A long read.
The Directors
Central Petroleum Limited
Suite 3
Level 4 Southshore Centre
85 The Esplanade
South Perth WA
6151
Dear Sirs,
At your request I have prepared the following Independent Geologist's Report for
consideration by the board of Central Petroleum Limited in respect of farm-in opportunities in
your newly acquired Pedirka Basin acreage, with the emphasis on non-conventional
hydrocarbon accumulations.
The report covers Exploration Permits (Applications)( EPA's) 105,106 and 107, all of
which are included in an arrangement with Traditional Oil Pty Ltd for purchase thereof by
Central. This report should be read as an addendum to the previously submitted report on your
existing Pedirka Basin tenements,"The Unconventional Petroleum Potential of EP 93 and
EPA's 130&131 and PELA 77 Pedirka Basin Onshore Northern Territory and South Australia
Australia".
Jack N. Mulready
Director/Principal
Mulready Consulting Services Pty Ltd
Services: Petroleum Exploration Planning & Management Petroleum Exploration & Development Geology
Permit
Valuations Reserves Estimates
Basin
Studies Economic Evaluation
Prospect & Permit Evaluations Wellsite Supervision
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THE UNCONVENTIONAL PETROLEUM POTENTIAL OF
EPAs 105, 106 & 107
PEDIRKA BASIN
ONSHORE NORTHERN TERRITORY
AUSTRALIA
21st June2007
( Addendum to "The Unconventional Petroleum Potential of EP 93 and EPA's 130 & 131
and PELA 77 Pedirka Basin Onshore Northern Territory and South Australia Australia.
Mulready Consulting Services Pty Ltd )
R.A MEANEY
MULREADY CONSULTING SERVICES PTY LTD.
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EXECUTIVE SUMMARY
1. Central Petroleum Limited, in their own right, have recently acquired from Traditional
Oil Pty Ltd EPA's (Applications) 105, 106 and 107 in the Northern Territory subject to
granting of the Permits and various payments. The company also controls EP 93 and
have the sole rights to EPA's (Applications) 130 and 131 in the Northern Territory and
PELA (Application) 77 in South Australia.
2. The newly acquired tenements cover most of the western sector of the potentially
prospective, but under explored, Pedirka Basin of central Australia, as well as the
overlying and underlying sedimentary sequences. Refer Figure 1b)
3. Studies by the company and the relevant state Departments of Minerals and Energy
have highlighted the conventional hydrocarbon prospectivity of these tenements.
4. Work by the company, which has been confirmed by this report, has identified
substantial prospectivity for the presence of, and the potential to develop, non-
conventional hydrocarbons in the company's three new tenements, as well in the four
other Pedirka Basin tenements that they currently control. The unconventional petroleum
potential of these four tenements is detailed in an earlier report.
5. It is estimated that an Original Gas in Place (OGIP) Prospective Resource of
approximately 25.4 TCF of coal bed methane could be present in Central's newly
acquired Pedirka Basin acreage in Permit Application areas EPA 105, 106 and 107. Of
this some 17.1 TCF is believed to be hosted in the Permian aged Purni Formation of the
Pedirka Basin sequence and some 8.3 TCF is thought to be present in the Triassic aged
Peera Peera Formation of the overlying Simpson Desert Basin sequence. As detailed in
the earlier report on EP 93, EPA'S 130 &131 and PELA 77, the corresponding value for
the company's previously held four tenements is 67.4 TCF. Hence the relevant OGIP
values for the Company's 7 Pedirka Basin permits in prospective resources is 92.8
TCF.
6. It is thought that the total estimated recoverable prospective hydrocarbon resource
possibly hosted in EPA's 105, 106 and 107 in the "low", "best" and "high" deterministic
cases are 9, 13 and 19 TCF assuming recoveries of 35%, 50% and 75%, respectively.
The corresponding values for EP 93, EPA's 130&131 and PELA 77 are 25, 34 and 51
TCF respectively. Hence the relevant values of recoverable prospective resources
for all of Central's 7 Pedirka Basin blocks are 34, 47 and 70 TCF.
7. According to Holt Campbell Payton, typically a GTL plant will require about 10
thousand standard cubic feet of gas (mSCF) to synthesize one barrel of oil. Hence the
"high" indicative possible resource anticipated in the company's newly acquired Pedirka
Basin acreage, 19.0 TCFG, could produce some 1,900 million barrels of liquids. This is
in addition to the 50.6 TCFG or 5,060 million barrels of liquids which could be present in
the company's other Pedirka Basin permits, as detailed in the earlier report.
Consequently Central's entire Pedirka Basin acreage package could possibly
produce some 70 TCFG or approximately 7,000 million barrels of ancilliary
petroleum liquids based on "high" prospective recoverable resources.
8. The entire Pedirka Basin acreage with "low", "best" and "high" estimates of
recoverable prospective resources could conceivably fuel a 140,000 bbl/day GTL
plant for 70 years, 100 years and 150 years.
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9. Central's Pedirka Basin acreage is known to contain extensive Permian and Triassic
coal measures and carbonaceous shales, correlatives of which are known to have
sourced the gas accumulations in the Cooper Basin and the oil accumulations of the
overlying Eromanga Basin, adjacent and overlying basins respectively. These coals
have considerable potential for coal bed methane drainage. These source beds, which
contain Type 2 or oil prone macerals, could also have sourced conventional hydrocarbon
accumulations.
10. The acreage also contains section within the underlying Amadeus Basin Sequence
which may be prospective for "basin centred gas accumulations" in the tight and dirty
Horn Valley Siltstone.
11. Given the knowledge of the central Australian petroleum systems the overlying
Mesozoic aged Eromanga Basin has potential for oil accumulations as a consequence of
late generated gas displacing oil up-dip.
12. Central have plans for the establishment of one or more large scale gas to liquids
(GTL) synthesis plants, probably located in Alice Springs for strategic reasons, given the
proving up of appropriate reserves. Future potential for coal to liquids processing also
exists.
13. Such plants would use the latest variant of the Fischer-Tropsch reaction to produce
liquids, which could include ultra-clean dieseline, jet fuel and naphtha.
14. Given the company's extensive acreage in the Pedirka Basin,and in central Australia
in general, should the company's plans come to fruition, then they should become the
dominant player in a large scale gas and or coal to liquids industrial process in central
Australia.
15. It is known that markets, both locally and internationally, exist for clean liquid
petroleum products, which could include ultra-clean diesel, jet fuel and naphtha. These
markets are substantial and are under-supplied. Other by products of the hydrogenation
process also have a ready market in the chemical industry.
16. Markets for the disposal of sales gas may also exist in southern and eastern
Australia if gas sales prices rise to sufficient levels.
17. It is considered appropriate that conventional and non- conventional exploration be
conducted simultaneously, as far is as possible, in the initial stages of exploration in the
permit areas. This should be a natural occurrence.
18. Besides an exploration program, additional analytical studies will be required to
accurately estimate the likely potential resources present in the company's acreage.
19. Indeterminate potential also exists in the Poolowanna Formation of the Eromanga
Basin sequence, probably not as widespread.
20. This report is directed at the recently acquired acreage from Traditional Oil Pty Ltd,
EPA's 105, 106 and 107 permit applications which straddle the Pedirka/Amadeus Basin
boundaries but are thought to include some 8,000 km2 of Permian and probable Triassic
coal horizons.
