COOPER–EROMANGA BASINS SOUTH Petroleum Exploration Data Package 3

EXPLORATION OPPORTUNITIES BLOCKS CO2000A–H January 2000

Acreage release

Acreage release

Government of EXPLORATION OPPORTUNITY – THIRD ROUND BLOCKS CO2000-A to H

Compiled by Tony Hill Petroleum Group

JANUARY 2000

Petroleum Exploration Data Package 3

© Department of Primary Industries and Resources South Australia, 2000 This report is subject to copyright. Apart from fair dealing for the purposes of study, research, criticism or review as permitted under the Copyright Act, no part may be reproduced without written permission of the Chief Executive Primary Industries and Resources South Australia. CONTENTS EXECUTIVE SUMMARY ...... 4 EXPLORATION HISTORY ...... 6 COOPER BASIN ACREAGE RELEASE STRATEGY ...... 6 GEOLOGICAL SUMMARY Eromanga Basin ...... 7 Cooper Basin ...... 9 Warburton Basin ...... 9 PETROLEUM GEOLOGY Reservoirs ...... 11 Source rocks...... 14 Seals and plays ...... 14 UNDISCOVERED POTENTIAL Introduction ...... 16 Cooper Basin gas ...... 16 Cooper-Eromanga Basin oil...... 16 Results...... 16 INFRASTRUCTURE AND MARKETS Production facilities ...... 16 Other facilities in the Cooper Basin...... 18 Oil and gas markets ...... 18 REGULATORY REGIME Review of Petroleum Act ...... 18 EXPLORATION ACCESS Access to land ...... 19 National Parks and Reserves ...... 19 Innamincka and Strzelecki Regional Reserves ...... 19 European Heritage ...... 19 Aboriginal Heritage ...... 19 Commonwealth Native Title Act 1993 ...... 19 Environmental regulation ...... 21

APPENDICES 1. CO2000 block maps, seismic surveys, and selected well information ...... 23 2. Data and order forms ...... 41 3. Licence application form and procedures...... 47

FIGURES 1. Cooper Basin location map...... 5 2. Eromanga Basin stratigraphy...... 7 3. Base Cretaceous, ‘C’ seismic horizon map ...... 8 4. Cooper Basin stratigraphy ...... 9 5. Top Permian, ‘P’ seismic horizon map ...... 10 6. Warburton Basin stratigraphy...... 11 7. Top Warburton Basin unconformity, ‘Z’ seismic horizon map...... 12 8. Patchawarra Formation coal isopach map ...... 15 9. Base Patchawarra Formation maturity map...... 15 10. Hydrocarbon plays schematic...... 16 11. Comparison of Australian and US gas prices ...... 18 12. Gas supply and demand, Eastern Australia (Australian Gas Association report)...... 18 13. Regional Reserves and environmental zones, Cooper Basin region ...... 20 14. Native Title Claims, Cooper Basin region ...... 22 15. Seismic line and well locations; ‘C’ Horizon Block CO2000 – A ...... 24 16. Seismic line and well locations, ‘C’ Horizon Block CO2000 – B ...... 26 17. Seismic line and well locations, ‘P’ Horizon Block CO2000 – C ...... 28 18. Seismic line and well locations, ‘C’ Horizon Block CO2000 – D ...... 30 19. Seismic line and well locations, ‘C’ Horizon Block CO2000 – E ...... 32 20. Seismic line and well locations, ‘C’ Horizon Block CO2000 – F ...... 34 21. Seismic line and well locations, ‘P’ Horizon Block CO2000 – G ...... 36 22. Seismic line and well locations, ‘P’ Horizon Block CO2000 – H ...... 38

TABLES 1. Third round acreage release blocks, and open file data summary Cooper Basin, 2000 ...... 4 2. Cooper Basin acreage releases, 1998 – 2000...... 7 3. Cumulative production to 31/7/99 for selected fields adjacent to CO2000 blocks...... 13 4. SA Cooper Basin reserve summary, 1/1/99 (source Santos Ltd)...... 16 5. Undiscovered recoverable Cooper Basin gas potential, billion cubic metres (tcf) ...... 17 6. Undiscovered recoverable Cooper Basin oil potential, million cubic metres (mmstb)...... 17 7. Cooper Basin pipeline licences, February 1999 ...... 17 8. PEPS-SA® modules and contents ...... 41 COOPER BASIN EXPLORATION OPPORTUNITY THIRD ROUND BLOCKS CO2000-A to H

Compiled by A.J. Hill (PIRSA) with contributions from J.G.G. Morton * - undiscovered potential, C. Boreham (AGSO) – source rocks, E.M. Alexander * and D.I. Gravestock * – seals and traps, B. O’Neil – history, Alan Sansome * and Dragan Ivic * – data. PIRSA staff indicated by *. Executive Summary The South Australian part of the Cooper Basin had been under licence continuously since 1954, however on 27 February 1999 Petroleum Exploration Licences (PELs) 5&6 expired. The former PEL 5&6 area is being released in four bidding rounds over 1998–2000, with a planned total of 27 blocks on offer for the first three rounds. The first round commenced in October 1998 when eleven blocks flanking the Cooper Basin (CO98-A to K) were released. Applications for those blocks closed on 11 March 1999 and a total of 41 bids were received from 15 consortia. This keen bidding resulted in 11 exploration licences being offered to 6 consortia who will invest a total of $45 million during the next 5 years. The second round of eight core Cooper Basin blocks (CO99-A to H) in the Patchawarra Trough was released in April 1999 (Fig. 1). Applications for these blocks closed on 25 November 1999 and a total of 47 bids were received from 16 consortia. This has resulted in 8 exploration licences being offered to 7 consortia who will invest a total of $120 million during the next 5 years. The current release of eight Cooper Basin blocks (CO2000-A to H) comprising four outer blocks in the Patchawarra Trough, one outer block to the west of the Wooloo Trough and three inner blocks adjacent to producing oil and gas fields, forms the third round acreage release (Fig. 1). The total area on offer is approximately 12 735 km2 or 3 147 000 acres (Table 1). A six month evaluation period applies for blocks CO2000-A to E blocks with applications closing at 4.00 pm on Thursday 29 June 2000 whilst a nine month evaluation period applies for blocks CO2000-F to H with applications closing at 4.00 pm on Thursday 28 September 2000.

Table 1. Third round acreage release blocks, and open file data summary Cooper Basin, 2000.

Block Block area Year last drilled No. wells 2D seismic 3D seismic km2 acres km km2

CO2000-A 2051 506 811 – 375.5 CO2000-B 1508 372 633 – 116.7 CO2000-C 1452 358 796 1997 2 1198.6 CO2000-D 1185 292 819 1991 3 1775.4 CO2000-E 3314 818 904 – 487.9 CO2000-F 1163 287 382 1999 16 3137.0 39 CO2000-G 956 236 232 1997 18 2802.3 7 CO2000-H 1106 273 297 1998 24 3671.1

Applications may be made for any or all of the eight areas, CO2000-A to H. Licences are offered on the basis of the most competitive work program. In the event that more than one area is offered to an applicant for licence, there is no obligation for the applicant to accept any or all of the offers. It should be noted that there are no criteria limiting the number of PELs which may be offered to one applicant (although in considering Competition Policy Principles it would require major work program benefits to offer more than two PELs to the one applicant in the third round of bidding). In addition, applications for this third release of acreage will in no way prejudice successful applications in the final Cooper Basin acreage release. Areas constituting unsuccessful Petroleum Production Licence Applications made by the operators of former PELs 5&6 will not be included in the surrounding CO98, CO99 or CO2000 blocks. Subject to resolution of PPLA issues, if any such areas become available, they would be included in a final bidding round, post September 2000. A decision on blocks to be released in the Coongie Lakes area will not be made until after a consultative process has been completed on issues relating to access to this environmentally important area. Comments, enquiries and applications for Petroleum Exploration Licences may be addressed to: Director, Petroleum Group Level 7 Telephone: IAC 61 8 8463 3204 101 Grenfell St Facsimile: IAC 61 8 8463 3229 Adelaide SA 5000 Website: www.petroleum.pir.sa.gov.au AUSTRALIA General enquiries: Email: [email protected] Applications should be accompanied by a proposed five year work program, a map of the area applied for, the appropriate application fee (A$2298 at the time of writing, but scheduled to increase on 1 July each year) and details of the technical and financial resources of the applicant (an application form and summary guidelines are included in appendix 3). The envelope containing your application(s) must be marked ‘CONFIDENTIAL – PEL APPLICATION’. It is anticipated that successful bids for areas CO2000-A to E and CO2000-F to H will be announced in July 2000 and November 2000 respectively. The closing date for CO2000-A to E applications is 4.00pm on Thursday 29 June 2000. The closing date for CO2000-F to H applications is 4.00pm on Thursday 28 September 2000.

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Fig. 1. Cooper Basin location map.

5 EXPLORATION HISTORY Export shipments of crude oil and condensate commenced in 1983 and LPG handling facilities were The Cooper Basin is Australia’s largest onshore oil and commissioned in July 1984. The establishment of these gas province (Fig. 1), located 800 km north of Adelaide in a facilities enabled the Cooper Basin Producers to bring the remote, sparsely populated desert environment. The first wet gas reservoirs into production, which further enhanced petroleum exploration licence over the basin was issued in production flexibility. In 1991 condensate production from 1945 – OEL 1 issued to Zinc Corp. Ltd, covered the area Port Bonython was replaced by a full range naphtha, which from Lake Frome to the southern Cooper Basin. OELs 2 and has a greater market value. 3, covering the now productive parts of the Cooper and Eromanga Basins were issued in 1947 and transferred to Santos became exploration and production operator for Frome-Broken Hill Co. Pty Ltd. Petroleum exploration PELs 5 and 6 in 1987. In 1991 a contract was signed for the commenced in 1954 with the granting of OEL 7 to sale of natural gas by the SW Producers to SA. R. Bristowe on behalf of Santos. Santos then held a total of The gas is delivered to the SA market via a 190 km pipeline 860 000 km2 in SA and Qld. constructed by the Producers to link the Queensland gas fields with the Moomba processing facility and the Initial exploration included reconnaissance gravity and Moomba–Adelaide natural gas pipeline. An agreement magnetic surveys between Birdsville and Marree and was finalised between Santos on behalf of the Cooper structural/stratigraphic bores in the northern Cooper Basin Basin Producers and ICI in 1994 to supply ethane from undertaken by Geosurveys for Santos. In 1959 Delhi-Taylor Moomba to a petrochemical plant in Botany Bay. A Oil Corporation joined Santos as a partner and was pipeline was constructed and supply commenced in June exploration operator until 1987. Early exploration targeted 1996. Early Palaeozoic carbonates and clastics and in 1959 Innamincka 1, the first oil and gas exploration well was In 1995 the SA Government confirmed that no rights of drilled. Additional reflection surveys over the ensuing years renewal would be applied to PELs 5&6 on expiry, which led to the discovery of gas in the Permian section in occurred on 27 February 1999. The former exploration Gidgealpa 2 in 1963 and three years later the ‘giant’ licence area has been divided into smaller blocks which are Moomba gas field was discovered. One-third of SA’s being progressively released for licence applications. Cooper Basin gas reserves are in the Moomba and Big Lake fields. COOPER BASIN ACREAGE RELEASE The decision to generate the bulk of SA’s electricity STRATEGY from natural gas ensured the economic viability of Cooper Basin acreage is being released for work constructing and operating the Moomba–Adelaide pipeline, program bidding in four rounds over the period 1998 to and gas was first supplied to Adelaide in 1969. PELs 5 and 6 2000. were issued to Delhi and Santos in 1969 to replace OELs 20 and 21, and the first PPLs were granted. Further gas PIRSA has divided the former PELs 5&6 into flank and discoveries were made in 1970 at Packsaddle, Tirrawarra, core areas. Flank blocks lie beyond the margin of the Della, Merrimelia, Mudrangie and Strzelecki, some of Cooper Basin and because most have only regional seismic which were made by farm in companies such as Crusader data and a few wells, a six month evaluation period applies. and Pursuit Oil NL. PELs granted for flank blocks have two renewals (i.e. a total of three five year terms) because of the frontier nature of the In 1971 Santos was appointed operator of the gas acreage. production facilities and camp at Moomba by the joint venturers. Also during 1971 an agreement was signed by the Core blocks are those close to production and have large Cooper Basin Producers to supply gas for the NSW market volumes of seismic and well data available – a nine month from 1976 to 2006 and construction of a pipeline linking evaluation period applies. PELs granted for core blocks will Moomba and Sydney commenced. In 1975 the Cooper have one renewal (i.e. two five years terms). Basin Ratification Act (and Indenture) came into effect. Gas Round one (CO98-A to K blocks) closed on 11 March was first supplied to AGL in Sydney in 1976. Santos 1999. A total of 41 bids from 15 consortia were received and became the sole operator for development drilling, all eleven outer blocks are now under application by 6 production and processing in 1979. consortia. Award of tenements will follow resolution of The first Cooper Basin oil was discovered in native title issues now being addressed in a formal Tirrawarra 1 in 1970. The Tirrawarra field contains 80 per negotiation process. cent of known oil reserves in the SA region. Eromanga The second round of eight core Cooper Basin blocks Basin oil was discovered in 1977 with an uneconomic flow (CO99-A to H) in the Patchawarra Trough was released in from Poolowanna 1 (Poolowanna Trough) and the first April 1999 (Fig. 1). Applications for these blocks closed on economic oil flow was recorded from Strzelecki 3 in the 25 November 1999 and a total of 47 bids were received from following year. In order to market newly discovered oil and 16 consortia. This has resulted in all 8 exploration licences existing gas liquids, the Cooper Basin Liquids Project was being offered to 7 consortia who will invest a total of $120 initiated in 1980 and completed in stages from 1982 to 1984 million during the next 5 years. at a cost of $1.4 billion. The project involved the The current release of eight Cooper Basin blocks construction of a high vapour pressure liquids pipeline from (CO2000-A to H) comprises four outer blocks in the Moomba to a processing plant and storage and loading Patchawarra Trough, one outer block to the west of the facilities at Port Bonython, as well as field development, oil Wooloo Trough and three inner blocks adjacent to collection and crude stabilisation facilities at Moomba. producing oil and gas fields (Fig. 1).

