prospectivity_eromanga

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EROMANGA BASIN

Links

Tenements ( link to the PIRSA website for the latest information)

Well location map, 1:250 000 scale (PDF;

link to the PIRSA website for the latest information)

Reports

• The petroleum geology of South Australia, Volume 2: Eromanga Basin. 2nd

edn. (Cotton, T.B.,

Scardigno, M.F. and Hibburt, 2006; PDF)

Publications

Acreage releases, previous

Summary

Age Early Jurassic – Late Cretaceous.

Area in South Australia 360 000 km2 (139 000 sq. miles).

Depth to target zones 1200–3000 m.Thickness Up to 3000 m.

Hydrocarbon shows Commercial discoveries of oil from almost every unit from the

Poolowanna to the base Cadna-owie Formation in the Cooper

region; elsewhere shows in the Poolowanna Formation.

First commercial discovery 1976 gas (Namur 1), 1978 oil (Strzelecki 3).

Identified reserves Cooper region only; elsewhere — nil.

Undiscovered resources (50% prob.) 2.4 x 106 kL (15.1 mmbbl); western Eromanga Basin

8.4 x 106kL (52.8 mmbbl) (PIRSA estimate June 1996).

Production Cooper region only — refer to Cooper Basin chapter; elsewhere

nil.

Basin type Intracratonic.

Depositional setting Productive non-marine sequence overlain by non-productive

http://www.pir.sa.gov.au/__data/assets/pdf_file/0003/28551/p01.pdf

http://www.pir.sa.gov.au/__data/assets/pdf_file/0004/92803/203859_002bigblue_all.pdf



http://www.pir.sa.gov.au/petroleum/access_to_data/petroleum_publications/petroleum_geology_of_south_australia/vol_2_-_eromaga_basin_2nd_edition





http://www.pir.sa.gov.au/petroleum/access_to_data/petroleum_publications

http://www.pir.sa.gov.au/petroleum/prospectivity/basin_and_province_information/prospectivity_eromanga


http://www.pir.sa.gov.au/petroleum/prospectivity/basin_and_province_information/prospectivity_eromanga

http://www.pir.sa.gov.au/petroleum/access_to_data/petroleum_publications





Eromanga Basin

Source rocks Underlying Cooper Basin coal and siltstone; Birkhead and

Murta formations’ siltstone and coal.

Depth to oil/gas window 1250 m (oil).

Number of wells ~1980 in Cooper region; ~30 elsewhere.

Seismic line km 104 455 2D; 9736 3D km2 (64662 km)

Structural setting

The Eromanga Basin covers 1 000 000 km2 of central–eastern Australia, 360 000 km

2 of which lie in South

Australia. The Eromanga Basin encloses the multi-aquifer system of the Great Artesian Basin.

In South Australia, the Eromanga Basin overlies late Palaeozoic and older basins. It consists of a broaddownwarp with two main depocentres — the Poolowanna Trough and the Cooper region — containing up to

3000 m of sediment (Figs 1, 2). The central Eromanga Basin is overlain by the Tertiary to Recent Lake Eyre

Basin. Eromanga Basin units crop out extensively on the western and southern margins.

Structurally, the Eromanga Basin is divided into two by the NE-trending Birdsville Track Ridge, a complex of

related domes and ridges. The Poolowanna Trough in the NW contains a thick sand-dominated sequence in

comparison to the Cooper region where intercalated shale and siltstone units occur.

Exploration history

Petroleum exploration commenced in the 1950s when licences covering the Cooper and Eromanga basins

were first acquired by Santos, who went against conventional wisdom that commercial accumulations of oil

would not be found in Mesozoic formations within the Great Artesian Basin.

Initial exploration involved surface mapping, stratigraphic drilling, aerial surveys, gravity and aeromagnetic

surveys and seismic. The first petroleum well was drilled in 1959 and Cooper Basin gas was discovered in

1963.

