of A$2240 for each licenceapplied for, made payable to Primary Industriesand Resources SA.

APPLICATION FOR PETROLEUM EXPLORATION LICENCEPETROLEUM 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 areakm2 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.

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COOPER–EROMANGA BASIN - Petroleum · The first Cooper Basin oil was discovered in Tirrawarra 1 in...

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Transcript of COOPER–EROMANGA BASIN - Petroleum · The first Cooper Basin oil was discovered in Tirrawarra 1 in...