6 Applications for blocks CO2000-A to E close at 4.00 pm on AGE Thursday 29 June 2000 whilst applications for blocks CO2000-F ROCK UNIT

to H close at 4.00 pm on Thursday 28 September 2000. SERIES GROUP

CO2000 blocks, current Petroleum Production Licences SYSTEM (PPL) and Petroleum Production Licence Applications QUAT. Millyera Formation and equivalent (PPLA) are shown on Figure 1. Yandruwantha Sand Areas constituting unsuccessful PPLAs made by the Namba Formation operators of former PELs 5&6 will not be included in the BASIN surrounding CO98, CO99 or CO2000 blocks. Subject to Eyre Formation LAKE EYRE resolution of PPLA issues, if such areas become available, they would be included in a separate bidding round, post Mount Howie September 2000. In addition, areas surrounding the Coongie Sandstone Late Lakes Control Zone (CLCZ) will also be made available following a review of environmental issues. Winton Formation The key dates for Cooper Basin acreage releases are Allaru Mudstone listed in Table 2. Oodnadatta Formation Coorikiana Sst. Wallumbilla GEOLOGICAL SUMMARY CRETACEOUS TERTIARY Formation MARREE Eromanga Basin Early SUBGROUP The Eromanga Basin covers one million square Cadna-owie Formation Murta Formation kilometres of central-eastern Australia and contains the McKinlay Member multi-aquifer system of the . It Namur unconformably overlies the Cooper and Warburton Basins. Sandstone Westbourne Eromanga Basin stratigraphy can be divided into three Late Formation sequences – lower non-marine, marine and upper Adori Sandstone Birkhead Formation Sandstone Algebuckina non-marine (Fig. 2). Exploration is concentrated on the EROMANGA BASIN productive lower non-marine sequence. Middle The lowermost unit of the Eromanga Basin is the Hutton Sandstone

Poolowanna Formation, which consists of interbedded JURASSIC siltstone, sandstone and coal, deposited in high sinuosity Early Poolowanna Formation fluvial and floodplain environments. Poolowanna

Formation inter tongues with and is overlain by low 200171-002 sinuosity fluvial deposits of the Hutton and Algebuckina Sandstones. Basinward lateral equivalents of the Fig. 2. Eromanga Basin stratigraphy. Algebuckina Sandstone are Hutton Sandstone, Birkhead Formation, Adori Sandstone, Westbourne Formation, is developed at the top of the Cadna-owie Formation. The Namur Sandstone and Murta Formation. The Hutton, Adori contact between sandstones of the upper Cadna-owie and Namur Sandstones are similar in lithology and facies to Formation (Wyandra Sandstone Member) and overlying the Algebuckina but with an additional volcaniclastic marine shales of the Bulldog Shale or Wallumbilla component in minor amounts. Formation approximates a prominent seismic reflector - the The Birkhead Formation consists of interbedded C horizon – which is mappable across the entire Eromanga siltstone, coal and sandstone, Westbourne Formation Basin (Fig. 3). Formations of the Early Cretaceous are of consists of interbedded siltstone and sandstone of Late secondary interest to petroleum exploration in the area and Jurassic age. Murta Formation and McKinlay Member are not discussed in detail. The marine succession is overlie and intertongue with the Namur Sandstone and overlain by the rapidly deposited upper non-marine consist of thinly interbedded siltstone, shale, sandstone sequence (Winton Formation) which consists of coal, deposited in a large lake which extended throughout the floodplain and low sinuosity channel deposits. Cooper Basin region. The McKinlay Member is a lacustrine A period of erosion and deep weathering in the Late shoreface facies. Cretaceous caused by a switch in drainage from the Cooper Cadna-owie Formation records the transition into open region to the Ceduna Depocentre on the rifted southern marine conditions during the Early Cretaceous and consists margin of the continent was followed by deposition of the of interbedded sandstone, siltstone and claystone with minor non-marine Cainozoic Lake Eyre Basin. The modern carbonate. The fluvio-deltaic Wyandra Sandstone Member landscape was formed during the Pliocene-Quaternary. Table 2. Cooper Basin acreage releases, 1998 – 2000.

Round No. of Blocks Release dates Closing dates Notification of winning bids PEL details

First CO98 11 flank Th 15/10/98 Th 11/3/99 Fri 9/4/99 3x5 year terms Second CO99 8 core Th 8/4/99 Th 25/11/99 Jan 2000 2x5 year terms Third CO2000 5 flank Th 20/1/2000 Th 28/6/2000 July 2000 3x5 year terms 3 core Th 29/9/ 2000 Nov 2000 2x5 year terms Fourth CO2000 To be advised Late 2000 To be advised To be advised 2x5 year terms

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8 Cooper Basin glaciofluvial system deposited on glacially sculpted flat lying to deformed Warburton Basin sediments, volcanics The intracratonic Cooper Basin represents a Late and intrusives. The Tirrawarra Sandstone represents low Carboniferous to Triassic depositional episode. It lies sinuosity fluvial to proglacial outwash deposits overlain by unconformably over early Palaeozoic sediments of the peat swamp, floodplain and high sinuosity fluvial facies of Warburton Basin and is overlain disconformably by the the Patchawarra Formation. Eromanga Basin (Fig. 4). Three major troughs (Patchawarra, Nappamerri and Tenappera) are separated by Two lacustrine siltstone units (Murteree and Roseneath structural ridges (Gidgealpa-Merrimelia-Innamincka (GMI) Shales) with intervening fluvio-deltaic sediments (Epsilon and Murteree) associated with the reactivation of and Daralingie Formations) were deposited during a phase northwest-directed thrust faults in the underlying Warburton of continued subsidence. Early Permian uplift led to erosion Basin. These troughs contain up to 2500 m of of the Daralingie Formation and underlying units from Permo-Carboniferous to Triassic sedimentary fill overlain basement highs. by as much as 1300 m of Jurassic to Tertiary cover. Floodplain, peat swamp and high sinuosity fluvial facies The Late Carboniferous to Early Permian formations of of the Late Permian Toolachee Formation were deposited on the Cooper Basin comprise, in ascending order, the the Daralingie unconformity surface and are overlain Merrimelia Formation and Tirrawarra Sandstone – a conformably by Late Permian to Early Triassic Arrabury Formation. The uppermost coal, approximating the top Permian is mapped as the ‘P’ seismic horizon (Fig. 5). The AGE Arrabury Formation comprise floodplain and channel facies ROCK UNIT of the Callamurra, Paning and Wimma Sandstone Members, SERIES STAGE ZONE which are overlain by the Early Triassic Tinchoo Formation. SYSTEM PALYNOLOGICAL In the northern Patchawarra Trough, the Cooper Basin is locally overlain by the Middle to Late Triassic Cuddapan LAKE EYRE BASIN Formation. Deposition in the region was terminated at the

CENOZOIC end of the Early Triassic with slight but widespread deformation, regional tilt and erosion. EROMANGA BASIN Warburton Basin

JURASSIC- The Cooper Basin is unconformably underlain by CRETACEOUS sediments and volcanics of the eastern Warburton Basin Norian to PT5 Cuddapan Formation (Fig. 6). Warburton Basin sediments range from Cambrian Rhaetian Late Carnian PT4 to Ordovician; Devonian sediments have not been Ladinian intersected in the Cooper Basin region of SA. The eastern Middle PT3 Tinchoo Formation Anisian Warburton Basin is essentially a fold belt deformed during Wimma Sandstone the Late Devonian-Carboniferous Alice Springs Orogeny PT2 Member Paning intruded by mid-Carboniferous granitoids and subsequently Early Scythian Arrabury Member Formation buried to depths ranging from 1300 m to almost 4000 m. PT1 Callamurra Member The eastern Warburton Basin contains a basal suite of PP6 Tatarian acid-intermediate volcanics, tuff and agglomerate Toolachee Formation Late PP5 (Mooracoochie Volcanics), overlain by dolomitised shelfal Kazanian limestone historically assigned to the basal Kalladeina Ufimian Daralingie Formation PP4 Formation. A Middle to Late Cambrian carbonate shelf Kungurian Roseneath Shale developed in the Coongie-Cuttapirie area, with a slope to the

Epsilon Formation east. Several depositional sequences have been identified in Artinskian PP3 the Kalladeina Formation typically with deep water shales Murteree Shale COOPER BASIN overlain progressively by shallow water carbonate and Early clastic deposits. The Pando and Innamincka Formations PERMIAN TRIASSIC continue this trend to shallow water depths as part of a

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10 AGE ROCK UNIT Cooper Basin CARBONACEOUS–CRETACEOUS COOPER–EROMANGA BASINS Multi-zone high sinuosity fluvial sandstones form poor to good quality reservoirs. The main gas reservoirs occur primarily within the Patchawarra Formation (porosities up Mid-Late DULLINGARI to 23.8%, average 10.5% and permeability up to 2500 mD) and Toolachee Formation (porosities up to 25.3%, average 12.4% and permeability up to 1995 mD). Shoreface and GROUP Innamincka delta distributary sands of the Epsilon and Daralingie Early Formation Formations are also important reservoirs. Oil is produced

ORDOVICIAN Pando principally from low sinuosity fluvial sands within the Fm. Tirrawarra Sandstone (porosities up to 18.8%, average 11.1% and permeability up to 329 mD). Towards the margin of the Cooper Basin, oil is also produced from the Kalladeina Late Formation Patchawarra Formation and from fluvial channel sands in the Merrimelia Formation in Malgoona field.

Jena ? The Callamurra Member of the Arrabury Formation is Basalt conventionally regarded as a regional seal but nevertheless Middle contains economic oil and gas reservoirs in some areas and is a leaky seal in others. Low sinuosity fluvial sandstones of the Paning and Wimma Sandstone Members form economic oil and gas reservoirs and high sinuosity fluvial sandstone of Unnamed dolomite CAMBRIAN the Tinchoo Formation reservoir oil. As yet, there have been no economic oil or gas fields discovered in the Cuddapan Early Formation in SA.

Mooracoochie Warburton Basin Volcanics Fractures in brittle siltstones (e.g. Dullingari Group in Lycosa 1) are capable of trapping commercial oil and gas. Fracture patterns and their relation to pre-Cooper and PROTEROZOIC 200171-006 post-Cooper Basin structure are currently being studied by Fig. 6. Warburton Basin stratigraphy. PIRSA and the NCPGG. Pando Formation sandstone has surprisingly high porosity (~10%) in view of its low stratigraphic position. It is glauconitic and zircon-rich and consequently has a high gamma ray response. Moolalla 1 gas is reservoired in this 150 m thick has altered Warburton Basin strata and the formation which extends from Pando in the west to Moomba granites in particular, immediately beneath the Cooper Basin in the northeast. unconformity. Basal and middle Kalladeina Formation dolomites Structural style superimposed by compressional represent shelf limestones exposed to meteoric diagenesis deformation during the Alice Springs Orogeny follows during marine lowstands. Although minor gas shows have arcuate northeasterly trends imposed by northwest-directed been recorded, porosity prediction has proved elusive, the thrust faults. Wrench fault zones have been mapped dolomites and associated karst breccias proving tight when seismically in the Titan-Charo-Yanta area on the northwest drilled. flank of the Patchawarra Trough. Complex folding and Sturt 6 oil was produced from weathered tuff which faulting occur in some parts of the basin, but in many regions forms an extensive unit beneath the southwest Cooper the Early Palaeozoic is almost flat lying. Basin. The tuff, together with underlying agglomerate and lava, comprises the Mooracoochie Volcanics. Both the oil PETROLEUM GEOLOGY and gas originated from Permian source rocks. Reservoirs Oil and gas production from fields adjacent to CO2000 blocks is summarised in Table 3. Eromanga Basin Principal reservoirs are good to excellent reservoir quality Hutton and Namur Sandstones (porosities up to 25%, permeability up to 2500 mD). Oil is also reservoired in fair to excellent quality sandstones in the Poolowanna and Birkhead Formations, McKinlay Member and Murta Formation. The Algebuckina Sandstone is a major artesian aquifer. The Cadna-owie Formation (Wyandra Sandstone Member) forms a significant oil reservoir in Queensland, however economic hydrocarbons have yet to be discovered in this unit within SA.