The first commercial hydrocarbon to flow from the Eromanga Basin was gas produced from Namur 1 in 1976

(Cooper region). Oil was discovered in 1977 with an uneconomic flow from Poolowanna 1 in the Poolowanna

Trough. The first economic oil flow was recorded from Strzelecki 3 (Cooper region) in the following year and

this stimulated a major oil exploration program.

Since 1959 over 1980 wells have penetrated the Eromanga Basin sequence and over 100 000 km of seismic

has been acquired (Fig. 1). Exploration has concentrated in the Cooper region. A new phase of exploration

for oil in the Eromanga Basin commenced in 2002 in the 27 new licences resulting from the expiry of PELs 5

and 6 in 1999. Most new entrant explorers are currently targeting Eromanga Basin oil plays.



Eromanga Basin

In the Poolowanna Trough, the Poolowanna Formation (up to 130 m thick) is overlain by a thick sand-

dominated unit (Algebuckina Sandstone). West of the northern Birdsville Track Ridge, Birkhead and Murta

Formation shales pinch out into Algebuckina Sandstone. Algebuckina Sandstone crops out on the western

and southern basin margin.

The non-marine sequence is succeeded conformably by a sequence reflecting transition from non-marine to

marginal marine to open marine shale and sandstone. The basal unit, Cadna-owie Formation, is of

significance for petroleum exploration as the top of the unit approximates a distinctive seismic reflector — the

C horizon mappable over the entire basin (Fig. 3). PIRSA has compiled a basin-wide C horizon data set from

company seismic maps (Fig. 5). The C horizon mapping now extends into Queensland, Northern Territory

and New South Wales as a result of the National Geoscience Mapping Accord Cooper and Eromanga Basinproject.

The upper non-marine sequence (Winton Formation) was rapidly deposited — up to 1100 m over ~8 million

years. A period of erosion in the Late Cretaceous, caused by a switch in drainage from the Cooper region to

the Ceduna Depocentre on the rifted southern margin, was followed by deposition of the non-marine

Cainozoic Lake Eyre Basin.

Source rocks

Vertical migration of oil from Permian (Cooper Basin) source rocks has been widely accepted as the principal

source of most Eromanga-reservoired oil (in the Cooper region). Both Cooper and Eromanga mature source

rocks have contributed to oil accumulations in the region, however each oil accumulation needs to be

considered on its merits with respect to the extent of mixing from Permian and Mesozoic sources. The

Poolowanna and Birkhead formations contain organic-rich shales that are oil-prone and in places at peak

maturity for oil generation. Lateral migration from these source areas has also been postulated.

Elsewhere in the basin, the presence of thick Poolowanna, Birkhead and Murta formations is critical to

evaluation of oil source potential. The marine sequence and upper non-marine sequence are immature for

hydrocarbon generation over much of the basin. The underlying Simpson and Pedirka basins also contain

mature source rocks and are well placed to charge Eromanga Basin reservoirs.

Reservoirs

Principal reservoirs in the Cooper region are the braided fluvial Hutton and Namur sandstones (porosities upto 25%, permeability up to 2500 mD). Oil is also reservoired in meandering fluvial (Poolowanna and Birkhead

formations), lacustrine shoreface (McKinlay Member) and lacustrine turbidite (Murta Formation) sandstones.

Detailed petrophysical data is available from PIRSA for all of these Eromanga Basin reservoirs. A schematic

section showing typical petroleum traps of the Eromanga Basin is shown in Figure 6.



Eromanga Basin

Trapping mechanisms within the Eromanga Basin are dominantly structural (anticlines with four-way dip

closure or drapes over pre-existing highs) with a stratigraphic component (e.g. Hutton–Birkhead transition,

Poolowanna, McKinlay Member and Murta Formation). Eromanga structures in South Australia are rarely

filled to spill with oil — net oil columns are relatively thin compared to the height under closure (due to poorsealing characteristics).