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LIST OF CONTENTS
EXECUTIVE SUMMARY
1. RATIONALE OF REPORT
1.1. General
1.2. Strategy
1.3. Prospectivity
2. INTRODUCTION
3. TENEMENTS
4. METHODOLOGY
5. THE COMPANY
6. PREVIOUS EXPLORATION
7. GEOLOGY
7.1. Regional Geology
7.2. Tectonic Setting
7.3.
Stratigraphy
8. PETROLEUM GEOLOGY
8.1. Source Rocks
8.2. Maturity
8.3. Reservoirs
8.4. Sealing Units
8.5. Traps
9. COAL BED METHANE DRAINAGE
10. COAL TO LIQUID CONVERSION
11. COAL TO GAS PROCESSING
12. UNDERGROUND GASIFICATION
13. FRACTURE STIMULATION
14. UNTESTED PLAYS
15. POTENTIAL UNDISCOVERED RESOURCE
15.1 Indicative undiscovered target size
16. RISKS
17. RECOMMENDATIONS
18. CONCLUSIONS
19. SELECTED REFERENCES
DECLARATIONS
LIST OF FIGURES
Figure 1 Company's Acreage Holdings Map
Figure 2 Infrastructure Map
Figure 3 Pedirka Basin Cross Section
Figure 4 Pedirka Basin Acreage and Tectonic Elements Map
Figure 5 Combined Stratigraphic Column
Figure 6 Map of Purni coal above 1,250m
Figure 7 Map of Peera Peera coal above 1,250m
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Figure 1a. Central Petroleum acreage holdings map
1.0 RATIONALE OF REPORT
This Report was commissioned by Central Petroleum Limited, ABN 72 083 254 308 in June
2007 and it should be read as an addendum to a previously submitted report on the
unconventional petroleum potential of adjacent permits, EP 93, EPA's 130&131 and PELA
77.
This preliminary study reports upon the potential for the discovery and commercial production
and marketing of unconventional petroleum accumulations in undiscovered prospective
resources at "high, low and best" deterministic levels in accordance with the SPE guidelines
preferred by the ASX. The study also comments on the potential for the utilization of gas to
liquids (GTL) technology and processes in central Australia, detailed in a report appended to
the main body of the earlier report prepared by consulting engineers Holt Campbell and
Payton Pty Ltd (Holt Campbell Payton).This report does not attempt to produce profit
forecasts for Central Petroleum Limited and should not be relied upon as a basis for
investment in Central Petroleum Limited.
This report is intended for those persons who may have an interest in examining the
potential for the commercial development of GTL plants in central Australia as joint
venture or farmin partners.
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The authors are competent persons with appropriate qualifications and relevant experience
and the assumptions used and the conclusions reached in this report are considered by them
to be based on reasonable grounds and appropriate for the scope of the assignment.
The report has drawn upon a number of sources including the statement of potentially
recoverable hydrocarbons in the Amadeus and Pedirka Basins provided by the Independent
Geologists, Mulready Consulting Services Pty Ltd, who have consented to the use of data
drawn from their Independent Geological Report included in the Central Petroleum
prospectus dated 12th September 2005, Pre-feasibility Study for a 10,000 bbl/day FT GTL
Plant in Central Australia with notes on 50,000 bbl/day and 140,000 bbl/day options by Holt
Campbell Payton, March 2006 and March 2007, who have also consented to the use of their
reports. Reference was also made to "The Unconventional Hydrocarbon Potential of EP 93
and EPA'S 130&131 and PELA 77 Pedirka Basin Onshore Northern Territory and South
Australia Australia". Mulready Consulting Services Pty Ltd. Public domain data available from
the Northern Territory and South Australia Geological Surveys, and other sources last
reviewed in February 2007 was also utilized.
Estimations of plant costs and other costs such as gas production are likely to escalate over
time, new and improved technology is likely to be developed and no forecasts of oil prices
other than accepted investment community generalizations can be made, nor is attempted.
The conclusions reached in this report are based on market conditions and technical
knowledge at the time of writing and as such may not be relied upon as a guide to future
developments, nor do the authors take any responsibility for commercial decisions that may
be made on the basis of this report.
This is a scoping study aimed at defining potentially recoverable, but un- discovered,
prospective resources and viable uses of gas resources that may be discovered in central
Australia in Central Petroleum Limited's newly acquired acreage.
At the time of presentation of this report, Central Petroleum Limited does not own nor control
any drilled petroleum resources in central Australia nor has any drilling yet been undertaken
by Central Petroleum Limited.
2.0 INTRODUCTION
2.1 General
Central Petroleum Limited has requested Mulready Consulting Services Pty Ltd to provide an
independent report on the potential for non-conventional hydrocarbon accumulations in its
newly acquired Pedirka Basin holdings, EPA's 105, 106 and 107. This is in addition to the
company's other holdings in the Pedirka Basin, which are covered in an earlier report, " The
Unconventional Petroleum Potential of EPA 93 and EPA's 130 & 131 and PELA 77 Pedirka
Basin Onshore Northern Territory and South Australia Australia".
Central Petroleum Pty. Ltd (Central) is a recently formed public company with the objective of
exploring for, developing, producing and commercializing hydrocarbon accumulations, both
conventional and non-conventional, i.e. coal bed methane (CBM), underground coal gasification
(UCG), and tight gas reservoirs in their under-explored central Australian acreage in the
Northern Territory (NT) and South Australia (SA).The prime focus is on the Permian aged
Pedirka Basin: however there is also potential in the overlying and underlying basins. Central
also is examining potential for value adding to production options such as gas to liquids (GTL)
and possibly coal to liquids (CTL) transformations to produce a range of liquid petroleum
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products such as dieselene, jet fuel and naphtha. The coal rich Pedirka Basin is of particular
interest in non-conventional gas resources (CBM and basin centred gas accumulations), CTL as
well as conventional hydrocarbon reservoir types.
Although there is significant potential for both conventional and unconventional hydrocarbon
resources, for CBM alone, undiscovered recoverable Prospective Resources (SPE definition)
thought to be hosted in EPA's 105,106 and107 are as tabled in below.
BASIN LOW ESTIMATE BEST ESTIMATE HIGH ESTIMATE
Pedirka (Permian) 6.0 TCF 8.6 TCF 12.8 TCF
Simpson Desert (Triassic) 2.9 TCF 4.2 TCF 6.2 TCF
TOTAL 8.9 TCF 12.8 TCF 19.0 TCF
Table 1 CBM Possible Recoverable Resources -Trillions of Cubic Feet of gas (TCF)
EPAs 105, 106 and 107 only
It should be noted that this is in addition to the prospective resources likely to be hosted in the
company's other Pedirka Basin tenements, EP 93, EPA's 130& 131 and PELA 77, which are
also listed below.
BASIN LOW ESTIMATE BEST ESTIMATE HIGH ESTIMATE
Pedirka (Permian) 15.6 TCF 22.3 TCF 33.5 TCF
SimpsonDesert (Triassic) 8.0 TCF 11.4 TCF 17.1 TCF
TOTAL 23.6 TCF 33.7TCF 50.6 TCF
Table 2 CBM Possible Recoverable Resources - Trillions of Cubic Feet of gas (TCF)
EP 93, EPAs 130, 131 and PELA 77
Hence the corresponding values for all 7 of Central's Pedirka Basin blocks are as listed
below.