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12 Table 3. Cumulative production to 31/7/99 for selected fields adjacent to CO2000 Blocks. Block Field name Gas pool Gas (m3 x106) Oil pool Oil (kL)

CO2000-C James Tinchoo 1009.6 Keleary Birkhead 1589.5 Hutton 482.9 Poolowanna 196573.2 Tinchoo 9593.2 Telopea Tinchoo 73617.2

CO2000-D Fly Lake Patchawarra 1346.721 Patch/Tirra 76484.4 Fly Lake East Patchawarra 184.154 Tirrawarra 18437.3 Fly Lake South Patchawarra 27.363 Patch/Tirra 34819.7

CO2000-F Cabernet Patchawarra 136.088 Daralingie Epsilon 32.445 Patchawarra 3913.353 Daralingie North Patchawarra 425.508 Deina Patchawarra 104.763 Dirkala Birkhead 127257.7 Epsilon 95.125 Epsilon 56.5 Patchawarra 8.403 Dirkala West Patchawarra 29.357 Dirkala South Birkhead 3049.0 Garanjanie Epsilon 57.606 Epsilon 504.5 Patchawarra 473.859 Kujani Patchawarra 240.201 Thurakinna Patchawarra 498.613 Touriga Patchawarra 13.428 Wancoocha Murta 573.4 Birkhead 232771.3 Hutton 11255.4 Patchawarra 25688.5

CO2000-G Alwyn Murta 43034.5 McKinlay 14863.7 Murta Goyder Patchawarra 173.183 Jena Murta 277431.6 McKinlay 154785.0 Kerinna Hutton 2922.5 Limestone Creek/Biala Murta 260049.7 Murta/McKinlay 149782.5 Namur 41358.7 McKinlay Namur 5280.4 Ulandi Murta 72510.4 McKinlay 15176.7

CO2000-H Burke Nappamerri 9.971 Tool/Daralingie 961.823 Patchawarra 299.887 Della Hutton 28.057 Tool/Patchawarra 18752.102 Dullingari Murta 887730.7 McKinlay 21727.9 Namur 718417.0 Tool/Daralingie 4570.294 Patchawarra 2321.351 Dullingari North Tool/Dara/Patch 1246.278 Murta 34179.1 Kidman East Toolachee 810.744 Kidman Main Toolachee 1452.752 Epsilon 2.496 Patchawarra 150.147 Kidman North Toolachee 142.342 Patchawarra 576.959 Munkarie Toolachee 136.606 Epsilon 927.846 Patchawarra 2426.447 Narcoonowie Murta 2884.0 McKinlay 11513.6 Namur 23652.6 Hutton 68944.1 Strzelecki Namur 247197.0 Birkhead 5924.7 Hutton 2461572.0 Toolachee 3276.351 Toolache 41 Toolachee 2.362 Patchawarra 124.196

13 Block Field name Gas pool Gas (m3 x106) Oil pool Oil (kL)

CO2000-H (continued) Toolachee East Epsilon 23.454 Patchawarra 2748.408 Toolachee North Patchawarra 74.755 Toolachee Northeast Patchawarra 661.207 Toolachee Northwest Epsilon 7.581 Patchawarra 362.319 Toolachee West Epsilon 426.940 Patchawarra 9404.187

Source Rocks light (30 to 60° API) and paraffinic, with low to high wax Both Cooper and Eromanga Basin mature source rocks contents. Most Permian oils in Permian reservoirs contain have actively contributed to oil accumulations in the region. significant dissolved gas and show no evidence of water Each oil accumulation needs to be considered on its merits washing. Gas composition is closely related to with respect to the extent of ‘mixing’ from Permian and maturity/depth with drier gas occurring towards basin Mesozoic sources. depocentres although there is strong geological control on hydrocarbon composition. Eromanga Basin The Patchawarra Trough contains the bulk of the oil and Oil originated either in the Eromanga or the Cooper wet gas reserves consistent with local source rocks being in Basin or a mixture of both. Although it is recognised that the ‘oil window’ while the hot Nappamerri Trough (40–50° Birkhead and Murta Formation sources exist, there is still C/km), underlain in part by granite, is over mature and considerable debate as to their extent and relative contains mainly dry gas. contribution. Permian source rocks have average TOC and S2 Potential source rocks of Jurassic and Early Cretaceous pyrolysis yields of 3.9% and 6.9 kg/tonne, respectively age contain Type II to Type III organic matter and have been (excluding coals). Locally, the Toolachee Formation is the shown to have maturities within the ‘oil window’ (onset of richest source unit. The Patchawarra Formation is oil generation between vitrinite reflectance 0.65-0.7%). considered the other major source unit (Fig. 8) especially the Significant suppression of Ro has been detected in some lower shales and coals. The lacustrine Murteree and Eromanga Basin source rocks using the FAMM technique. Roseneath Shales have little source potential. Average TOC and pyrolysis yields are slightly lower for Together, the petrographic and geochemical evidence Eromanga source rocks compared to Permian source rocks. support coals and associated DOM as the effective source However, the Birkhead Formation (mid-Jurassic) contains rocks capable of generating gas and minor oil, albeit in low the most hydrogen-rich organic matter and has an average yields. At maturity levels between 0.81-0.95% Ro, initial TOC of 2.5% and S2 pyrolysis yield of 10.8 kg/tonne. The generation from the richer facies has led to partial filling of Poolowanna Formation shows fair to good source richness; reservoirs with wet gas and oil (Fig. 9). There is a sharp the Westbourne Formation exhibits mainly fair source onset of significant hydrocarbon accumulation when the richness. source reaches a maturity of 0.95% Ro. Hydrocarbon extracts of Jurassic potential source rocks Thin, laterally discontinuous coals represent the best are paraffinic and waxy and similar to those from Permian source rocks of the upper Nappamerri Group whilst shales sediments. This lack of distinction probably reflects only tend to be organically lean. The lower Nappamerri Group is minor changes in organic facies and/or maturation histories coal-poor, contains kerogen that tends to be oxidised and or alternatively, reflects oil staining/contamination of any source rocks are humic-rich and gas-prone. Eromanga source rocks by migrating Permian hydrocarbons. Warburton Basin Oils in Cretaceous reservoirs are often geochemically Source rock quality of samples principally from the distinct from those in Jurassic reservoirs. They are typically Kalladeina Formation is poor to fair. With the exception of light (45° API gravity), non-waxy, low sulphur, paraffinic anomalously low maturity indices from Kalladeina 1, the crudes although waxy oils do occur. In Dullingari field, succession below 3000 m is late-mature to post-mature for Murta Formation oils are thought to be locally sourced from oil. Organic matter is mainly Type II kerogen derived from Early Cretaceous source rocks. marine algal/bacterial precursors. The marine Cretaceous sequence contains good potential Seals and Plays source rocks, however it is considered immature for hydrocarbon generation. Clearly, more work needs to be Where the regional seal is thin or absent multiple oil and done in order to distinguish local Eromanga Basin sourcing. gas pools are stacked in coaxial Permian-Mesozoic structures and may occur from as low as the Patchawarra Cooper Basin Formation to as high as the Murta Formation (Fig. 10). Permian coal measures and shales are the principal Locally, Permian oil has migrated into Warburton Basin hydrocarbon source rocks in the region and are dominated reservoirs on the basin margin and gas has migrated into by Type III kerogens derived from higher plant fractured Ordovician reservoirs fringing the Allunga assemblages. Oils and condensates are typically medium to Trough.

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Eromanga Basin Cooper Basin Trapping mechanisms are dominantly structural Anticlinal and faulted anticlinal traps have been relied on (anticlines with four–way dip closure or drapes over as proven exploration targets but potential remains high for pre-existing highs) with a stratigraphic component (e.g. discoveries in stratigraphic and sub-unconformity traps, Hutton–Birkhead transition, Poolowanna facies, McKinlay especially where the Permian sediments are truncated by the Member and Murta Formation). Eromanga structures in SA overlying Eromanga Basin succession. Economic oil and are rarely filled to spill with oil – net oil columns are gas are reservoired in the Nappamerri Group, paradoxically relatively thin compared to the height under closure (due to regarded as a regional seal to the Cooper Basin. poor sealing characteristics). Seals consist of Intraformational shale and coal form local seals in the major intraformational siltstones and shales of the Poolowanna, reservoir units. Beneath the Daralingie Unconformity are Birkhead and Murta Formations – no economic two important early Permian regional seals - the Roseneath hydrocarbons have been discovered in SA above the Murta and Murteree Shales. The Roseneath Shale is the top seal of Formation. Where these units are absent, potential seals the Epsilon Formation and the Murteree Shale seals the include Bulldog Shale and . Patchawarra Formation.

15 Undiscovered reserves of hydrocarbons have also been metres Cenozoic estimated by PIRSA, the Bureau of Resource Sciences LAKE EYRE 1000 BASIN (BRS) and Stratigraphic Research International AS (APRAS) to predict the undiscovered potential of the Jurassic- Cooper and Eromanga Basins. Results are summarised Cretaceous EROMANGA below. For more detail, refer to The Petroleum Geology of BASIN 2000 SA – Volume 4, Cooper Basin.

Permo- Triassic Cooper Basin gas COOPER BASIN The present discovered recoverable raw gas reserves (as Cambro- 3000 Ordovician at 1/1/99) of the basin are 245 billion cubic metres (8.7 TCF) WARBURTON BASIN comprising 146 billion cubic metres (5.19 TCF) of produced gas and 100 billion cubic metres (3.5 TCF) of gas yet to be Source rock Shale produced from known discoveries. The average recovery Gas Sandstone factor for gas fields is 64%. There have been 121 Cooper Oil Carbonate 200171-010 Basin gas fields discovered in SA to 1/1/98 from 298 new field wildcats. Fig. 10. Hydrocarbon plays schematic. Cooper–Eromanga Basin oil Warburton Basin The present recoverable oil reserves (as at 1/1/99) of the basin are 21.9 million cubic metres (138.25 MMSTB) Cooper Basin reservoirs, source rocks and seals have comprising 17.7 million cubic metres (111.35 MMSTB) of been juxtaposed against elevated ridges of Warburton Basin produced oil and 4.2 million cubic metres (26.9 MMSTB) of rock by faulting or by original deposition. These ridges are oil yet to be produced from known discoveries. The potential lateral seals but may also be reservoirs. Ridges are combined average primary and secondary recovery factor for composed of sandstone, shale, carbonate and volcanic units, oil fields is 21%. More than 80% of the oil reserves are which are fresh to severely altered by weathering and contained in the Tirrawarra Field. There have been 25 Cooper diagenesis (but not metamorphism). Dips vary from oil fields discovered in SA up to 1/1/98 from 297 new field horizontal to vertical, and units range from massive to wildcats. In the overlying Eromanga Basin, there have been slightly to pervasively fractured, with weak to strong 33 oil fields discovered from 293 wildcats (to 1/1/93). faulting and folding. Their competence as lateral seals is dependent upon a combination of lithologic and structural Results factors. Potential (undiscovered) resources should not be Potential traps in the Warburton Basin include large compared to traditional Proved, Probable and Possible hanging wall anticlines associated with northeasterly reserves in known discoveries. Undiscovered resources are trending thrust faults and upthrown fault blocks on wrench calculated to give a quantitative indication of the potential of fault zones. the basin, and require considerable exploration to establish A thick impermeable weathered profile on the top their existence. The results of methods considered to be Warburton unconformity surface forms a semi-regional seal reasonably reliable are summarised in Tables 5 and 6. and is distinguished on logs by its low uniform resistivity. Some of the potential attributed to the Cooper Basin may UNDISCOVERED POTENTIAL have already been discovered in the Eromanga Basin. The current discovered recoverable oil reserves of the Eromanga Introduction Basin in the Cooper Basin region are 14.5 million cubic The Cooper Basin is a mature petroleum province, metres (92.5 mmstb). however potential remains high for discoveries in INFRASTRUCTURE AND MARKETS stratigraphic and sub-unconformity traps, which have received increasing interest in the past five years. Pinchout Production Facilities plays along the margins of the Cooper Basin have been A total of 5238 km of pipeline have been laid to gas tested with commercial success. 3D seismic will have a markets in SA, NSW and Victoria and to the liquids load out critical role to play in delineating more subtle traps in the facility at Port Bonython. Key pipelines are listed in Table 7 future. Remaining SA Cooper–Eromanga Cooper Basin and shown on Figure 1. reserves (Santos) are shown below. At 1/11/99 in the SA Cooper Basin there were 94 online Table 4. SA Cooper Basin reserve summary, 1/1/99 (source Santos gas fields with a total of 495 connected gas wells (378 Ltd). online), and 29 online oil fields with a total of 124 oil wells Energy minerals Reserves producing oil wells. Sales gas 2449.7 PJ A combined total of 163 PJ of sales gas was sold in 1998 Ethane 283.6 PJ to Epic Energy and AGL. The estimated average daily LPG 55.2 mmbbl production in 1998 from the Cooper and Eromanga Basins Condensate 37.1 mmbbl 6 3 Oil 26.9 mmbbl was sales gas – 14.2 x 10 m (0.5 bcf), crude oil and conden- sate – 3816 kL (21 400 bbl) and LPG – 986 t (11 500 bbl).