Seals consist of intraformational diagenetic sandstones, siltstones and shales of the Poolowanna, Birkhead

and Murta formations in the Cooper region. In the Poolowanna Trough, they consist of intraformational

siltstone and shale in the Poolowanna Formation and siltstone of the Cadna-owie Formation. Elsewhere in

the basin, potential seals include the Cadna-owie Formation and Bulldog Shale – Wallumbilla Formation).

Undiscovered resources

As the Eromanga Basin is clearly oil-prone, only undiscovered oil resources are calculated, however gas

discoveries are known from the Cooper region. The gas in these fields has been sourced from the underlying

Permo-Carboniferous Cooper Basin. In the western Eromanga Basin, gas discoveries are possible,

particularly in areas overlying the older infrabasins (Pedirka and Simpson basins), but it is unlikely that small

gas discoveries in this area would be economic.

Petroleum exploration in the Eromanga Basin in South Australia has traditionally concentrated in the portion

underlain by the highly productive Cooper Basin, a relatively mature area. In addition, there is the likelihood

that a significant amount of the oil found in this area has been sourced from the underlying Cooper Basin.

For these reasons, undiscovered oil resources in this area are best estimated using methods that extrapolate

discovery trends.

Areas to the west have had minimal exploration effort, with only one sub-economic discovery. Oil found here

will probably be sourced from the Poolowanna and Birkhead formations or the underlying Pedirka andSimpson basins. Estimates of undiscovered resources in the western Eromanga are best carried out by a

method that uses available geological data and Monte Carlo type statistical techniques to calculate, as a

probability distribution, the undiscovered resources for each play.

Western Eromanga Basin

For a commercial petroleum field to exist in the western Eromanga Basin, four essential components are

required: a mature ‘source’, a ‘reservoir’ horizon, a ‘seal’ horizon and a structure over the reservoir horizonthat will concentrate the petroleum in economic quantities and that was present at the time of the petroleum

expulsion from the source rock. Usually this is an anticline, but stratigraphic traps can also be important.

When all four of these occur together, a petroleum ‘play’ or a potential target for exploration exists.

Maps for each play, taking into account distribution of source, seal and reservoir were constructed. Figure 7



Eromanga Basin

Table 1 Undiscovered recoverable oil resources of the western Eromanga Basin

UNDISCOVERED POTENTIAL106 kL (mmbbl)

Probability that the ultimate potential wil l exceed the stated value:PLAY

90% 50% 10%

Poolowanna 0.2 (1.3) 0.6 (3.8) 1.9 (12.0)

Hutton 0.6 (3.8) 2.4 (15.1) 7.6 (47.8)

Namur–Algebuckina 1.0 (6.3) 4.1 (25.8) 13.0 (81.8)

Total 3.5 (22.0) 8.4 (52.8) 18.6 (117.0)

Note: Totals do not add arithmetically as they are Monte Carlo simulations. Current 1996.

Current projects

A new project to evaluate the coal seam methane potential of the Cooper and Eromanga Basins commenced

in April 2009.

Exploration access

Several National Parks and Wildlife reserves overlie the Eromanga Basin . Exploration is permitted in the

Simpson Desert Regional Reserve, the Innamincka Regional Reserve, the Witjira National Park, Tallaringa

Conservation Park and the Lake Eyre National Park. Exploration is not permitted in the Coongie Lakes

National Park, the Simpson Desert Conservation Park or the No-Go Special Management Zone of the

Innamincka Regional Reserve (Fig. 1).

The initial 2001 right to negotiate (RTN) agreements in the Cooper Basin for the CO-98 PEL application

areas were groundbreaking in Australia as the first conjunctive agreements (covering exploration andproduction) that provide certainty in enabling any explorer, the Aboriginal parties, and the state being able to

benefit from any commercial discoveries made.

The state has also commenced the RTN process for additional PELs in the Eromanga and Arrowie basins

and it is likely that existing RTN agreements will continue to form a practical precedent. Any agreements will

provide for protection of the heritage and cultural interests of the Aboriginal parties.