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BASIN LOW ESTIMATE BEST ESTIMATE HIGH ESTIMATE
Pedirka (Permian) 21.6 TCF 30.9 TCF 46.3 TCF
SimpsonDesert (Triassic) 10.9 TCF 15.6 TCF 23.3 TCF
TOTAL 32.5 TCF 46.5 TCF 69.6 TCF
Table 3 CBM Possible Recoverable Resources - Trillions of Cubic Feet of gas (TCF)
EP 93, EPAs 130, 131, 105, 106 and 107 and PELA 77
The calorific value of these resources is anticipated to be relatively high compared to many
other CBM resources due to the oil prone nature of the coal source rocks, which are known to
contain fresh water Type 1 and Type 2 macerals. These rocks have high exinite to vitrinite ratios
compared to source rocks in other basins, such as the Cooper Basin, and as such these source
rocks are considered to be oil prone.
Although there is generally a paucity of information, an indicative "factory gate" delivered cost
inclusive of exploration, development and production is thought to be approximately A$ 2.00 per
thousand cubic feet of gas (mSCFG) for a centrally located GTL plant in the Pedirka Basin. This
price is expected to be higher, due to piping costs, at A$2.20/mSCFG for a GTL plant located in
Alice Springs. These indicative costings are highly volume dependent but would probably
support a very large scale GTL plant at oil prices prevailing above US$ 30, according to Holt
Campbell Payton, Consulting Engineers of Perth. Such volumes, of course, could also be
available to service gas markets on the eastern seaboard subject to prevailing market
conditions. Markets for the sale of sales gas do exist in southern and eastern Australia.
According to Holt Campbell Payton, typically a GTL plant will require about 10 thousand
standard cubic feet of gas (mSCF) to synthesize one barrel of oil. Hence the "high" indicative
possible resource anticipated in the company's newly acquired Pedirka Basin acreage, 19.0
TCFG could produce some 1,900 million barrels of liquids. This is in addition to the 50.6 TCFG
or 5,060 million barrels of liquids which could be present in the company's other Pedirka Basin
permits, as detailed in the earlier report. Consequently Central's entire Pedirka Basin acreage
package could contain some 69.6 TCFG or approximately 6,960 million barrels of ancilliary
liquids.
Figure 1.b Central's acreage in detail
The possible resource in EPA's 105, 106 and 107 could conceivably sustain a GTL plant
producing 140,000 barrels of liquid GTL products per day for about 37 years. It is assumed,
reasonably, that each well would average 0.25 million cubic feet of gas per day (MMCFD),
hence some 560 producing wells would be required to feed a GTL plant of this capacity. This is
a considerable capital outlay which would entail a major drilling campaign. If Central's program
is successful, then with a large scale development drilling program the cost per well would fall
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markedly due to the reduced mobilization costs. For such a large scale drilling program Central
could further reduce their costs by purchasing drilling rigs and sub contracting the manning of
them to an established drilling contractor. Similarly, for a 140,000 bbl/day output plant, the best
estimate of 12.8 TCF would sustain a 27 year operation and the low case of 23.6 TCF, a 13
year plant life. The Company would of course plan on bringing all potential gas production from
the other permits together with EPAs 105,106 and 107 to give a combined total of 33 TCFG, 47
TCFG and 70 TCFG for the prospective recoverable resource figures which would
conceivably give a 140,000 bbl/day GTL operation plant lives of 70 years, 100 years and
150 years at "low", "best" and "high" estimates of prospective recoverable resources.
2.2 Strategy
As part of its strategy, commencing in 1998 when oil prices were US$ 12/bbl, the Company
acquired four contiguous and very prospective tenements in the onshore Pedirka Basin of
Central Australia. These permits are located in far southeastern NT and far northern SA, as
shown in Figures 1, 2 & 4, the company's acreage holdings and infrastructure maps,
respectively. This acreage has been augmented by the recent purchase of EPA's 105, 106 and
107, the subject of this report. The company also has other extensive interests in the adjacent
Amadeus Basin.
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Figure 2 Infrastructure Map, current and possible developments
In the short term, Central aims to develop early cash flow via the discovery and development of
and production from conventional oil targets, for example, the Blamore and Avalon Prospects in
EP 93 which are reported by RPS Energy to have prospective recoverable resources at "best"
estimate of c.60 MMbbls and the Guinevere and Madigan leads reported by Robsearch to have
potential for "best" recoverable prospective resources of 275 MMbbls. However the company
has also examined the potential for GTL for a range of plant sizes from 2,500-10,000-50,000
bbl/day plant options located at Alice Springs and fed by conventional gas reservoirs.
However Central's longer term strategy in the Pedirka Basin involves the search for both
conventionally and unconventionally reservoired gas to feed larger scale GTL plants.
Additional reserve based asset acquisition, to grow the company, will also be considered by the
company.
Whilst the Pedirka Basin is not yet productive of hydrocarbons, significant indications of
hydrocarbons and minor recoveries had been made in wells drilled for conventionally
reservoired hydrocarbons, in this sparsely explored basin, for example at Colson 1 and
Poolowanna 1, the locations of which are shown on Figure 3, a schematic cross section.
Indications of hydrocarbons were also encountered in the overlying Triassic aged Simpson
Desert Basin in the latter well.
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Figure 3 Schematic cross section of Pedirka Basin
To date no effort has been made to search for or to develop non-conventional hydrocarbon
accumulations in this area, although similar aged sedimentary section sustains commercial
production of non-conventional hydrocarbons in Queensland (QLD) and New South Wales
(NSW). Rocks of a similar age, genesis and lithology are productive of conventional
hydrocarbons in SA, QLD and NSW. Rocks of an older age, which underlie the Permian section
of the Pedirka Basin sequence sustain oil and gas production in the Mereenie and Palm Valley
Fields, respectively, of the Amadeus Basin in the Alice Springs area of the NT. Rocks of the
Amadeus Basin sequence are probably present in all seven of Central's Pedirka Basin blocks.
Markets for hydrocarbons, either conventionally or non-conventionally reservoired, exist.
Eastern and southern Australia faces a looming shortfall in gas supply. Oil, and/or other liquid
petroleum products such as diesel, jet fuel and naphtha, whether of a natural or synthetic
genesis, are readily saleable, particularly with the current high oil prices of over US$ 45/bbl.
These prices are expected to prevail in the foreseeable future.
Central has prepared, or has had other consultants prepare, reports on the conventional
hydrocarbon prospectivity of their permits. Accordingly this will not be discussed in depth in this
report. Central have plans for an initial 6 well drilling programme, in their Pedirka Basin and
Amadeus Basin permits, to target prospective recoverable resources of 3.4 TCF of gas, 105
BCF of Helium and 300 MMBBLS of oil.