16 Table 5: 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 6: 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)

Gas emerges at the wellhead at pressures up to 25000 gas for the plant), propane, butane, light naphtha, kPa and temperatures up to 120°C. Gas from individual intermediate naphtha, heavy naphtha, and reduced crude. wells passes via field gathering systems (flowlines) to Once cooled to ambient temperatures, the naphtha and satellite stations which separate gas, free water and reduced crude fractions are pumped to the blending section condensate. Evaporation ponds are used for water disposal. where they are mixed in precise ratios. The resulting two The essentially water-free gas and condensate pass to the products, ‘naphtha’ and ‘crude oil’ are sent to storage tanks Moomba treatment plant through trunklines. Crude oil is to await shipping. transported by either pipeline or truck to the Moomba plant. One destination for Cooper–Eromanga crude oil and Currently, nine oil and eleven gas satellites are in operation condensate is the refinery at Port Stanvac, which supplies in the Cooper and Eromanga Basins. Approximately 1010 petroleum products mainly for the SA market. The refinery km of trunklines and 1135 km of flowlines have been laid to commenced operations in 1963 and the adjacent lubricating date in the region. oil refinery began operations in 1976. The refinery does not At the Moomba plant free condensate and water are have sufficient capacity to produce all the State’s initially removed from the raw gas at the slug catchers. The requirements for motor spirit, and some must be imported gas then proceeds to the Benfield unit to ensure that no from interstate. The main refinery products from Port greater than 3% by volume of CO2 remains in the sales gas Stanvac are LPG, solvents, motor gasoline, jet fuel, stream. The gas is dehydrated at molecular sieves before it kerosene, diesel, lube oil base stocks for Australian and proceeds to the liquid recovery plant where 100% of the overseas markets, fuel oil and bitumen. remaining condensate, 98% of the LPG (C3 and C4) and Mini-refinery technology has proven itself viable in the 75% of the ethane are removed, leaving sales gas for Eromanga Basin at Eromanga in southwest Queensland, Adelaide and Sydney with a heating value <37.5 megajoules where the company, Inland Oil Refiners has been operating per cubic metre. The plant has been designed to process 25.4 6 3 since 1985. The Eromanga mini refinery has a throughput x10 m (902 mmcf) of raw gas and 6000 kL (42 000 bbl) of capacity of 1500 barrels of crude per day and receives condensate and crude oil per day. Condensate, LPG, crude feedstock from a number of Eromanga Basin oil fields, and some ethane are transported as a ‘cocktail’ via a pipeline including the Inland oilfield, discovered by the company in to Port Bonython where they are separated and marketed. 1994. The principal product is diesel, which is trucked The feedstock delivered to Port Bonython is first across western Queensland to regional centres for sampled, filtered and metered to determine flow rates and marketing. Other products include automotive distillate, jet composition. It is then pumped through a series of fuel, high quality kerosenes and specialised products for fractionating towers to separate ethane (which is used as fuel Mount Isa Mines. Heavy residues are processed in Brisbane.

Table 7. Cooper Basin pipeline licences, February 1999.

PL Pipeline name Operator Product Length Pipe diam. MAOP Construction (km) (mm) Kpa period

1 Moomba–Adelaide Epic Energy Sales gas 1065 total 560 7300 1968–69 +12 laterals various 1969–90 2 Moomba – Port Bonython Epic Energy (under Liquids 659 356 10380 1982 liquids line contract to Santos) 5 South–West Queensland Santos Sales gas 92 400 10000 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 Ethane 101 219 15300 1996 9 Stokes-Mettika Santos Raw gas 3.5 323.9 11400 1996 10 Moomba Interconnection Boral Energy Pipelines Sales gas 0.087 250 9665 1998

17 Other facilities in the Cooper Basin and producers facilitated. The issue of a right of access to upstream facilities is also currently being reviewed. The northern part of SA is sparsely populated and relatively undeveloped due to its remoteness and harsh Existing contracts with the South Australian and climate. The main primary industry in the region is cattle Queensland Cooper Basin Producers supply the State’s which are run on large pastoral leases. Eco-tourism is a needs in full until 2004, and partial needs to 2013 and those growing industry in the region. The township of Innamincka of until 2006. Demand in NSW is forecast is located 65 km from Moomba and offers a hotel, general to exceed current contracted quantities after 2001. The store and light aircraft airstrip. The Birdsville and Strzelecki Australian Gas Association (AGA) predict that gas will be Tracks are unsealed, but provide access for heavy vehicle the fastest growing energy source in Australia to 2030, with transport in the region. annual growth of 3% predicted. Natural gas currently supplies around 18% of Australia’s primary energy needs, Accommodation and support facilities are located at and the AGA predict this will increase to 28% by 2030. Moomba, a fly in-fly out camp operated by the Cooper Basin Their study of future Australian gas supplies and demand Joint Venture. Access to these facilities requires the forecasts that gas reserves in southern and eastern Australia agreement of Santos Ltd. The Moomba Camp can will be insufficient to supply market demand within a decade accommodate 450 people, with an additional 150 beds (Fig. 12). mothballed. A full range of support services is available at Moomba including logging, wireline, fraccing, cementing, transport, fuel supply, aviation and emergency services. The sealed airstrip is 1720 m long and able to accept Eastern Australia gas supply/demand medium-sized jets. Petajoules Groundwater, extracted from the Great Artesian Basin 1200 aquifer system, is critical for petroleum operations in the 1000 region. There are two major aquifers, the lower occurs DEMAND 800 BOWEN/SURAT within the Algebuckina Sandstone and Cadna-owie and coal seam Formation and provides hot (up to 100°C) good quality 600 COOPER (TDS 1000 mg/L) artesian water. The upper aquifer 400 comprises the Winton and Mackunda Formations which 200 produce poorer quality water. BASS STRAIT 0 Oil and gas markets 1995 2000 2005 2010 2015 2020 2025 After AGA A free market was introduced in 1988 for all oil and 200171-026 condensate produced in Australia. There is no restriction on imports or exports of crude oil or refined petroleum Fig. 12. Gas supply and demand, Eastern Australia (Australian products. A similar regime has applied since 1991 for LPG. Gas Association report). Markets for crude oil and condensate exist in SA and Australia and low sulphur light crude oils find a ready domestic and overseas market. Ex-field natural gas prices in SA are freely negotiated REGULATORY REGIME between buyer and seller. Ex-Moomba plant natural gas Review of Petroleum Act prices from the Cooper Basin are currently in the order of A$2.50 per gigajoule (Fig. 11). As a consequence of the gas Petroleum exploration and development are reform process in Australia, regulatory policy impediments administered by the Petroleum Group, PIRSA under the to the free trade in gas are being removed and the rights of Petroleum Act 1940 (SA onshore); and the Petroleum access to gas transmission and reticulation pipelines have (Submerged Lands) Act 1967 (Commonwealth, offshore) been provided, and direct negotiations between consumers and 1982 (SA offshore). During 2000 it is intended that new legislation will replace the existing Petroleum Act 1940. The main thrust of the proposed legislation is to provide a modern, Gas price - USAvs SA Cooper Basin pro-competitive, efficient and flexible basis for 1997 $AUS/GJ administration of petroleum exploration and development. 6 The objective is to establish a business environment that maximises investment opportunities for the exploration 5 USA average gas price industry in the State and facilitates development of 4 ex-plant discoveries. The main features of the Bill (which can now be 3 accessed from the PIRSA website) are: 2 • establishment of a co-regulatory regime focusing on 1 SA average gas price at Moomba gate achievement of environmental, public safety and 0 resource management objectives and reduced 1965 1970 1975 1980 1985 1990 1995 2000 compliance costs. 200171-025 • licence allocation and management mechanisms to Fig. 11. Comparison of Australian and US gas prices. facilitate competition for acreage and in gas supply.

18 • rights of third party access to licensed pipelines Innamincka Regional Reserve which, with the full (where not covered by the national access regime), cooperation of the PPL operator and partners, now covers depleted reservoirs (for gas storage purposes) and much of the productive area of the Cooper Basin. pipeline easements. Blocks CO2000-A, B, C, D and H lie partly within the • greater security of tenure for licences though Innamincka Regional Reserve, whilst parts of Blocks improved registration procedures. CO2000-E and F lie within the Strzelecki Regional Reserve • consultation processes to establish environmental (Fig. 13). objectives. Mineral and petroleum exploration licence applications The Occupational Health and Safety (OH&S) provision for areas within Regional Reserves are processed by PIRSA of the Petroleum Regulations have been repealed and but are referred to the Minister for Environment, Heritage substituted by regulations under the OH&S Act. and Aboriginal Affairs (MEHAA) for comment. Exploration work programs are discussed with DEHAA EXPLORATION ACCESS (Department for Environment, Heritage and Aboriginal Affairs) as a matter of policy. In the case of production Access to land tenements, approval must be given by the MEHAA in PIRSA Petroleum Group acts as a ‘one stop shop’ for Mining Production Tenements Regulation areas (Fig. 13) explorers in obtaining any necessary environmental production licence applications must be referred to MTUPA approvals on the occasions when they are required from (Minister for Transport, Urban Planning and Arts) for advice other Government Departments. Onshore and offshore on environmental significance of operations. In all other tenement applications, approvals to conduct field operations respects exploration and production is carried out under the etc. are first submitted to PIRSA, which arranges provisions of the Petroleum Act and Regulations. distribution to the other relevant Government agencies for Parts of the Cooper Basin (Fig. 13) are listed as wetlands comment and then issues the necessary approvals. of international significance under the Ramsar Convention Petroleum Group staff are available to assist licensees (the 1971 Convention on Wetlands of International prepare the necessary paperwork. Importance). The Coongie Lakes and part of the Coopers PIRSA Petroleum Group is currently introducing an Creek system have also been included in the Register of the objective based co-regulatory approach to the regulation of National Estate (Fig. 13). the upstream petroleum industry. This marks a move away from prescriptive regulation and the pre-existing ‘command European Heritage and control’ regime. There will still be inspection of field A number of sites of European heritage significance such operations, including audits by PIRSA inspectors and as historic buildings and structures and geological authorised persons. The co-regulatory approach requires a monuments occur in the region. These are indicated on the change in both culture and method. Successful Environmental Sensitivity Maps available from PIRSA. implementation of the new regime will reduce compliance The majority of the sites are small and easily avoided by costs and deliver better environmental outcomes. exploration activities. National Parks and Reserves Aboriginal Heritage A number of National Parks and Reserves have been In SA it is an offence to disturb or destroy Aboriginal created to conserve the best examples of vegetation and sites, objects or remains. Standard procedures for landforms in the region (Fig. 13). There are three types of determining the presence of Aboriginal heritage prior to the South Australian reserves including Conservation Parks, commencement of activities have been determined. These National Parks and Regional Reserves. The conditions of procedures involve consulting with the relevant Aboriginal access vary from park to park, based upon the type of reserve organisation and maintaining a watch for sites, objects or classification, the activity proposed and its likely impact on remains during activities. Generally the sites are no larger the environment. Access for petroleum exploration and than a few hundred square metres and are easily avoided. production is allowed in all parks in the Cooper Basin region Since the inception of the Aboriginal Heritage Act in 1988, and in all regional reserves in the state. Access issues into there have been no conflicts between Aboriginal heritage the Coongie Lakes Control Zone are currently under review. sites and exploration or production activities in SA. Innamincka and Strzelecki Regional Commonwealth Native Title Act 1993 Reserves The Native Title Act 1993 was passed by Federal In 1986, the Government determined that it was Parliament on 22 December 1993. The lengthy and complex necessary to consider the principle of multiple land use to Act provides statutory recognition and protection for the reconcile any conflict between the aims of conservation, concept of native title as recognised by the High Court in the agricultural interests and exploration for, and development case of Mabo v. The State of Queensland (1992). This Act of, subsurface petroleum and mineral resources. A Regional was substantially amended in 1998. Amongst other things, Reserve classification was created under amendments in these amendments inserted provisions for reaching 1987 to the National Parks and Wildlife Act 1972 indigenous land use agreements, provided more detailed specifically for the purpose of conservation while at the provisions for dealing with acts which might affect native same time permitting the utilisation of the petroleum and title, and provided a new test to be applied in the registration other resources of the reserve. A good example of this is the of claims for native title.