Compulsory relinquishment of roughly 36% (19 150 km2) of the areas in current Cooper region PELs will

precede competitive bidding from 2009. In anticipation of the calling for work program bids in 2009,

negotiations opened in 2006 to develop a conjunctive Indigenous land access agreement (ILUA) for the

regions already covered with land access agreements resulting from earlier RTN proceedings. These

negotiations involve the Aboriginal Legal Rights Movement, the three native title parties already familiar with



Eromanga Basin

The first conjunctive ILUA in Australia in a proven petroleum province was concluded in February 2007 with

the Yandruwandha–Yawarrawarrka native title claimants over a major portion of the South Australian Cooper

Basin This will provide greater certainty and expedite the grant of PELs in a way that remains fair to native

title claimants and sustainable in relation to exploration and production investment. The application ofconjunctive ILUAs will enable land access more quickly and with lower transaction costs than serial RTN

proceedings. The successful implementation of conjunctive ILUAs for Cooper Basin petroleum exploration

and production will serve as a model for analogous agreements elsewhere in the state.

Negotiations in respect to formalising conjunctive petroleum ILUAs with the remaining two native title

claimant parties in the Cooper Basin are progressing.

In summary, conjunctive ILUAs are proposed as an evolutionary, additional, alternative to the RTN process

already working comparatively well in South Australia. Indeed, conjunctive ILUAs will be an attractive

incentive to achieve competitive bids, with explorers knowing the terms of land access prior to lodging bids.

A number of applications are being held over the western part of the Eromanga Basin pending resolution of

native title issues.

Licence status

Figure 8 shows the licence status at the time of publication. Use this link for further information on holders of

petroleum tenements in South Australia.

Key references

Altmann, M.J. and Gordon, H.M., 2004. Oil on the Patchawarra Flank - some implications from the Sellicks

and Christies oil discoveries. In: Boult, P.J., Johns, D.R. and Lang, S.C. (Eds), PESA’s Eastern Australasian

Basin Symposium II, Adelaide 2004. Petroleum Exploration Society of Australia. Special Publication, pp. 29-

34.

Boult, P.J., Lanzilli, E., Michaelsen, B.H., McKirdy, D.M. and Ryan, M.J., 1998. New model for the

Hutton/Birkhead reservoir seal couplet and the associated Birkhead-Hutton(!) petroleum system. APPEA

Journal, 38(1):724-744.

Cotton, T.B., Scardigno, M.F. and Hibburt, J.E. (Eds), 2006. The petroleum geology of South Australia. Vol.2: Eromanga Basin. 2nd edn. South Australia. Department of Primary Industries and Resources. Petroleum

Geology of South Australia Series.

Gravestock, D.I., Moore, P.S. and Pitt, G.M. (Eds), 1986. Contributions to the geology and hydrocarbon

potential of the Eromanga Basin. Geological Society of Australia. Special Publication, 12.













Eromanga Basin

Nakanishi, T. and Lang, S.C., 2002. Constructing a portfolio of stratigraphic traps in fluvial–lacustrine

successions, Cooper–Eromanga Basin. APPEA Journal, 42(1):65-82.

O’Neil, B.J. (Ed.), 1989. The Cooper and Eromanga Basins, Australia. Proceedings of the Cooper andEromanga Basins Conference, Adelaide, 1989. Petroleum Exploration Society of Australia, Society of

Petroleum Engineers, Australian Society of Exploration Geophysicists (SA Branches).



Eromanga Basin

FIGURES

1. Wells and seismic lines. (203838_053)

2. Schematic section across the Eromanga, Pedirka and Simpson basins. (203838_054)

3. Geological summary of the Eromanga Basin. (203838_055)

4. Base of Eromanga Basin depth structure map. (203838_056)

5. Near top of Cadna-Owie Formation (C horizon) depth structure map. (203838_057)

6. Schematic section showing typical petroleum traps in the Warburton, Cooper and Eromanga basins.

(203838_050)

7. Prospectivity of the western Eromanga Basin: (a) Poolowanna Formation; (b) Hutton Sandstone; (c)

Namur–Algebuckina sandstones. (203838_058)