In addition to the chances of discovering and producing conventional hydrocarbons from the
Pedirka Basin, Central is also drawn to the basin by the large potential coal resource known to
be present. Intersections of extensive coal intervals have been encountered in some oil
exploration wells drilled in the basin and ubiquitous coal horizons are identified on seismic data
acquired in the basin. The company is investigating little utilized, but known and proven,
techniques of producing gas and oil from the extensive coal measures and possibly
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carbonaceous shales present in their acreage. These processes include:-
7 Coal bed methane drainage
7 Gas to liquids synthesis
At a later date, if applicable, the company will consider other options, if appropriate, including:-
7 Coal to liquids processing
7 Underground coal gasification
7 Coal mining for hydrogenation
7 Fracture stimulation of tight, gas saturated intervals
Whilst there is no infrastructure present in the area at this time to transport any produced
hydrocarbons from the area of Central's permits, the magnitude of the potential hydrocarbon
resource and expected production rates could sustain the construction of high pressure gas
pipelines or dual phase gas and liquids pipelines to new facilities. In the short term, to ensure a
speedy cash flow, any liquids produced, from either conventional or small scale development of
non-conventional sources, could be trucked to the Alice Springs to Darwin rail line and thence
direct to port facilities at Darwin for export or domestic consumption.
The existing adjacent infrastructure including rail links to Darwin and existing oil and gas
pipelines present is shown in shown in Figure 2, an infrastructure map.
Large volumes of gas, if discovered or synthesized, could be sold directly, subject to prevailing
market conditions. This to would involve the construction of a new a high pressure gas pipeline
to existing facilities in the Cooper Basin and subsequent transmission into the national gas
pipeline grid which interconnects South Australia with Queensland, New South Wales, the
Australian Capital Territory, Victoria and Tasmania. Similarly, this gas could be transported by a
potential pipeline to connect with the Alice Springs to Darwin pipeline for local sale in the "Top
End "or for compression and export. These pipelines are also shown in Figure 2.
Markets, either national or export, appear to exist for any hydrocarbons produced from the
Pedirka Basin acreage, whatever their genesis.
2.3 Prospectivity
The results of the study to prepare this report have established that the onshore Pedirka Basin
fulfils all the requirements for the hosting of hydrocarbon accumulations, namely:-
7The presence of rich, mature, source rocks, with some liquids generating
potential
7
The presence of reservoir quality rocks and carrier beds
7
The presence of sealing units
7
The presence of traps, both of a structural and stratigraphic genesis
7The presence of thick and widespread coal beds for methane adsorption, at
appropriate depths
The source rocks mentioned above could source either conventional or non-conventional
hydrocarbons. They could also have generated oil and or wet gas, and with deeper burial,
dry gas
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It is the author's view that, to the present, the lack of commercial exploration success and
production from the area of Central's newly acquired permits has been due to the lack of
seismic coverage and the sparsity of drilling, and in some cases the lack of drilling, as well
as the perceived distance from existing facilities. Another factor is that dating back to 1963
when Santos and Total were in a joint venture exploration over the area, commercial gas
was discovered at Gidgealpa 3 in the Permian section and the exploration focus of the two
companies shifted exclusively to the Cooper Basin sequence. The oil price slump in 1986,
followed by the stock market crash of October 1987 also made fundraising for juniors
engaged in exploration very difficult for many years. Finally, the lack of infrastructure before
the rail link to port facilities at Darwin was completed in 2004 coupled with low oil prices up
until recently meant that the monetisation of gas in particular (via GTL) but oil as well would
have been difficult.
However, the size of Central's intended targets, and the proposed associated exploration
and development projects, if successful, will counteract these previous constraints. The
intention to produce synthetic crude oil and then refined liquid products from either gas or
coal is particularly innovative and may ensure the development of a large, known, but un-
utilized, coal, and possibly methane resource. It also must be remembered that globally, oil
consumption is increasing, with Western countries importing increasing volumes of oil.
3.0 TENEMENTS
Central holds seven petroleum exploration permits over the area of the Pedirka Basin. Four
of these, EP 93, EPA's 130 &131 and PELA 77 are discussed in the earlier, previously
mentioned report, to which the reader is referred. The three permits which are the subject of
this report, EPA's 105, 106 &107 are all located in the south east of the Northern Territory
(NT) (Figure 1b..
In all cases the permit tenure is of 5 years duration and is renewable, with a fifty percent
relinquishment at the end of each 5 year period. The awarding also involves the rights to any
coal bed methane as well as conventionally reservoired gaseous and liquid hydrocarbons. If
any commercial discovery is made, the operating company, and any Joint Venture partners
are automatically granted a 21 year Production License over the discovered field. This
Production License is renewable for the life of the field. In the event of a non-commercial
discovery the company can apply for a Retention Lease over the field. This Lease is of 5
years duration and is renewable at the discretion of the Authority.
The right to explore for and to mine and develop coal is held by the holders of any
superimposed coal exploration tenements but it is believed that the Company's rights to
develop any CBM will prevail over any, most unlikely efforts, to mine coal for export. This
results from the huge distances required for the transport the coal to suitable ports, and the
depth of burial of this relatively low value commodity. This issue will ultimately have to be
resolved by negotiation.
Recently the company has concluded an arrangement with Traditional Oil Pty Ltd
(Traditional) to purchase that company's Pedirka Basin acreage. This purchase, which will
give Central control of most of the Pedirka Basin acreage, involves EPA's 105, 106 and 107.
EPA 105 covers some 185 graticular blocks or approximately 14,000 square kilometres,
whereas EPA 106 extends over 61 graticular blocks or 5,000 square kilometres, and finally
EPA 107 encompasses 91 graticular blocks or some 7,000 square kilometres. Hence the
company has gained another 26,000 square kilometres of ground in Central Australia. The
newly acquired tenements are located to the west of Central's currently held acreage, with
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the north west corner of the acreage package located only some 20 kilometres east of Alice
Springs.
The recently acquired three blocks will be owned by Merlin Energy Pty Ltd, a wholly owned
subsidiary of Central. After the settlement of the purchase Traditional will hold a 1.25% gross
production royalty over the three blocks in question, after the deduction of transport costs
and other costs from the well head to the point of sale allowable under the Petroleum Act.
Since the preparation of the earlier report and this report, Central have signed a
Memorandum of Understanding (MOU) with Petroleum Exploration Pty Ltd for a farmout to
the latter company. The farminee plans to farm into all 18 of Central's tenements on a 2 for 1
basis by funding 40% of the expenditure to earn 20% of the tenement. This expenditure is
capped at a maximum of $3million of seismic and three wells in each Permit. This MOU is to
planned to be ratified by the board of each company in a formal farmout agreement by the
end of June 2007.
The initial exploration targets were conventionally reservoired hydrocarbons, in this
prospective, but under-explored, basin. However these permits are also prospective for
unconventional hydrocarbon exploration, due to the presence of extensive coal measures.
Correlatives of these coal measures are known to be ``gassy" and productive of coal bed
methane in similar aged section in other basins of eastern and central Australia. Hence the
company has decided to explore for both conventional and non-conventional resources
simultaneously. It is expected that oil prospects will be the initial targets. This report will only
address non-conventional hydrocarbons.
A thick siltstone, the Horn Valley Siltstone, which, where drilled to date in the Amadeus Basin
has been gas saturated, is also postulated to be present over a wide, area under, the
Permian Pedirka Basin sequence, and due to its affinity with "basin centred gas
accumulations", it may be a good candidate for fracture stimulation and gas production.
Central plans to evaluate this unit also, during the drilling of wells aimed at overlying targets.