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20 The term ‘native title’ refers to those rights held by the Mining Act. Under the State scheme, responsibility for indigenous inhabitants of Australia at and since the time of negotiations lies with the licensee. European settlement that are recognised by the common law Licence holders are encouraged to develop a dialogue - it differs from conventional titles. There must be a with regard to Aboriginal heritage and related matters with sufficient and relevant connection to the land in question, Aboriginal people having associations with their licence continuous since settlement (1836 in South Australia). The area. Current Native Title Applications in the Cooper Basin nature of native title rights vary from group to group region are shown on Figure 14. according to laws and customs, and may include the right to camp or travel across land, rights to hunt, fish, gather food The right to negotiate process under the Native Title Act and take materials (timber, bark, ochre etc.) from the land. 1993 has been initiated with regard to the successful applications from Round 1 of the Cooper Basin acreage Since the passage of the amendments to the Native Title release. The applicants have decided to negotiate as a group Act in 1998, all applications in respect of native title under facilitated by the SA Chamber of Mines and Energy. The that Act are made as claims in the Federal Court (Any claims Aboriginal Legal Rights Movement is seeking to represent made under the South Australian legislation [see below] are all of the native title claimants. made in the Environment Resources and Development Court). The federal Court refers claims for native title to the Environmental regulation National Native Title Tribunal (‘NNTT’) for registration. If Petroleum Act 1940 the application passes the test which now must be applied before registration, the details of the claim are entered on the Environmental issues pertinent to petroleum exploration register kept by the NNTT (‘the Register of Native Title are managed in SA primarily through proper operational Claims’). Registration is a pre-requisite for getting most of planning in the initial stages. In order to ensure that activities the rights conferred on claimants under the NTA, including are undertaken in a manner which avoids or minimises the ‘right to negotiate’. environmental impacts, several documents are required before approval to commence operations is given. First a The NNTT also keeps the National Native Title Register Declaration of Environmental Factors (DEF) is required which comprises a record of all determinations made by the from the licensee. This is the licensee’s assessment of the NNTT, Federal Court, High Court, other Courts or Tribunals environmental impact of the proposed activity. A Code of and recognised State/Territory arbitral bodies. Environmental Practice is also required by regulation. The The NTA allowed for States to pass their own legislation code describes procedures that the proponent will adopt in a number of areas. South Australia did so in 1994/95. This during the planning, field management and monitoring legislative package validated certain acts which occurred phases of the operation. before 1994, allowed the State Environment Resources and Santos Ltd and their joint venture partners, who are the Development and Supreme Courts to hear native title related major oil and gas producers within the Eromanga and issues (including determinations under the State ‘right to Cooper Basin, have developed Codes of Environmental negotiate’ schemes) and set up alternative State ‘right to Practice for exploration and production. The codes provide negotiate’ schemes under the Mining Act 1971 and the Land guidance to licensees on environmental issues that need to Acquisition Act 1969. A ‘right to negotiate’ scheme was be taken into consideration in planning and undertaking later enacted as part of the Opal Mining Act 1995. No State exploration activities. These codes are currently being ‘right to negotiate’ process was enacted for petroleum at that revised in a move towards an outcomes based approach. stage. However in the interim they provide a standard acceptable to In so far as there is an impact on native title, the issuing the Government. A company may either adopt these Codes of Petroleum Tenements in this State continues to be or use its own Codes of Environmental Practice subject to governed by the Commonwealth ‘right to negotiate’ approval by PIRSA. The Codes are required to be reviewed procedure. regularly (at least every 3 years) to ensure techniques are up-to-date. In response to industry concerns, in 1995 a ‘safety net’ PIRSA is able to assist licensees by providing examples clause was introduced into the Petroleum Act which gives a of the documentation and advising on their scope. To date licensee first right to any licence which may be terminated there have been no significant concerns raised with regard to due to no fault of the licensee. Licence holders are requirements to minimise the environmental impacts of their encouraged to develop a dialogue with regard to Aboriginal operations. heritage and related matters, with Aboriginal people having associations with their licence area. Petroleum Act 1999 Following passage of the Commonwealth Native Title The key requirements of the new Petroleum Act enacted Amendment Act in 1998, there are now a number of options sometime in the latter half of 1999 are: available under the new federal legislation to develop a) All impacts on the environment, including the alternate State procedures to handle native title matters. The cultural and heritage and public safety aspects of the South Australian Government has initiated a number of environment, of all activities pertaining to petroleum legislative responses to these amendments. exploration and development must have a Declaration of The Government is undertaking extensive consultation Environmental Factors (DEF) prepared in accord with the with all relevant organisations as well as the requirements specified in the Regulations. Commonwealth, to establish a right to negotiate process in b) On the basis of the DEF and established criteria the Petroleum Act similar to that previously implemented in gazetted by the Minister, the Minister must classify the

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22 proposed activities as either low, medium or high impact APPENDIX 1 – CO2000 BLOCK MAPS, activities. SEISMIC SURVEYS AND SELECTED c) On the basis of the information provided in the WELL INFORMATION DEF and from stakeholder consultation, a statement of environmental objectives will be prepared and approved by NOTES ON WELL & SEISMIC DATA the Minister for all regulated activities classified as low or TABLES: medium impact. The statement documents the environmental objectives that must be achieved in carrying TD out the activities and the criteria to be used to determine Total depth (metres) whether the environmental objectives have been achieved. TNMT Compliance with the statement is a mandatory licence Tenement, No. = tenement at well spud condition. d) For low impact activities comprising the STATUS AT RIG RELEASE majority of wells, seismic surveys and development SC = single completion operations, the Minister approves the statement of Aban = abandoned environmental objectives for the proposed activity after Susp = suspended consulting with the Minister for Environment, Heritage and Aboriginal Affairs. P&S = plugged and suspended e) For medium impact activities the Minister WHEN OPEN considers approval of the statement of environmental When well completion report to be released to open file, objectives through a public consultation process equivalent 2 years for PEL wells (all wells and seismic drilled or to the PER process under the SA Development Act 1993. recorded in former PELs 5&6 became open file on expiry), 5 f) For high impact activities the Minister refers years for PPL wells. them to the Minister responsible for the administration of the SECURITY Development Act 1993 (Minister for Transport, Urban Planning and Art) for an environmental impact assessment OF = open file under Part 8 of that Act. Conf = confidential The new Act ensures transparency by making available PIRSA REF on a public register all DEFs, statements of environmental PIRSA reference number for each well completion objectives and classifications made on the level of report, to be used when ordering data. environmental impact of all activities under this Act. Also, the classification on the level of environmental impact of SEISMIC SURVEY INFORMATION proposed activities will be made by the Minister in Current at 26/11/1999. consultation with the DEHAA; and Planning SA. The Includes survey name, number of lines and line km consultation arrangements with these agencies will be within block. formalised in service or inter-Departmental agreements. For confidential seismic surveys ‘when open’ indicates date survey will be released to open file status (PEL seismic 2 years, all seismic recorded in former PELs 5 &6 became open file on expiry, PPL seismic 5 years). NOTE: All efforts are made to record best possible data and to correct errors or omissions made known to PIRSA. However, PIRSA takes no responsibility for the consequence of errors or omissions in these data.

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24 CO2000-A 2D Open File Surveys Summary: 9 Surveys, 29 lines, 375.5 km

Survey No. Line Lines km

62 ER02 2 1.8 65 CP01 1 30.2 67 CP01 1 23.2 70 CP03 4 74.4 82 CP01 1 17.5 82 CP42 4 74.5 83 CP31 4 75.5 84 CP12 9 64.9 92 CP01 3 13.5

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26 CO2000-B 2D Open File Surveys Summary: 4 Surveys, 9 lines, 116.7 km

Survey No. Line Lines km

65 CP01 1 9.7 84 CP12 5 93.5 85 CP11 2 10.5 87 CP21 1 3.0

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Fig. 17. Seismic line and well locations, ‘P’ Horizon Block CO2000 – C.

28 CO2000-C Well data summary (including selected wells in adjacent PPLs and PPLAs).

Well TD (m) Tnmt No. Spud Date Status Rig Primary Objective Security PIRSA Release Ref

Crumpa 1 2682 PEL 5&6 12/10/93 Abandoned Tinchoo (Oil) OF 7475 Pothos 1 2590 PEL 5&6 06/08/97 Abandoned Tool, Tirr/Merr (gas); Pool, Tinch (oil) OF 7623

2D Open File Surveys Summary: 176 surveys, 106 lines, 1198.6 km

Survey No. Line Lines km

58 ER02 1 47.7 60 ER01 1 23.0 66 ER01 1 42.5 78 CP01 4 18.3 79 ER01 1 44.3 80 CP02 7 36.0 81 CP04 4 35.1 83 CP31 1 5.4 84 CP12 7 102.6 85 CP11 8 144.7 85 CP21 5 87.8 87 CP21 3 38.3 88 CP01 20 208.3 91 CP11 8 45.0 92 CP01 2 17.7 95 CP01 14 134.4 96 CP01 19 167.5

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Fig. 18. Seismic line and well locations, ‘C’ Horizon Block CO2000 – D.

30 CO2000-D Well data summary (including selected wells in adjacent PPLs and PPLAs).

Well TD (m) Tnmt No. Spud Date Status Rig Primary Objective Security PIRSA Release Ref

Darter 1 2741 PEL 5&6 02/13/91 Abandoned Patchawarra OF 7348 Titan 1 2144 PEL 5&6 12/23/84 Abandoned Eromanga Oil OF 597 Yanta 1 2229 PEL 5&6 01/09/85 Abandoned Eromanga Oil OF 600

2D Open File Surveys Summary: 31 surveys, 187 lines, 1775.4 km

Survey No. Line Lines km

62 ER02 3 22.4 63 CP01 1 5.7 65 CP01 3 20.7 66 ER01 1 6.5 67 CP01 4 84.7 70 CP03 11 173.7 70 CP08 1 2.9 71 CP05 4 14.2 73 CP01 2 10.3 77 CP01 1 17.8 80 CP01 2 1.1 80 CP02 10 71.7 81 CP06 4 8.4 82 CP01 1 1.0 82 CP42 10 140.6 83 CP02 1 21.2 83 CP31 8 166.3 84 CP12 24 269.1 85 CP11 8 79.0 85 CP21 3 23.4 86 CP21 18 142.3 86 CP31 1 6.1 87 CP11 5 39.7 89 CP01 16 153.0 90 CP08 10 70.9 91 CP07 4 7.3 91 CP11 2 15.7 93 CP01 5 20.1 95 CP01 5 19.7 96 CP01 14 121.5 97 CP01 5 38.4

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Fig. 19. Seismic line and well locations, ‘C’ Horizon Block CO2000 – E.

32 CO2000-E 2D Open File Surveys Summary: 7 surveys, 30 lines, 488.1 km

Survey No. Line Lines km

64 CP01 4 77.4 65 CP01 2 7.8 66 ER01 1 14.0 69 ER01 4 58.3 70 CP09 2 14.5 84 CP32 8 238.9 85 CP11 9 77.0

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Fig. 20. Seismic line and well locations, ‘C’ Horizon Block CO2000 – F.