8. Petroleum and geothermal tenements. (203838_059)





203838_054

O do a Fnadat t m

ERINGATROUGH

EROMANGA

BASIN

POOLOWANNA TROUGH

PATCHAWARRATROUGH

NAPPAMERRI TROUGH

BIRDSVILLETRACK RIDGE

DALHOUSIE –

McDILLSRIDGE

MUSGRAVEBLOCK

PEDIRKABASIN

SIMPSON BASIN

F m

Winton Formation

Mount Howie

Sandstone

QUATERNARY AND TERTIARY

PRE-PERMIAN

INNAMINCKADOMESIMPSON

DESERT

Mount Alexander

Sandstone Member

C o r o i

d

k i a

a n a S n s t o n e

K I L

O M E T R E S ( A H D )

-2

-1

0

-3 COOPER

BASIN

NT/SA SA/QLD

W o o l d r i d e g Li m t e s o ne M e r mbe

Mbr

GROUP

NAPPAMERRI

Namur Sst

?

?

?

?

Drn T.McK

GIDGEALPA –MERRIMELIA –

INNAMINCKA RIDGE

PEDIRKA

BASIN

Western margin of Eromanga Basin

BASIN

BASIN

SIMPSON

COOPER

QLD NT

0 100

KILOMETRES

200

A

B

A B430 km 230 km200 km

VARIABLE HORIZONTAL SCALE

C o

o r i k i a n a S a n

s o

d

e

t n

B u l l d

o g S h a l e

O o d n a d at t a F or mation

M a c k u nda For m a t i o n

C a d n a-owie F m

Al g e b u c k i na Sans t o n e

P e e r a P e e r a F m

P o olo wa n n a F m

W a l k an d i F m

W a l l um billa For ma t i o n

A l l a ru Mudst one

T o o lebucFo r m a t i

o n

H u t t o n S a n d s t o n e

Bi r k h e a d F m

B u l l do g S h a l e

M c K inla yM ur ta F m

W e s t b o u r n e

Sediments with significantCraton-derived materials (reservoirs)

Sediments with significantvolcanic-arc-derived material (seals)

Adori Sst

Figure 2 Schematic section across the Eromanga, Pedirka and Simpson basins.



AGE ROCK UNIT

WEST EAST

TERTIARY

-RECENT LAKE EYRE BASIN

MT HOWIESANDSTONE

1200m

200m

300m

300m

320m

20m

60m

450m

80m

210m

120m

230m

130m

60m

E a r l y

POOLOWANNAFORMATION

HUTTONSANDSTONE

BIRKHEADFORMATION

CADNA-OWIEFORMATION

MURTA FORMATION

BULLDOGSHALE

WINTON FORMATION

WALLUMBILLAFORMATION

OODNADATTAFORMATION

COORIKIANA SS.

TOOLEBUCFORMATION

ALLARU FORMATION

MACKUNDA FORMATION

NAMURSANDSTONE

A L

G E B

U C K I N A

S A N D

S T

O N E

McKinlay Member

WESTBOURNEFORMATION

ADORI SANDSTONE

M i d d l e

J U R A S S I C

L a t e

C R E T A C E O U S

E R O

M

A N G

A

B A S

I N

L A K E E Y R E B A

S I N

( C A L L A B O N N A S U B

- B A S I N )

E a r l y

L a

t e

LITHOLOGY COMMENTSDEPOSITIONAL

ENVIRONMENT

Fluvial and lacustrine

Non-marine to

marginal marine

Marginal marine Regional seal

Oil shale potential

Lenticular sand, variable

reservoir quality

Regional seal to Cadna-owie

Formation

Regional sand sheet

Poor - fair reservoir quality

Fair to excellent reservoir quality.

Predominantly anticlinal traps.

Tertiary structuring has influenced

hydrocarbon migration

Fair source rockThin lenticular sandstones

Potential for stratigraphic

structural traps

Fair reservoir quality

Variable reservoir quality.

Structural-stratigraphic traps.