4.0 METHODOLOGY
The basis of this report was an open file study of much of the data available on the onshore
Pedirka Basin (Permian) in both the Northern Territory and South Australian sectors of the
basin, although reference was made to the underlying Amadeus Basin (Devonian and older)
and overlying Simpson Desert (Triassic) and Eromanga (Jurassic) Basins. Some internal
reports provided by Central were also utilized and one of these by Holt Campbell Payton was
relied upon for comments on GTL and CTL fundamentals, as were presentations from
Syntroleum of Tulsa, Oklahoma, Rentech Inc. and the Japan Oil and Gas National
Corporation. The reader is referred to these reports. Knowledge in the possession of the
author of coal bed methane drainage in NSW and QLD was also included as was his
knowledge of conventional exploration in NSW, QLD, NT and SA. Publications on coal bed
methane exploration, development and production were also referred to.
5.0 THE COMPANY
As indicated by the name, Central is a company focused on the hydrocarbon potential of
central Australia. It is a new public company with extensive acreage holdings in the
sedimentary basins of central Australia. Currently Central operates over 226,000 square
kilometres of ground in granted permits and applications, of which 26,000 square kilometres
relates to the newly acquired tenements, EPA's 105, 106 and 107. Hence it has a strong
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acreage position. It has objectives to produce both conventional and non-conventional
hydrocarbons from these prospective but under-explored basins. The company has
innovative plans to develop and produce hydrocarbons from a potentially large, long known
but un-utilized coal resource.
Given the company's extensive acreage holdings, if their programs are successful, they will
control much of central Australia's future hydrocarbon production, particularly in the Pedirka
Basin. The company has innovative and far-sighted plans to develop a potentially huge, non-
conventional hydrocarbon resource in a time of energy shortage. Their plans for the
synthesis of liquid hydrocarbons from coal and or gas are particularly enterprising, as liquid
hydrocarbons command a premium over the sale of gas, and the nation and the Western
world is in short supply of oil. Zero to low sulphur ultra-clean dieselene, a planned product of
the Company's GTL strategy, is expected to command an increasing premium over
conventional mineral oil diesel as it is being progressively more extensively used for blending
to meet environmental requlations. Diesel powered motor cars have increased their market
share in recent years and this trend is likely to continue.
6.0 PREVIOUS EXPLORATION
The area held by Central in the area of the Pedirka Basin is virtually unexplored, in an
exhaustive and definitive manner. Some early rudimentary exploration, aimed at Cambrian
targets, was conducted by the Delhi-Santos consortium in the early 1960's. At a similar time
Beach Petroleum explored in the NT sector of the basin. After the discovery of gas by Delhi
in the Permian section of the Cooper Basin at Gidgealpa 3 in 1963 some exploration aimed
at Permian targets occurred in the area. Following the recovery of 38 degree API gravity oil,
from the terrestrially sourceed Poolowanna Formation of the Eromanga Basin sequence at
Poolowanna 1 in 1977, (Western Mining Company), attention was directed towards the
Mesozoic section in the area of Central's permits. This exploration was regional in nature
and not really focused on specific plays or targets. Little exploration has occurred in recent
years in the area covered by the company's Pedirka Basin acreage.
Recent work by the Departments of Mines and Energy of both the NT and SA has upgraded
the petroleum potential of the area markedly. This work has established the presence of
mature source rocks, with oil generative potential in the area of question, the presence of
traps, and confirmed the accepted belief in the presence of excellent reservoir units. Seals
are known to be present within the blocks. No work, other than Central's, has been done on
the non-conventional prospectivity of the tenements. This prospectivity appears to be high.
7.0 GEOLOGY
The Pedirka Basin is one of a number of intra-cratonic sedimentary basins located in central
Australia. Minor recoveries of, and indications of, hydrocarbons have been made in several
of the few wells drilled into this prospective but under-explored and remotely located basin.
These wells seem to be inappropriately sited to definitively evaluate traps, in particular, and
the basin in general.
The area encompassed by Central's permits contains several sedimentary sequences, which
are productive of conventional hydrocarbons in basins immediately adjacent. Namely the
Paleozoic aged Amadeus Basin, to the northwest in the NT, where gas and oil are produced
from Ordovician section in the Palm Valley and Mereenie Fields, respectively. These
sediments are expected to be present in all of Central's newly acquired tenements, namely
EPA's 105, 106 and 107, as well as in the company's previously acquired permits, EP 93,
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and in EPA's 130 and 131 in the NT and in PELA 77 in SA.
Hydrocarbons are also produced from the Permo-Triassic aged Cooper Basin of SA and
QLD, to the east, where the giant Moomba, Gidgealpa and Dullingari Gas Fields, amongst
others, are located. The Cooper Basin is Australia's largest onshore gas province, and it also
contains the nation's biggest onshore oil field, at Tirrawarra. Correlatives of the producing
and source intervals are known to be present in Central's permits.
The Mesozoic aged Eromanga Basin of SA and QLD, also to the east, contains most of
Australia's onshore oil fields. Correlatives of producing and source intervals of the lower
Eromanga Basin sequence are present in Central's permits. Oil, of a waxy nature, probably
indicating sourcing from underlying Permian or Triassic coals, or carbonaceous shales has
been recovered from wells in the Poolowanna Trough of the Simpson Desert Basin, to the
east of the company's acreage.
Further east in QLD, but not adjacent, much gas and some oil has also been produced from
the Permo-Triassic aged Bowen Basin. The Permo-Triassic Gunnedah Basin of
northwestern NSW also produces gas. A correlative of the Eromanga Basin, the Surat Basin,
sustains oil and gas production in QLD. This basin hosts Australia's first commercial oil field,
discovered in 1961 at Moonie.
All of the Paleozoic, Permian, Triassic and Lower Mesozoic intervals, or their lateral
equivalents, which source the above-mentioned hydrocarbon accumulations, are known to
be present in the tenements which Central hold. It is known that the Permian coals are the
source of the oil and gas reservoired in the Cooper and Bowen basins and the gas in the
Gunnedah Basin. Further more it is widely believed that they are also the source of the oil
produced from the overlying Mesozoic Eromanga and Surat Basins. Oil has also been
recovered and produced from some Triassic intervals, particularly in SA, and it is thought
that the Triassic section also contains mature source rocks. Coal of Triassic age, which is
buried to shallow depths, is mined at Leigh Creek in central South Australia by open cut
methods. Hence, Central's acreage is essentially surrounded by, and contains, rich, mature
and generative source rocks, a fundamental requirement for hydrocarbon generation and
entrapment, either conventional or non-conventional.
7.1 Regional Geology
The Pedirka Basin of central Australia is located in both the NT and SA, and it covers an
area of approximately 73,000 square kilometres, of which Central holds some 40,000 square
kilometres or 55% of the basin. The acreage recently purchased from Traditional, EPA's 105,
106 and 107, extends over 26,000 square kilometres in total with approximately 6-8,000
square kilometres of Permian sediments and much more Triassic and Jurassic sediments
thought to be present. The company's previously held Pedirka Basin tenements covered
approximately 33,000 square kilometres.
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Figure 4 Large scale map of Central's Pedirka Basin acreage showing tectonic
elements.
Central's Pedirka basin acreage is located in northern SA, north of the settlement of
Oodnadatta and in south eastern NT and it straddles the state-territory border. The northwest
corner of the acreage package is just 20 kilometres east of Alice Springs. Its location is
shown on Figures 1, 2 and 4, along with the underlying and overlying basins.