34 CO2000-F Well data summary (including selected wells in adjacent PPLs and PPLAs).

Well TD (m) Tnmt No. Spud Date Status Rig Primary Objective Security PIRSA Release Ref

Augusta 1 2684 PEL 5&6 10/30/96 Abandoned Patchawarra (gas) OF 7578 Boxwood 1 1933 OEL 20&21 04/18/68 Abandoned Cooper Gas OF 11/5/296 Boxwood 2 1789 PEL 5&6 05/01/85 Abandoned Eromanga Oil OF 643 Dunoon 1 1523 PEL 5&6 10/26/84 Abandoned Eromanga Oil OF 578 Gamay 1 1874 PEL 5&6 11/18/98 Abandoned Patchawarra OF 7719 Karilla 1 2149 PEL 5&6 06/05/87 Abandoned Cooper Gas Eromanga Oil OF 7071 Karina Southwest 1 2189 PEL 5&6 08/07/95 Abandoned Patchawarra (Gas/Condensate) OF 7520 Kopi 1 2627 PEL 5&6 12/26/90 Abandoned Patchawarra Gas OF 7338 Kujani 2 2180 PPL 65 10/08/92 Abandoned Patchawarra Formation OF 7438 Manooka 1 1966 PEL 5&6 05/12/87 Abandoned Cooper Gas OF 7065 Merinda 1 2684 PEL 5&6 11/29/87 Abandoned Cooper Gas OF 7118 Padulla 1 1494 PEL 5&6 10/28/86 Abandoned Eromanga Oil OF 7022 Pandruannie 1 1836 PEL 5&6 05/25/87 Abandoned Cooper Gas Eromanga Oil OF 7070 Trebbiano 1 2455 PEL 5&6 01/20/99 Abandoned Patchawarra OF 7730 Wancoocha 1 1986 OEL 20&21 03/10/68 Abandoned Cooper Gas OF 11/5/295 Warki 1 2146 PEL 5&6 09/12/96 Abandoned Patchawarra (gas) OF 7563

2D Open File Surveys Summary: 43 surveys, 517 lines, 3137 km

Survey No. Line Survey No. Line Lines km Lines km

62 ER01 5 5.7 90 CP01 12 86.8 63 CP01 4 71.2 91 CP10 2 3.1 64 CP01 10 118.1 91 CP11 18 104.3 65 CP01 2 22.4 92 CP01 15 31.7 67 CP01 17 111.2 92 CP10 1 0.2 68 CP01 17 61.0 92 CP11 11 25.4 69 CP02 4 17.0 93 CP01 8 89.7 70 CP06 3 22.2 93 CP04 7 13.1 70 CP07 1 2.1 94 CP09 5 20.6 72 CP01 1 1.7 94 CP21 21 166.9 75 CP01 3 12.6 95 CP01 21 139.1 76 CP01 9 91.8 96 CP01 23 56.3 77 CP01 11 68.4 98 CP01 11 120.1 78 CP01 2 7.8 79 CP01 19 193.1 82 CP02 30 217.9 3D Surveys 82 CP03 7 7.0 Survey Area (km2) 82 CP42 11 100.1 83 CP02 3 11.3 92 CP13 5.88 83 CP21 19 152.6 94 CP03 7.40 83 CP22 1 9.5 98 CP03 25.68 84 CP32 11 35.4 85 CP11 15 90.5 85 CP21 17 92.9 85 CP61 6 11.4 86 CP31 34 201.3 87 CP11 55 393.8 87 CP21 1 4.6 88 CP01 9 20.3 89 CP01 35 124.8

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36 CO2000-G Well data summary (including selected wells in adjacent PPLs and PPLAs).

Well TD (m) Tnmt No. Spud Date Status Rig Primary Objective Security PIRSA Release Ref

Alkoomi 1 1612 PEL 5&6 6/26/1986 Abandoned Eromanga Oil OF 7016 Aragorn 1 1618 PEL 5&6 5/15/1997 Abandoned Hutton Sst OF 7616 Battunga 1 2537 PEL 5&6 9/13/1987 Abandoned Cooper Gas OF 7094 Buckinna 1 1647 PEL 5&6 5/13/1983 Abandoned Eromanga Oil OF 450 Buckinna 2 1655 PEL 5&6 10/10/1989 Abandoned Murta Oil OF 7254 Cooloon 1 2769 PEL 5&6 6/1/1990 Abandoned Toolachee, Patchawarra Gas OF 7295 Kiwarrick 1 1836 PEL 5&6 3/16/1985 Abandoned Eromanga Oil OF 624 McKinlay 2 1588 PEL 5&6 8/15/1981 Abandoned Eromanga Oil OF 342 Mudlalee 1 2081 OEL 20&21 12/28/1967 Abandoned Cooper Gas OF 289 Mudlalee 2 1917 PEL 5&6 10/21/1978 Abandoned Cooper Gas OF 240 Mulga 1 1974 OEL 20&21 4/9/1969 Abandoned Cooper Gas OF 6 Murteree 1 2204 PEL 5&6 9/1/1970 Abandoned Cooper Oil OF 59 Murteree 1C 2267 PEL 5&6 8/23/1972 Abandoned OF 129 Murteree 2 2204 PEL 5&6 4/18/1984 Abandoned Eromanga Oil OF 514 Pinna 1 2582 PEL 5&6 12/21/1979 Abandoned Cooper Gas OF 262 Rieke 1 2179 PEL 5&6 9/14/1995 Abandoned Patchawarra, Epsilon (Gas) OF 7524 Ungari 1 1992 PEL 5&6 7/8/1989 Abandoned Namur Oil OF 7234 Yilki 1 1588 PEL 5&6 9/17/1988 Abandoned Eromanga Oil OF 7161

2D Open File Surveys Summary: 46 surveys, 489 lines, 2802.3 km Survey No. Line Survey No. Line Lines km Lines km 87 CP11 9 38.8 62 CP01 1 1.7 87 CP21 9 62.0 62 ER01 14 72.0 88 CP01 9 11.3 63 CP01 10 72.8 90 CP01 8 22.8 64 CP01 1 1.6 90 CP02 2 1.2 65 CP01 7 46.2 90 CP08 8 29.7 67 CP01 1 3.4 91 CP04 4 5.5 68 CP01 11 85.5 91 CP10 6 6.5 69 CP01 9 58.0 91 CP11 10 66.1 69 CP03 4 22.0 92 CP01 14 59.7 70 CP04 5 31.0 92 CP09 10 24.6 70 CP07 9 34.5 93 CP01 41 272.2 71 CP01 1 6.0 94 CP01 9 67.3 71 CP02 3 5.3 94 CP21 11 37.8 73 CP01 1 1.7 95 CP01 20 144.7 75 CP01 3 37.1 96 CP01 37 234.2 76 CP01 4 14.8 98 CP01 5 39.2 77 CP01 11 105.3 489 2802.3 79 CP01 13 121.0 80 CP01 18 118.7 82 CP02 1 8.0 3D Surveys 82 CP05 1 0.7 2 82 CP41 3 3.4 Survey Area (km ) 82 CP42 18 65.6 94 CP03 7.04 83 CP21 44 216.2 83 CP22 26 267.9 84 CP01 9 26.4 84 CP32 17 102.5 85 CP21 31 148.7 86 CP31 1 0.7

37 IRH°QH9 IRH°RS9 IRI°HH9

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Fig. 22. Seismic line and well locations, ‘P’ Horizon Block CO2000 – H.

38 CO2000-H Well data summary (including selected wells in adjacent PPLs and PPLAs).

Well TD (m) Tnmt No. Spud Date Status Rig Primary Objective Security PIRSA Release Ref

Azolla 1 2440 PEL 5&6 12/7/88 Abandoned Toolachee Epsilon Patchawarra Gas OF 7201 Baratta South 1 2361 PEL 5&6 3/23/92 Abandoned Patchawarra Gas OF 7416 Barcooloo 1 2198 PEL 5&6 3/31/85 Abandoned Cooper Gas Eromanga Oil OF 626 Burruna 1 1911 PEL 5&6 9/1/82 Abandoned Eromanga Oil OF 404 Chilcarrie 1 2292 PEL 5&6 3/25/88 Abandoned Cooper Gas OF 7139 Childie 1 2118 PEL 5&6 10/16/83 Abandoned Cooper Gas Eromanga Oil OF 481 Coobowie 1 1509 PEL 5&6 4/18/88 Abandoned Eromanga Oil OF 7144 Corkwood 1 2157 PEL 5&6 6/9/81 Abandoned Cooper & Eromanga Gas OF 328 Grystes 1 2353 PEL 5&6 5/5/91 Abandoned Patchawarra Gas OF 7363 Gudnuki 2 2637 PEL 5&6 3/15/98 Plug & Susp Patchawarra OF 7669 Katingawa 1 2575 PEL 5&6 5/17/92 Abandoned Patchawarra OF 7421 Katingawa 1 DW1 3116 PEL 5&6 5/17/92 Abandoned Patchawarra OF 7421 Keeto 1 2353 PEL 5&6 10/23/85 Abandoned Cooper Gas OF 631 Keeto 2 2316 PEL 5&6 3/29/91 Abandoned Patchawarra Gas OF 7355 Nappacoongee 1 3010 OEL 20&21 9/14/65 Abandoned Cooper & Eromanga Oil/Gas OF 201 Nappacoongee 3 1994 PEL 5&6 11/15/83 Abandoned Cooper Gas Eromanga Oil OF 476 Pelketa 1 2195 PEL 5&6 6/13/79 Abandoned Cooper Gas OF 255 Plotosus 1 2245 PEL 5&6 7/12/96 Abandoned Patchawarra (gas) OF 7553 Strathmount 1 3229 PEL 5&6 6/3/87 Abandoned Cooper Gas OF 7069 Toolachee 2 2195 OEL 20&21 5/4/69 Abandoned Cooper Oil OF 8 Toolachee 22 1728 PPL 14 9/30/83 Abandoned Eromanga Oil OF 472 Toolachee 37 2423 PPL 14 2/8/87 Abandoned Cooper Gas OF 7049 Wirha 1 1944 PPL 24 1/31/88 Abandoned Eromanga Oil OF 7125 Witchetty 1 2235 PEL 5&6 4/14/88 Abandoned Toolachee Gas OF 7167

2D Confidential Surveys Survey No. Lines Total Line Summary: 6 surveys, 19 lines, 43.9 km 71 CP03 3 2.4 72 CP02 2 7.2 Survey No. Lines Total Line km When 73 CP01 9 32.1 Open 75 CP01 22 150.1 80 CPXX1 2 3.9 ?? 76 CP01 15 155.2 94 CP08 6 6.2 12/12/99 95 CP07 4 12.7 3/03/00 77 CP01 13 55.5 95 CP08 1 5.6 1/03/00 78 CP01 12 76.2 95 CP09 3 8.9 20/05/00 78 CP02 1 4.0 96 CP03 3 6.6 14/04/01 79 CP01 6 30.0 80 CP01 21 19.5 80 CPXX2 1 2.5 2D Open File Surveys 81 CP02 22 33.6 Summary: 62 surveys, 757 lines, 3671.1 km 81 CP06 18 104.1 81 CPXX1 1 1.1 Survey No. Lines Total Line 82 CP02 3 22.5 82 CP05 20 80.8 61 ER02 8 21.0 82 CP42 15 103.7 62 CP01 1 18.5 82 CPXX1 1 2.1 62 ER01 1 3.0 83 CP03 19 30.5 63 CP01 12 58.0 83 CP21 30 155.1 63 ER01 1 21.4 83 CP22 14 152.8 65 CP01 9 83.3 84 CP01 12 58.0 68 CP01 12 89.7 84 CP32 26 128.5 69 CP01 27 147.9 85 CP02 11 48.0 69 CP03 4 44.7 85 CP21 7 49.1 70 CP04 4 14.8 85 CP41 18 47.2 70 CP07 1 1.9 86 CP11 1 4.1 71 CP01 9 44.2 86 CP21 17 50.3 71 CP02 2 10.8

39 Survey No. Lines Total Line

87 CP11 16 79.3 87 CP21 41 208.6 88 CP01 18 70.1 88 CPXX1 1 0.8 89 CP01 39 154.7 89 CPXX1 2 0.6 90 CP01 37 133.1 90 CP12 1 1.0 90 CPXX01 5 7.5 91 CP01 5 38.8 91 CP11 24 148.2 92 CP01 43 269.2 92 CP05 9 13.7 92 CP06 2 0.7 93 CP01 8 27.3 93 CP03 7 14.4 94 CP07 2 1.8 94 CP21 4 9.6 95 CP01 30 174.8 96 CP01 29 141.2 97 CP01 3 10.3

40 APPENDIX 2 – DATA AND ORDER Paradox Runtime and software to query and export the data FORMS are provided. ® Extensive databases of petroleum information are held PEPS-SA (spatial database) by Petroleum Group PIRSA and are readily available and Bundled with the attribute data are Mapinfo spatial accessible in digital and hard copy format. All basic datasets. Viewing this data in a mapping package allows the technical data obtained by a licensee in an exploration geoscientist to spatially view datasets, to turn on and off licence are required to be submitted to PIRSA as part of various layers of interest, zoom in and out etc, to allow the licence commitments. These data are held confidential for generation of custom built base maps which can be printed. two years after acquisition for PELs and for five years for There are more than 60 separate layers, ranging from PPLs, after which data are placed on open file. Basic data general topographic data such as state boundaries, coastline, comprises well completion reports, well logs, core and fluid national parks and restricted areas, road, railways and analyses, seismic acquisition and processing reports, various tenements, through to geotechnical layers such as seismic record sections, field and processed tapes and basin outlines, well locations, seismic lines, seismic production data. horizons, tectonic provinces, and many more. PIRSA provides a ‘one stop shop’ for industry and is The PEPS-SA attribute and spatial databases are bundled ready and able to provide data and expert advice quickly to ® together as one package on CD-ROM which costs $3000. the explorer. A digital database (PEPS–SA ) contains Twice yearly updates of PEPS-SA cost an additional $300 details of all wells drilled, seismic surveys, production per year. statistics etc. Comprehensive digital datasets and maps of key seismic horizons in the Cooper, Eromanga and Otway Core photos Basin are also available. The department has recently scanned all petroleum core photographs, and the thumbnail images are included in the PIRSA COOPER BASIN PRODUCTS data package if you receive the CD-ROM version. Full size PEPS-SA® (attribute database) images are also available and are approximately 1500 pixels by 1000 pixels by 256 colours. The total set contains over PEPS-SA (Petroleum Exploration and Production 1900 images occupying 1.4 Gigabytes. System—SA) is a comprehensive relational database containing a wide range of technical data relevant to the The Core Photo CD-Rom set (3 disks) costs $250, and petroleum industry. PEPS-SA is available for purchase. includes viewing software which links the photo to the The key data element is the petroleum well and each well has attribute data. A special discount of 50% is available for thousands of attributes. There are eight key modules Tertiary academic institutions. comprising 99 data sets (Table 8). Selected publications Data are supplied with a PEPS-SA menu-driven Publications providing information on petroleum in SA windows system. For clients without Paradox, a copy of and in the Cooper Basin include:

Table 8. PEPS-SA® modules and contents. Engineering Well abandonments; casing details; formation tests (open & closed); liquid evaluation tests; perforations; treatments; well tests.