Oil prone source rocks

Good to excellent reservoir quality.

Predominantly anticlinal traps,

some stratigraphic traps at

Birkhead interface

Strong facies control on reservoirdevelopment. Stratigraphic andstructural trapping of Permiangenerated oil. Oil prone source

Stratigraphic, diagenetic to

structural traps. Variable reservoir

quality. Oil prone source rocks.

Marine

Restricted marine -

stratified and

anoxic

Regressive marineshoreface

Open marine

transgressive

Non-marine tomarginal marine

Lacustrine

turbidites, deltas

Lacustrine shoreface

Braided fluvial,

with intertonguing

lacustrine facies

Aeolian influence

Low energy

meandering fluvial &

overbank floodplain

Braided fluvial

Fluvio-lacustrine

backswamp

Braided fluvial with

aeolian influence

Meandering-

anastomosingfluvial

A

C

H



"

"

"

"

T A R C O O L A

A L I C E S P

R I N G S

S T U A R T

R A I L W A Y

B i r d

s v i l l

e T r

a c k R i d

g e

Officer BasinWarburton Basin

E r i n g

a T r

o u g h

Eromanga Basin

Cooper Basin

H I G H W A Y

Eromanga Basin prospective outline

Cooper Basinsubcrop limit

Arckar inga Bas in

Simpson BasinPedirka Basin

Moomba

Marree

Oodnadatta

Coober Pedy

Lake Eyre North

Lake Eyre South

141°0'E

141°0'E

140°0'E

140°0'E

139°0'E

139°0'E

138°0'E

138°0'E

137°0'E

137°0'E

136°0'E

136°0'E

135°0'E

135°0'E

134°0'E

134°0'E

2 6 ° 0 ' S

2 6 ° 0 ' S

2 7 ° 0 ' S

2 7 ° 0 ' S

2 8 ° 0 ' S

2 8 ° 0 ' S

2 9 ° 0 ' S

2 9 ° 0 ' S

PIRSA 203838_056

BASE OF EROMANGA BASIN

DEPTH STRUCTURE MAP

Eromanga Basin and infrabasinsSouth Australia

Equidistant Conic

0 25 50 km

"

"

Moomba

ADELAIDE

Q U E E N S

L A N D

N E W S O U T H

W A L E S

NORTHERN TERRITORY

PL5

PL9

PL1

PL15

PLs7,8

PL2

Figure 4

Pipeline licence

Gas pipeline

Gas and liquids pipeline

Liquids pipeline

SOUTH AUSTRALIA

PL18

PL17

4500

METRES

90



"

"

"

"

T A R C O O L A

A L I C E S P

R I N G S

S T U A R T

R A I L W A Y


E r i n g

a T r

o u g h

Eromanga Basin

Cooper Basin

H I G H W A Y


Cooper Basinsubcrop limit

Arckar inga Bas in


Moomba

Marree

Oodnadatta

Coober Pedy

Lake Eyre North

Lake Eyre South

141°0'E

141°0'E

140°0'E

140°0'E

139°0'E

139°0'E

138°0'E

138°0'E

137°0'E

137°0'E

136°0'E

136°0'E

135°0'E

135°0'E

134°0'E

134°0'E

2 6 ° 0 ' S

2 6 ° 0 ' S

2 7 ° 0 ' S

2 7 ° 0 ' S

2 8 ° 0 ' S

2 8 ° 0 ' S

2 9 ° 0 ' S

2 9 ° 0 ' S

PIRSA 203838_057

NEAR TOP OF CADNA-OWIE FORMATION

('C' HORIZON) DEPTH STRUCTURE MAP


Equidistant Conic

0 25 50 km

"

"

Moomba

ADELAIDE

Q U E E N S

L A N D

N E W S O U T H

W

A L E S

NORTHERN TERRITORY

PL5

PL9

PL1

PL15

PLs7,8

PL2

Figure 5

ipeline licence

Gas pipeline


Liquids pipeline

SOUTH AUSTRALIA

PL18

PL17



Source rock

203838_050

Shale

Gas Sandstone

Oil Carbonate

Cenozoic

LAKE EYRE

BASIN

COOPER

BASIN

WARBURTON

BASIN

Jurassic-

Cretaceous

Permo-

Triassic

Cambro-

Ordovician

EROMANGA

BASIN

1000

2000

3000

metres

Figure 6 Schematic section showing typical petroleum traps in

the Warburton, Cooper and Eromanga basins.