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The area of Central's permits contains 4 distinct sedimentary sequences, the oldest being
the Paleozoic sediments of the Amadeus Basin sequence which overly metamorphic and
granitic basement. This sequence is unconformably overlain by sediments of the
Carboniferous-Permian Pedirka Basin sequence, which is rich in coals and carbonaceous
shales. Central's acreage package contains the basin's two main depocentres, the Eringa
and Madigan's Troughs in the east, mainly in the company's previously acquired acreage.
The Simpson Desert Basin contains a large thickness of Triassic section. Its main
depocentre, which is located to the east of the company's tenements, is known as the
Poolowanna Trough. It too contains coal and carbonaceous shales. This source-rich basin is
unconformably overlain by the oil productive Eromanga Basin.
7.2 Tectonic Setting
The Pedirka Basin sequence had its genesis in Carbonaceous-Early Permian time when
sedimentation occurred in a downwarp over the pre-existing sediments of the Proterozoic-
Early Carboniferous Amadeus Basin.
Sedimentation in the Amadeus Basin was controlled and constrained by basement blocks of
metamorphic and igneous composition, the Arunta Block to the north and the Musgrave
block to the south. The western margin of the basin is a shallow basement ridge separating
the Amadeus Basin from the Canning Basin of Western Australia.
The basin's eastern margin is not well understood but appears to be truncated. Two pulses
of marine deposition occurred, these were followed by a later pulse of continental
sedimentation. Several episodes of structuring occurred, involving uplift and erosion and
then sinking and marine transgression. The previously mentioned basement blocks acted as
immobile bulwarks against which the sediments of the Amadeus Basin were deformed and
structured, due to north-south compression.
Subsequently subsidence occurred in the deeper eastern end of the basin and the lacustrine,
fluvial, and often glacially derived sediments of the Pedirka Basin were deposited
unconformably on the Amadeus Basin section. Much coal was deposited in this cycle. A
hiatus then occurred before the Triassic aged Simpson Desert Basin sequence was
deposited, unconformably, on the Pedirka Basin sequence. These sediments are of
lacustrine, flood plain and fluvial origin, with some glacial influence. This cycle is dominated
by carbonaceous shale with significant coal. The depocentre of this basin, the Poolowanna
Trough is eastwards of the Pedirka Basin depocentres, the Eringa and Madigan's Troughs,
and eastwards of Central's acreage. However Simpson Desert Basin section is present in all
of Central's Pedirka Basin blocks.
Uplift and erosion occurred as a result of the widespread Triassic structuring event. This was
followed by the cyclic sedimentation of the Eromanga Basin sequence, of fluvial and flood
plain origin. The Poolowanna Formation, the basal unit is a good source rock, containing
much coal and carbonaceous shale, which are known to be mature and to contain oil prone
macerals. A marine transgression occurred in Cretaceous time when the Wallumbilla
Formation was deposited. This unit is a regional top seal to the Eromanga Basin sequence.
The basin complex has had, for most of its life, an intra-cratonic setting. In eastern and
central Australia this has resulted in the deposition of considerable amounts of coal and or
carbonaceous shale, good source rocks, along with many good fluviatile sandstone reservoir
units.
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7.3 Stratigraphy
Included as Figure 5 is a combined stratigraphic column for the basin complex. There are
known source and sealing intervals in each basin sequence along with good quality
conventional reservoirs units. As this report is concerned with the unconventional
hydrocarbon potential of the basin complex, the conventional reservoirs will only be
discussed in passing. They are fully discussed in other reports in the possession of Central
and in the papers listed in the list of references.
For unconventional hydrocarbon exploration the intervals of major stratigraphic interest are:-
7 The Horn Valley Siltstone of the Amadeus Basin Sequence
7 The Purni Formation of the Pedirka Basin Sequence
7 The Peera Peera Formation of the Simpson Desert Basin Sequence
The Horn Valley Siltstone, where drilled in the Amadeus Basin, is of Lower Ordovician age
and was laid down in a marine environment and is composed of organic rich siltstones and
black shales, underlain by a dolomitic and or glauconitic limestone sequence. It is commonly
pyritic, highly fossiliferous with graptolites and other invertebrates and is commonly gas
saturated.
The Early Permian aged Purni Formation is composed of interbedded grey shale and
carbonaceous siltstone, fine to coarse grained sandstone along with coal and conglomerate.
It was deposited in a flood plain, lacustrine and fluvial environment. The unit is known to be
350 metres thick in the Mokari 1 well, east of the company's acreage.
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Figure 5 Combined Stratigraphic Column
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The Peera Peera Formation is of Triassic age and is composed of grey and black shales,
coal and thin fluvial sandstones. It was laid down in a flood plain, lacustrine and fluvial
environment.
The Eromanga Basin sequence, in its classic producing areas to the east of Central's
acreage, consists of cyclic, interbedded and juxtaposed shale and silty units overlain and
underlain by excellent reservoir units of fluviatile sandstones. The finer grained units, whilst
they do contain some organic matter, are not as rich source rocks as those of the underlying
Triassic and Permian intervals of coals and carbonaceous shales, except for the
Poolowanna Formation. It is generally accepted that the bulk of the hydrocarbons
reservoired in the Eromanga Basin have been expelled from the underlying Cooper Basin,
that is the Triassic and Permian units. However there is a chance of hydrocarbons being
trapped in the Poolowanna Formation, either conventionally by intra-formational seals or
even non-conventionally. At this stage there is insufficient information to attempt to quantify a
possible magnitude of resources in this unit. However care should be taken whilst drilling
through this unit to deeper targets, as it may be hydrocarbon bearing.
On the western flank of the Eromanga Basin, in the area of Central's permits, the section
becomes progressively more sandy and most of the sequence merges into the Algebuckina
Sandstone, which is overlain by the Cadna Owie Formation, which in turn is overlain by the
marine shales of the Wallumbilla Formation, hence the Eromanga Basin sequence still has a
regional top seal in the area of the company's acreage. As a consequence if any
hydrocarbons are present, above the Poolowanna Formation, they should have been noted
in oil exploration wells or water bores, beneath the Wallumbilla Formation sealing unit.
It should be noted that several shallow mineral holes, CUR 3 and CUR 5, drilled just east of
the outcropping Musgrave Block, west of Central's acreage, encountered organic shales at
an early mature stage in a unit equivalent to the Jurassic aged Birkhead Formation of the
Eromanga Basin sequence. It is thought that it is unlikely that this unit will be laterally
widespread and a major source contributor to the Eromanga Basin sequence. Given the lack
of well control and the many sandy intersections in the few wells in the area it is difficult to
estimate the size of any possible resource either conventional or non-conventional in the
upper Mesozoic section of Central's acreage.
8.0 PETROLEUM GEOLOGY
To have a hydrocarbon accumulation the following conditions must be met:-
7 The presence of organically rich and un-oxidized source rocks, usually shales or
coals
7 The burial of these source rocks to depths whereby the organic material begins
to expel hydrocarbons, oil first and then, with deeper burial, dry gas
7 The presence of porous and permeable carrier and reservoir beds to allow the
migration of generated hydrocarbons from the hydrocarbon generating
kitchens near the basin depocentres to shallower sites of entrapment, which
can be economically reached with the drill bit.