Geology Core analyses; cores (including core photograph thumbnails); cuttings; available formation tops; hydrocarbon bulk composition; palynology; Rock-Eval; aromatic and saturated hydrocarbon analyses; source rock extracts; thin sections; vitrinite reflectance.

Geophysics Available seismic exabyte tapes (including raw field data and processed data); seismic lines; seismic sections; seismic survey reports; seismic survey summaries; surveys and lines; synthetic seismograms, seismic survey marks; seismic analog tapes.

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 – exploration expenditure; consumer price index; crude oil prices; gas pricing, gas sales; liquid sales; petroleum royalties; raw gas production; seismic surveys; wells drilled annually.

Production CO2; crude oil; crude oil production summary; crude oil test data; crude unit oil; enhanced oil recovery gas injection volumes; gas field reservoir data; Katnook gas production; oil field reservoir data; raw gas deliverability; raw gas production summary; raw gas production completion summary; raw gas production.

Production graphs – production history (gas, oil); decline curves (gas, oil); completions (gas, oil); water ratio (gas); water ratio history (gas); average gas rates (gas); gas rate history (gas); completion days (gas, oil); oil cut decline (oil); oil cut history (oil); average oil rates (oil); oil rate history (oil); monthly production versus cumulative (gas, oil).

Tenements PELs; PPLs; PLs and pipeline details.

Wells Basic well data (latitude, longitude, TD, KB, status, classification etc.), well completion reports (PIRSA reference, cost).

41 • Petroleum Exploration and Development in South The stack seismic totals approximately 14 000 data files Australia 1999 edition — comprehensive summary on 15 Exabyte Tapes. All data has had SP/CDP relationships of the State’s petroleum industry, published every embedded in the EBCIDIC header, and supporting attribute two years (free). data relating to the line and data files. A data index is also • Petroleum Services Directory South Australia — provided in spreadsheet form for each tape. published annually (free). Stacked Cooper Basin seismic sections (SEGY, approx • Holders of Petroleum Tenements. Sheet P1 — 14 000 files) costs $22 400. includes maps of, and interests in PELs, PPLs and Seismic Mapping PLs, produced quarterly (free). A program commenced in 1989 to consolidate open file • The Petroleum Geology of South Australia series. basic and interpreted data into coherent data sets. The aim Volume 4 provides a comprehensive review of the was to prepare regional interpretations of basin structure in petroleum geology of the Cooper Basin, published in prospective basins. This program is nearing completion for 1998. The book costs $195 plus $25 p&p; a pdf file the major onshore and large areas of the offshore basins, on CD-ROM costs $100. Volume 2 covers the Ero- including the Otway, Eromanga, Cooper, Simpson and manga Basin and the book costs $50 plus $25 p&p. Pedirka Basins. • Cooper Basin Exploration Opportunity. Blocks The SA Cooper Basin seismic mapping data package CO98-A to K and CO99-A to H. — acreage release contains 54 digital datasets and costs $15 000 for all brochures (free). datafiles. Well Logs (Petlog) Cooper Basin Folio This digital open hole well log database includes field This folio is the culmination of an extensive seismic and and edit tapes, and higher resolution data including geological mapping and interpretation of the Cooper Basin dipmeter, FMS (Formation Micro scanner), array sonic and and the overlying Eromanga Basin in SA: VSP (Vertical Seismic Profile). These data are now • Volume 1 contains 39 maps including key seismic available in a variety of formats and media including depth structure maps, formation isopachs and CD-ROM. structural elements, infrastructure, licences, fields, Digital data are available as: wells and seismic line locations. • basic validated data as originally supplied, EDIT or • Volume 2 contains 30 maps of geological datasets FIELD processing, and including lithofacies and maturity maps of key • fully verified and merged data, or data digitised from source intervals (depths to oil and gas windows). analogue source. All data are also available in digital format and are The cost of basic log data is derived from the cost of supplemented by individual technical reports available from transfer – e.g. a special CD-Rom containing 100 selected PIRSA. Each volume of the folio in digital format (pdf) Cooper Basin well logs costs $100. Free quotes are provided costs $500, including postage and packing (if both volumes for specialised orders and fully verified, merged or digitised are purchased together a special price of $800 applies). In data orders. addition, gridded and contoured digital datasets of Volume 1 and Volume 2 maps (i.e. fully manipulative data) are Seismic Shotpoint Database available for $15 000 and $2500 respectively. This is a comprehensive digital data set of shotpoint Hard copies cost $1000 for each volume (if purchased locations and associated attribute data from ~611 surveys together, a special price of $1800 applies). Individual hard carried out in the State and adjacent waters to latitude 40°S copy maps can be purchased from $70 each and discounts since 1955, totalling over 200 000 km. These data are are available if map sets are purchased. maintained in ArcInfo where complex GIS analysis and modelling can be performed with other digital data sets. The NGMA COOPER/EROMANGA PRODUCTS index to these data and summary information are also available in PEPS. Regional seismic horizon maps Digital data are available for purchase in various formats Regional time and depth datasets covering key Cooper on exabyte tape or diskette. Hard copy maps can be prepared Basin seismic horizons in SA and Queensland, and key for any area at any scale. As an example, the Cooper Basin Eromanga Basin horizons in SA, Queensland, NSW and the Seismic Shotpoint database costs $75 for approximately NT have been prepared as part of the National Geoscience 80 000 km of seismic lines. Mapping Accord (NGMA) Project involving the above States and AGSO. Stack seismic data Digital grid files and digital contour files cost $1800 Archive processed data in SEGY format are available for each; individual hard copy colour fill contour maps cost approximately 5000 seismic lines over the Cooper and $200 each and sun shaded images cost $600 each. A 50% Eromanga Basin area. In most cases 3 versions of data are discount applies to companies who have already purchased available: the SA Cooper and Eromanga Basin datasets. • Filtered Final Cooper Basin Geohistory • Filtered Migration An interactive CD-Rom Cooper-Eromanga Geo- history • Raw Final for each line. Report, which uses a display version of WinBury and Web

42 Browser software to dynamically display model plots has SA_GEOLOGY been developed. It includes individual well model plots of A library of digital geological maps that provides geohistory, maturity, source rock generation and maps of detailed, up to date GIS coverages of the State’s geology. selected horizons which can be animated through time. In Available in ASCII, ArcInfo, DXF, ArcView and MapInfo addition, cross sections showing palaeotemperature, formats. maturity and source rock expulsion can be displayed and animated. The interactive Geohistory CD-Rom will be Miscellaneous Hardcopy Data available in early March at an expected cost of $500. PIRSA holds the largest collection of SA geoscientific Organic geochemistry database literature, mining and exploration data, dating from the 1850s. Open file data comprises company exploration A comprehensive organic geochemistry database reports (including well completion and seismic reports), (Oracle v7) has been developed during the NGMA Project. PIRSA report books, geophysical data including seismic It includes company and government generated Rock Eval, sections, government publications, geoscientific maps, TOC and Vitrinite Reflectance data for the Cooper and plans, publications and more. Eromanga Basins. The Oracle database (PC or Unix) costs $9000, an ASCII file of data costs $3000, available from The PIRSA Document Storage Centre is responsible for AGSO. storing and copying all unpublished material. Copies may be ordered on paper, microfiche and transparency. The DSC Petroleum Tenements strives to complete orders within two days. A free SA petroleum tenement brochure, including a listing of tenement, holder(s) and interests, expiry date and Web Site area, is released quarterly. In addition, up-to-date digital To be kept up to date on what is happening in SA, why tenement data are available for free download from the not visit our web site at: PIRSA website. http://www.petroleum.pir.sa.gov.au All tenements granted, surrendered or cancelled are published in the SA Government Gazette issued weekly PETROLEUM DATA CONTACTS from the State Information Centre, 25 Grenfell St, Adelaide. ® These notices are also widely publicised in the business, PEPS-SA (attribute and spatial), core photos, investment and resources sectors of the local and well logs: international press, as well as by circulation to listed Alan Sansome (Petroleum Data Manager) exploration companies, stockbrokers, etc. Ph: 08 8463 3221 * OTHER PIRSA SERVICES [email protected] Seismic data: Core Library Dave Cockshell Well samples obtained from company and departmental petroleum, stratigraphic and mineral exploration are stored Ph: 08 8463 3233 * at the PIRSA Core Library. Over 3 million metres of core [email protected] and cuttings from 24,000 SA drillholes are currently stored. The Core Library is located at 23 Conyngham St, Glenside, NGMA datasets approximately 3 km SE of the Adelaide CDB. Tony Hill Viewing facilities are world class – the core layout area Ph 08 8463 3214 * is fully enclosed with special lighting. All open file samples [email protected] are available for inspection, in most cases sampling is permitted. 48 hours notice for a layout is required – there is Petroleum Tenements no charge for viewing and sampling. Mario Colella Ph 08 8463 3209 * Aeromagnetic Database [email protected] A digital database of aeromagnetic survey boundaries has been compiled and gives the location of all airborne Core Library surveys over SA and adjacent waters. Aeromagnetic survey Brian Logan digital data and hard copy maps are also available for Ph 08 8379 9574 purchase from PIRSA. Fax 08 8338 1925, Digital Geological Maps Of SA [email protected] SA_DISPLAY Digital Geological Maps Of SA An integrated set of State-wide geological, geophysical, Stephen Bell Ph 08 8463 3288 geochemical and groundwater databases brought together in GIS where they can be digitally overlain and interrogated. Fax 08 8463 3268, Available in ArcView and MapInfo formats. [email protected]

43 Aeromagnetic Database Domenic Calandro Ph 08 8463 3051 Fax 08 8463 3040, [email protected] Ordering copies of miscellaneous hardcopy data Peter Dunne Ph 08 8463 3003 Fax 08 8204 1880 [email protected]

* Fax 08 8463 3229 DATA ORDER FORMS Two order forms for Cooper Basin data products and free PIRSA publications follow. Completed forms can be mailed to: Petroleum Group PIRSA GPO Box 1671 ADELAIDE SA 5001 Or faxed to: National (08) 8463 3229 International IAC 61 8 8463 3229

NOTE: All prices herein are $Australian.