QLD NT 139 141135

27

29

137

Optimistic area

Most likely area

PROSPECTIVITY ESTIMATE

L i m i

t o f T o

o l a

c h

e e F

o r m a

t i o

n

Cooper regionexcluded

99-0167

KILOMETRES

0 100

Poolowanna 1

Mokari 1MountHammersley 1

Tirari West 1

Kalladeina 1

Koonchera 1

Putamurdie 1

QLD NT 139 141135

27

137

Poolowanna 1

Mokari 1MountHammersley 1

TirariWest 1

Kalladeina 1

Koonchera1

Putamurdie 1

Lim i t

o f T o

o l a

c h

e e F

o r m a

t i o

n

KILOMETRES

0 100

(a)



"

"

"

"

T A R C O O L A

A L I C E S P

R I N G S

S T U A R T

R A I L W A Y


E r i n g a

T r o u g h

Eromanga Ba sin

Cooper Basin

H I G H W A Y

Simpson Desert (CP)

Elliot Price (CP)

Wabma KadarbuMound Springs (CP)

Coongie(NP)


EE

Arckar inga Bas in


Marree

Moomba

Oodnadatta

Coober Pedy464

160

335

159

333

288

334

331

71

77

289

290

332

511

515

512

514

133

516

512

515

146

516

513

513

516

522

513

514

518

516

517

514

516

101

516

516

101101

101

123

121

117

119

122

118

424

96

88

87

499

95

182

91

92

94

444

11293

218500

183

111

90

124

110

101

106

107

113 114

104

100

103

105138

115

102 287

394396

393 395

398 399 400

397

402 401 403 404

502

508 406 405

362 364355

347 346

357

195 204192 198 201

361

267 323

359 360

272

169

356

358

193 196 205199 202

268

319

390 283

276

191 197

200194 203

316

383

317

264

352

388

282

269

275

391

271

348

185

392

386

369370

367 366 368

373

354

382

375

385

236374

384376

221

379

281

211

365363

238

310

322378

380

220

320

371

237

372

324

273

274

387

318

270

265

389

277

284

309

377

381

Lake Eyre North

Lake Eyre South

141°0'E

141°0'E

140°0'E

140°0'E

139°0'E

139°0'E

138°0'E

138°0'E

137°0'E

137°0'E

136°0'E

136°0'E

135°0'E

135°0'E

134°0'E

134°0'E

2 6 ° 0 ' S

2 6 ° 0 ' S

2 7 ° 0 ' S

2 7 ° 0 ' S

2 8 ° 0 ' S

2 8 ° 0 ' S

2 9 ° 0 ' S

2 9 ° 0 ' S

PIRSA 203838_059

PETROLEUM and

GEOTHERMAL TENEMENTS


Equidistant Conic

0 25 50 km

"

"

Moomba

ADELAIDE

Q U E E N S L A N D

Petroleum tenements

Petroleum exploration licence (PEL)

Petroleum exploration licence application (PELA)

Petroleum production licence (PPL)

Petroleum production licence application (PPLA)

eothermal tenements

Geothermal exploration licence (GEL)

Geothermal exploration licence application (GELA)

Geothermal retention licence (GRL)

N E W S O U T H

W

A L E S

NORTHERN TERRITORY

PL5

PL9

PL1

PL15

PLs7,8

PL2

Figure 8 Parks with no petroleum exploration access

Pipeline licence

Gas pipeline


Liquids pipeline

SOUTH AUSTRALIA

PL18

PL17

Date post:	03-Jun-2018
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