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7 The presence of sealing units overlying the carrier and reservoir beds which
inhibit the upward migration of hydrocarbons, which results from the principle
of floatation in which less dense materials float on those which are denser.
Water is denser than oil, which in turn is denser than gas. These traps can be
of either a structural or stratigraphic genesis.
7 Natural gas, mainly methane, can also be trapped, by adsorption, against the
faces of cleats within coals, forming unconventional accumulations
7 In the case of dirty and tight source beds hydrocarbons can sometimes be
trapped unconventionally in "basin centred accumulations" in these source
intervals
All of these conditions are known to be present in Central's permits.
Once trapped, conventional hydrocarbon accumulations can be destroyed by later earth
movements, which can breach traps, igneous events, which can oxidize entrapped
hydrocarbons and deeper burial, which can reduce porosity and subsequently hydrocarbon
storage.
For non-conventional accumulations compressive events can close cleats reducing both
permeability and the macro-porosity of the coals. Igneous intrusions can fuse the cleats,
having the same effect.
8.1 Source Rocks
There are many intervals of known source rocks in the Amadeus, Pedirka, Simpson Desert
and Eromanga Basin sequences. The source intervals range in age from Ordovician to
Jurassic, and they, or lateral correlatives, are known to have generated hydrocarbons, both
oil and gas.
Amadeus Basin Source Rocks
The oldest of these is the Horn Valley Siltstone, of the Ordovician aged Larapinta Group of
the Amadeus Basin sequence. This unit is known to have sourced the oil and gas hosted in,
and produced from, the Pacoota and Stairway Sandstone reservoirs in the Mereenie and
Palm Valley Fields, respectively, to the west and northwest of Central's Pedirka Basin
acreage.
The unit, which is of 120 metres maximum thickness in the central part of the basin, near the
previously mentioned fields, is believed to be of a similar thickness in most of Central's
acreage. The Horn Valley Siltstone is a very rich source rock of marine origin averaging up to
10% total organic matter and is known to be mature for oil and gas generation over a very
wide area. Many wells drilled within the Amadeus Basin have, either discovered, recovered
or encountered indications of hydrocarbons from this unit. However it should be noted that
at Mc Dills 1 the unit was composed of barren red beds. Most wells in the Pedirka
Basin were not drilled deep enough to intersect this unit.
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If Gussow's Theorem has been, or is, operational then the undrilled southeastern margin of
the basin, located within Central's Pedirka Basin acreage, may host undiscovered oil
accumulations. This theorem, which appears to have been verified empirically by oil
accumulations on the northern basin margin, states that early generated oil is trapped first
then displaced by later generated dry gas. The mechanism of the theorem is that the gas,
which is less dense than oil, will enter the trap and rise to a crestal position and in doing so
will spill already reservoired oil from the base of the trap, up-dip and towards the basin
margin.
Given the wide lateral extent and the thickness of this unit it could have generated a
substantial oil, and later gas, charge.
Other units of the sequence have exhibited both oil and gas generative potential, namely gas
potential from some of the Proterozoic intervals and oil potential from the Chandler
Limestone and Tempe Formation of the Middle-Lower Cambrian Pertaoorta Group, as well
as the Pertatataka and Areyonga Formations and the Gillen Member of the Proterozoic Bitter
Springs Formation.
The Amadeus Basin sequence is likely to be oil prone rather than gas prone, given its marine
genesis. This is confirmed empirically in the Amadeus Basin by production and the many oil
shows and minor recoveries. Further deep drilling will be required to evaluate the
prospectivity or otherwise of the older Palaeozoic sequence within Central's permit areas.
Pedirka Basin Source Rocks
The overlying Pedirka Basin, like all other Carboniferous-Permian basins of eastern and
central Australia, is coal rich, and, although source rock analysis from the 14 wells drilled to
date shows a much higher exinite to vitrinite ratio than source rocks of the Cooper Basin, (ie
more oil prone) it is considered likely to have generated more gas than oil. However some oil
will have been generated as the organic matter in the source rocks, whether coals or
carbonaceous shales, is rich in the Type 2 macerals, which are oil prone. Indications of oil
have been encountered in exploration drilling in rocks of the Pedirka Basin sequence.
The prime source rock interval in the Pedirka Basin sequence is the Early Permian Purni
Formation. This unit, which contains much coal, is of intra-cratonic genesis, and is naturally
of a terrestrial origin, hence it is expected to be gas prone, but oil prone macerals have been
identified within it. The Purni Formation, which is widespread across both depocentres of the
Pedirka Basin, the Eringa and Madigan's Troughs, is one of Central's main targets for coal
bed methane exploration. It is known to be up to 350 metres thick, from well intersections,
which are located on large highs or on the flanks of the depocentres.The unit is likely to be
deeper and thicker in the NT, as the Eringa Trough plunges northwards. Also it is expected
to be much thicker in the basin depocentres, a later expected target area for Central's
proposed exploration drilling. However the cut-off depth for economic development of coal
bed methane (approximately 1,250m) may preclude much of these thicker units from
consideration, initially.
Simpson Desert Basin Source-Rocks
In the Simpson Desert Basin the prime source rock is the Triassic aged Peera Peera
Formation. This unit is composed of grey and black carbonaceous shales, coal and thin
fluviatile sandstones. It too is known to contain much mature source rock and some oil prone
macerals, although it is more gas and condensate prone .The depocentre, the Poolowanna
Trough, is located east of Central's acreage, however the unit is present in the company's
tenements. The Simpson Desert Basin sequence is believed to be approximately 1,000
metres thick in the basin depocentre to the east of Central's permit areas.
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8.2 Maturity
All of the quantitative data that is available on maturity from the area of the company's
acreage indicates that the source rocks are mature for hydrocarbon generation, both oil and
gas. This is supported by the empirical evidence of gas shows and oil fluorescence in
inappropriately sited oil exploration wells. Recent geochemical analyses conducted for the
Geological Surveys of SA and the NT have also confirmed that the Pedirka and Simpson
Desert Basin and lower Eromanga basin sequences contain rich and mature hydrocarbon
source rocks. The reader is referred to the listed references. Hence the area has generated
oil and gas.
These studies indicate that the oil generative window commences at about 1250 metres in
both the Pedirka and Simpson Desert Basin sequences. It should be noted that vitrinite
reflectance suppression has been observed so that the actual window is probably shallower.
The hot dry gas window will be more deeply buried. The Horn Valley Siltstone of the more
deeply buried Amadeus Basin sequence is known to be now in the dry gas window. The
source rocks of the Early Jurassic Poolowanna Formation (=Basal Jurassic of Queensland)
are also early mature for oil generation in the Poolowanna Trough, and perhaps in Central's
acreage. However it should be noted that this interval, a basal Eromanga Basin unit, is not a
blanket unit and is often absent from basement `highs and accordingly may not be laterally
extensive in Central's acreage, particularly in the most western of Central's Pedirka Basin
blocks, the newly acquired acreage.
Hence the company's Pedirka Basin acreage contains a multitude of known mature source
rocks. Recognized reservoir units are known to juxtaposed with these potentially generating
intervals. Large structural traps have been identified within the area. All of this bodes well for
the existence of large conventional accumulations of hydrocarbons.