44 SELECTED COOPER BASIN DATA PACKAGES

PRODUCT Digital Number Hardcopy Number Note all prices in $Aust Data Required Data Required PIRSA Seismic Mapping (Cooper Basin) $15 000 — (total of 54 digital datasets) Cooper Basin Folio 1 (seismic) gridded & contoured * $500 $1 000 datasets included in PIRSA Seismic Mapping product Cooper Basin Folio 2 (geology) * $500 $1 000 Cooper Basin Folio 2 gridded and contoured datasets $2 500 — Cooper Basin Folios1&2(special offer) * $800 $1 800 Petroleum Geology of SA Volume 4 Cooper Basin — $195 p&p $25 Cd-rom version Petroleum Geology of SA Volume 4 $100 — Cooper Basin (pdf file) Lineament associations in the Cooper Basin, basement — $75 controls on hydrocarbon distribution PEPS and MAPINFO Database (entire State) $3 000 — Selected Cooper Digital Well Logs CD-ROM $100 — Seismic Shotpoint Database Cooper Basin only $75 $100 Stacked Seismic Sections (SEGY) — One version of all 2D lines in blocks CO2000 A to E $500 One version of all 2D lines in blocks CO2000 F to H $1 600 All 3D data (migrated) in blocks CO2000 F to H $1 600 * = pdf file only, restricted data manipulation only (e.g. re-sizing) I accept the following conditions of sale: 1. All data must be kept exclusively for the use of the purchaser/purchasing company and must not be transmitted, traded or sold to any third-party without the permission in writing of the CE, Primary Industries and Resources SA. 2. All efforts are made to record best possible data and to correct errors or omissions made known to PIRSA. However, PIRSA takes no responsibility for the consequence of errors or omissions in these data

Customer signature: Total cost of order: $Aust

I enclose a cheque Please invoice Please charge my: Bankcard Mastercard Visacard

Cardholder’s name: Expiry date: Cardholder’s signature: Date: Name: Company: Address:

Phone: Fax: Email:

45 ORDER FORM FREE PETROLEUM PUBLICATIONS AND COOPER BASIN REPORTS

Name: Company: Address:

Phone: Fax: Email:

Please mail me a copy of the following free publications and add me to the PIRSA Petroleum free mailing list:

Petroleum Exploration and Development in SA YES NO Quarterly SA petroleum tenement update YES NO Mines & Energy SA Journal YES NO SA petroleum industry services directory YES NO Cooper Basin acreage release brochures YES NO Cooper Basin gas economics report YES NO Cooper Basin undiscovered potential report YES NO A guide to Cooper basement log picks YES NO Cooper99 Symposium Abstracts YES NO

46 APPENDIX 3 – LICENCE APPLICATION guaranteed program is a firm commitment by the applicant FORM AND PROCEDURES regardless of circumstances (force majeure or a taechnical issue excepting). Failure to fulfil the work program for any Application year of the guaranteed program will, unless as a Although there is no form set by regulation, it would be consequence of force majeure circumstances or a preferred that an application for a Petroleum Exploration compelling technical justification, result in cancellation of Licence (PEL) in the CO2000 round be lodged in the licence. Such cancellations will be taken into account in accordance with the attached pro forma, and must be assessing future applications for petroleum exploration accompanied by two copies of a plan of the application area licences in South Australia, by the applicant company and and accompanied by the prescribed fee (which is currently other companies with Directors in common with the A$ 2298 for each licence applied for). applicant company. An application can be made by one or more individuals Non-Guaranteed Program or one or more companies or a combination of both. When a For those years of the program not guaranteed, once that foreign company makes an application, the foreign company licence year has been entered the licensee guarantees to must be registered under the provisions of the Australian carry out the work program stipulated. The licensee may Corporations Law. Information on registration apply to withdraw from the licence prior to entering a requirements can be supplied on request. non-guaranteed year if the application is received at least 3 Technical Qualifications/Experience months prior to entering the year as provided in the Petroleum Act 1940 (provisions of a Petroleum Bill The applicant must submit with the application a currently before Parliament reduce the period to one month). summary of the technical qualifications and experience of A surrender in such circumstances will not jeopardise future the applicant (or consultants/agents of the applicant) to applications for Petroleum Exploration Licences. satisfy requirements that the applicant is capable of satisfying compliance with the Petroleum Act and the terms Variation of Work Programs and conditions of the licence. Variation of work programs are possible, however this Financial Position would only generally be done where extraordinary cause exists (force majeure or a significant technical issue), Evidence of the financial resources available to the especially for a licence issued for which there were applicant is to be supplied to demonstrate ability to fulfil the competing bids. In that case, variations below the next proposed work program and in particular, any “guaranteed” highest bids received at the time of award would not be portion of the program (see below). Such evidence can be in approved, and would require partial relinquishment of the the form of the latest annual report or a verifiable statement licence area proportional to any approved reduction in from an independent accountant, auditor or financial program. institution for each applicant company. If other known financial and exploration commitments over the next 5 years Special conditions of the licences to be offered are such as to subsequently impact on the applicants ability The licences to be offered for CO2000 Blocks A to E will to carry out the program set out in the application, attention be offered for two renewal periods, with non-negotiable must be drawn to this fact and the implications briefly relinquishment of one third of the initial licence area at the described. end of the initial 5 year term. Work Program The licences to be offered for CO2000 Blocks F to H will The applicant must submit with the application a be offered on the condition that only one renewal will be statement of exploratory operations the applicant proposes permitted, with non-negotiable relinquishment of 50% of the to carry out in each year of the first five year term of each initial licence area at the end of the initial 5 year term. licence, including an estimate of exploration expenditure (in A$) to be incurred in each year of the licence. Note that the Award Criteria program must be on a dry hole basis, and that appraisal or The basic objective in awarding a Petroleum Exploration development drilling will not be counted towards the first Licence is to select the work program considered most likely five year work program bid. Work programs proposed in to evaluate the prospectivity of the licence area and discover bids must significantly advance the exploration status of the petroleum within the initial 5 year term of the licence Work area. At least one well must be proposed within the 5 years of program bids will be assessed taking account of the criteria the licence term. A work program proforma is attached and listed below. All these criteria are used when selecting the should be submitted with your application. Under the winning bid. It is important to note that the timing of provisions of the Petroleum Act 1940, the Year 1 program of activities, especially the drilling of wells, and the extent of the tenement is a requirement (ie “guaranteed”). Programs the guaranteed nature of the program carry substantial proposed for Years 2 to 5 of the licence must be designated weight in the assessment process. either “guaranteed” or “non-guaranteed” – (ie years cannot The most important criteria for assessment of work be designated part guaranteed and part non-guaranteed), and programs (not necessarily in order of preference) are: non-guaranteed years cannot precede guaranteed years. • The number of exploration wells (dry hole basis) to Guaranteed Program be drilled, their timing and the anticipated As set out above, the Petroleum Act provides that as a exploration targets (i.e. Mesozoic, Permian or minimum the first year of the program is guaranteed. A Pre-Permian objectives).

47 • The extent that the wells proposed to be drilled are supported by adequate seismic or other geophysical techniques. • The amount and nature of seismic surveying to be carried out and its timing. • Other data acquisition and seismic reprocessing to be carried out. • The number of years that the applicant is willing to guarantee the work program. • The adequacy of financial resources and technical expertise available to the applicant. In addition to the above criteria, where work program bids are similar, the benefits of the introduction of new explorers into the area (including intention with regard to establishing an office in SA) may be taken into account. It should be noted that there are no criteria limiting the number of PELs which may be offered to one applicant providing the applicant has adequate financial resources to complete all programs (although in considering Competition Policy Principles it would require major work program benefits to offer more than two PELs to the one applicant in the third round of bidding). There will be no consideration taken of the success of applicants in the various bidding rounds in selecting successful applicants. In the case of ‘cascading bids’ (i.e. multiple or hybrid bids for an area by one applicant or joint venture) only the highest of the bids will be considered. Notification of assessment The basis for the selection of the successful applicant, including the successful applicants proposed work program for each block will be published. Unsuccessful applicants will be notified of the reasons for the failure of their application.

48 YEAR 1 WORK PROGRAM Note: All work in Year 1 is guaranteed (Petroleum Act)

WELLS YEAR 1 Please identify all test targets for all wells by ticking appropriate boxes Well 1 Well 2 Well 3 Well 4 Well 5 Well 6 Well 7 Well 8 Well 9 Well 10 Eromanga Cooper Warburton

Cost (A$k)

SEISMIC YEAR 1 km/km2 Cost (A$k) 2D Seismic 3D Seismic Seismic Reprocessing

OTHER STUDIES YEAR 1 Cost (A$k) Description Geological & Geophysical Studies

Aeromagnetic Surveys

Geochemical Surveys

Other

COMMENTS

49 YEAR 2 WORK PROGRAM Entire Year 2 program: guaranteed (You must tick a box) non-guaranteed

WELLS YEAR 2 Please identify all test targets for all wells by ticking appropriate boxes Well 1 Well 2 Well 3 Well 4 Well 5 Well 6 Well 7 Well 8 Well 9 Well 10 Eromanga Cooper Warburton

Cost (A$k)

SEISMIC YEAR 2 km/km2 Cost (A$k) 2D Seismic 3D Seismic Seismic Reprocessing

OTHER STUDIES YEAR 2 Cost (A$k) Description Geological & Geophysical Studies

Aeromagnetic Surveys

Geochemical Surveys

Other

COMMENTS

50 YEAR 3 WORK PROGRAM Entire Year 3 program: guaranteed (You must tick a box) non-guaranteed

WELLS YEAR 3 Please identify all test targets for all wells by ticking appropriate boxes Well 1 Well 2 Well 3 Well 4 Well 5 Well 6 Well 7 Well 8 Well 9 Well 10 Eromanga Cooper Warburton

Cost (A$k)

SEISMIC YEAR 3 km/km2 Cost (A$k) 2D Seismic 3D Seismic Seismic Reprocessing

OTHER STUDIES YEAR 3 Cost (A$k) Description Geological & Geophysical Studies

Aeromagnetic Surveys

Geochemical Surveys

Other

COMMENTS

51 YEAR 4 WORK PROGRAM Entire Year 4 program: guaranteed (You must tick a box) non-guaranteed

WELLS YEAR 4 Please identify all test targets for all wells by ticking appropriate boxes Well 1 Well 2 Well 3 Well 4 Well 5 Well 6 Well 7 Well 8 Well 9 Well 10 Eromanga Cooper Warburton

Cost (A$k)

SEISMIC YEAR 4 km/km2 Cost (A$k) 2D Seismic 3D Seismic Seismic Reprocessing

OTHER STUDIES YEAR 4 Cost (A$k) Description Geological & Geophysical Studies

Aeromagnetic Surveys

Geochemical Surveys

Other

COMMENTS

52 YEAR 5 WORK PROGRAM Entire Year 5 program: guaranteed (You must tick a box) non-guaranteed

WELLS YEAR 5 Please identify all test targets for all wells by ticking appropriate boxes Well 1 Well 2 Well 3 Well 4 Well 5 Well 6 Well 7 Well 8 Well 9 Well 10 Eromanga Cooper Warburton

Cost (A$k)

SEISMIC YEAR 5 km/km2 Cost (A$k) 2D Seismic 3D Seismic Seismic Reprocessing

OTHER STUDIES YEAR 5 Cost (A$k) Description Geological & Geophysical Studies

Aeromagnetic Surveys

Geochemical Surveys

Other

COMMENTS

53 PEL APPLICATION CHECKLIST The following information must be included in the licence application: 1. Complete the attached PRO FORMA (use of this form is strongly recommended) and include two copies of a plan of the application area. 2. PRO FORMA application must be signed by individual applicants and if the application is made by a consortium including a company(s) the application must be made under the company(s) seal. 3. If applicant is a foreign company, the company must be registered as a foreign company under the provisions of the Australian Corporations Law. 4. A summary of the technical qualifications of the applicant (or consultants/agents of the applicant). 5. Evidence of the financial position of the applicant to demonstrate ability to fulfil the proposed work program (i.e. the latest annual report or a verifiable statement from an independent accountant/ auditor/financial institution). 6. A statement of exploratory operations the applicant proposes to carry out in each year of the five year term of the licence, including an estimate of exploration expenditure to be incurred in each year of the licence in A$. These details should be included in the proforma supplied in this acreage release brochure. 7. The prescribed fee for each licence applied for, made payable to Primary Industries and Resources South Australia. At writing the application fee was A$2298, however all fees are scheduled to increase on 1 July each year. It is recommended that you check the current fee with PIRSA prior to sending in your application. 8. Please ensure the envelope(s) containing your application(s) are marked ‘CONFIDENTIAL – PEL APPLICATION’.

54 APPLICATION FOR PETROLEUM EXPLORATION LICENCE PETROLEUM ACT, 1940 (SECTION 7)

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

hereby make application for the grant of a petroleum exploration licence in respect of the area described hereunder [please tick block(s) you are applying for]: DESCRIPTION OF AREA Block Tick here Approximate area km2 Acres CO2000-A 2051 506 811 CO2000-B 1508 372 633 CO2000-C 1452 358 796 CO2000-D 1185 292 819 CO2000-E 3314 818 904 CO2000-F* 1163 287 382 CO2000-G* 956 236 232 CO2000-H* 1106 273 297

Please indicate Block(s) under application. Note each Block is offered as a separate licence and the application fee is A$ 2298 per licence. Details in support of the application and the application fee of $ are attached (see Checklist). * Note that applications for blocks CO2000-F, G and H have a later closing date and will attract a new licence application fee which will be determined on 1 July 2000. Contact PIRSA for the amended fee.

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 2000.

CLOSING DATES BLOCKS CO2000-A TO E: 4.00 PM ON THURSDAY 29 JUNE 2000. BLOCKS CO2000-F TO H: 4.00 PM ON THURSDAY 28 SEPTEMBER 2000.

SEND APPLICATIONS MARKED ‘CONFIDENTIAL – CONTAINS PEL APPLICATION’ TO: Director, Petroleum Group Primary Industries and Resources SA Level 7 101 Grenfell St Adelaide SA 5000 Phone: IAC 61 8 8463 3204 AUSTRALIA Facsimile: IAC 61 8 8463 3229

55