In the case of non-conventional accumulations at depths less than the oil window the chance
of biogenic methane and / or thermogenic methane also exists, as at early maturity levels
wet gas can be generated. It is known that shallowly buried members of the Jurassic aged
Walloon Coal Measures of the Surat Basin sequence host coal bed methane. During earlier
oil exploration programs several seismic shot hole drilling rigs were burnt out in Queensland
as a result of shallow gas flows from this unit. Hence the coals do not have to be within the
gas window to host methane.
The fact that the potential source rocks are rich in oil prone macerals is fortuitous as the gas,
adsorbed to the coal, will contain higher homologues than methane and should produce
more synthetic crude during synthesis than methane alone would.
8.3 Reservoirs
Many good quality conventional reservoirs are known to be present in the Pedirka, Simpson
Desert and Eromanga Basin sequences. The chance of discovering conventional
hydrocarbons in these units is considered to be high. The area of Central's permits is
virtually unexplored, no modern and focused exploration has been conducted in the area
apart perhaps than that of the Sydney Oil Company in the mid 1980's which was centred on
the Madigan Trough area. Studies by officers of the South Australian and Northern Territory
Department of Mines and Energy have identified potentially active petroleum systems in all
three basin sequences, in conventional reservoirs. These petroleum systems are analogues
of proven systems in adjacent basins, in laterally equivalent units. This is detailed in the
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listed references.
Central are also intent on unconventional exploration in the area of their permits, and as
such are also focused on non-conventional reservoirs. These include
7 The Horn Valley Siltstone (Ordovician Amadeus Basin)
7 The Purni Formation (Permian Pedirka Basin
7 The Peera Peera Formation (Triassic Simpson Basin)
As discussed above the Horn Valley Siltstone is a very rich, proven source interval, which has
sourced the commercial oil and gas production in the NT sector of the Amadeus Basin. In many
wells high gas readings have been encountered whilst drilling through it, typically the readings
"were off scale". A good gas show was tested at Tent Hill 1, however due to poor conventional
reservoir quality, the subsequent flow rate was not commercial.
Due to its silty composition and compaction along with the ubiquitous gas shows over a wide
area it is considered to be a good candidate for fracture stimulation, as the rocks are competent
and should be able to be fractured, to enhance flow rates. The gas saturated section seems to
extend through the entire section, hence a large volume of gas could be entrapped in this unit.
The chance of encountering oil cannot be discounted. It should also be noted that the eastern
end of the basin is deeper and the dip into the basin from this direction is gentler and that the
mechanism of Gussow's Theorem may not have been as active in this area, as in the north, and
may not have displaced all of the early reservoired oil.
An unusual feature of both ``basin centred gas accumulations" and coal bed methane is that
separate and distinct source and reservoir units are not necessarily required. In the former case,
hydrocarbons, generally gas, are held in the source beds by either hydrostatic and or capillary
pressure. This results from the tight and dirty nature of the interval. Whereas for coals, the
generated methane is adsorbed to the faces of the cleats and is held there by hydrostatic
pressure and to a lesser extent, by capillary pressure.
In the case of conventionally reservoired hydrocarbons, the hydrocarbons are expelled from the
source beds to porous and permeable reservoir rocks and held there by overlying fine grained,
impervious sealing units. However it should also be noted that under conventional trapping
geometry, either structural or stratigraphic, that coals and tight, dirty units ( ie unconventional
reservoirs ) can possess a gas cap in the traditional sense, in crestal or structurally high
locations. Wells located in such locations generally flow at higher rates and often without water.
As a consequence of the above for unconventional exploration, the source, seal and reservoir
units are one and the same. Hence the prime reservoirs in Central's proposed exploration
programs for unconventional hydrocarbons are :-
7 The Horn Valley Siltstone
7 The Purni Formation
7 The Peera Peera Formation
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Conventional and good quality reservoirs have been identified in the sedimentary sequences of
all the basins present in Central's acreage. They are legitimate targets for exploration in their
own right.
8.4 Sealing Units
As discussed above, non-conventional hydrocarbon accumulations are hosted in the source
beds and are trapped by unusual mechanisms. In the case of "basin centred gas" by hydrostatic
and or capillary pressure and for methane within coal beds, by adsorption to the faces of the
cleats in the coals. The entrapped methane is held there by hydrostatic pressure and to a lesser
extent by capillary pressure.
Hence for non-conventional hydrocarbon accumulations the source, reservoir and sealing units
are one and the same, namely the source beds. As a consequence of this the prime sealing
units are:-
7
The Horn Valley Siltstone
7
The Purni Formation
7
The Peera Peera Formation
Conventional seals of a regional and intra-formational nature are also known to be present in all
sedimentary sequences present in Central's acreage.
8.5 Traps
Conventional hydrocarbon traps of both a structural and stratigraphic nature have been
identified on seismic data from Central's tenements and are expected to be present in EPA's
105, 106 and 107. As discussed above, conventional traps are not necessarily a prerequisite for
non-conventional accumulations. However empirical evidence shows that where wells have
been drilled for unconventional hydrocarbons, invariably the better performing wells are sited on
conventional traps superimposed on larger non-conventional accumulations. Hence all
exploration should initially be aimed at large uplifted structural targets in all of Central's blocks.
9.0 COAL BED METHANE DRAINAGE
The reader is referred to the corresponding section of the previously mentioned earlier report.
10.0 GAS TO LIQUID (GTL) AND COAL TO LIQUID (CTL) CONVERSION
The reader is referred to the corresponding section in the previously referred to report by
Mulready Consulting Services Pty Ltd.
11.0. COAL TO GAS PROCESSING
The reader is referred to the corresponding section of the previously mentioned earlier report.
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12.0 UNDERGROUND GASIFICATION
The reader is referred to the corresponding section of the report on Central's current Pedirka
Basin blocks, previously mentioned.
13.0. FRACTURE STIMULATION
The reader is referred to the corresponding section of the report on Central's current Pedirka
Basin blocks, previously mentioned.
.
14.0 UNTESTED PLAYS
No play has been definitively tested in any of Central's Pedirka Basin acreage. The few existing
petroleum exploration wells are not definitive crestal tests or have not tested robust fault
independent closure. Only one well, Bluebush 1, is located within the acreage purchased from
Traditional and this well was designed to target the Amadeus Basin sequence. No exploration
for coal bed methane has been conducted in the area. No fracture stimulation of tight reservoirs
has been attempted in the acreage. In light of the above it is suggested that Central's
exploration program be directed towards the testing of large uplifted structures, as this will
evaluate both the conventional and non-conventional potential of the acreage simultaneously.
Several types of traps should be tested between the basin depocentre and the basin margin.
This applies to both the Pedirka and Simpson Desert Basin sequences for coal bed methane
exploration. Generally traps in these units are coincidental.
The coals should be fully cored for the evaluation of their suitability for coal bed methane
extraction. If the results are positive then blanket development drilling could commence.
15.0. POTENTIAL UNDISCOVERED RESOURCE
A large prospective, but as yet undiscovered, hydrocarbon resource appears to be present in all
of Central's Pedirka Basin acreage. It is not possible to accurately quantify the possible
resource due to the lack of specific definitive data on coal properties and the lack of drilling,
particularly in EPA's 105, 106 and 107. To date all exploration within the area has been frontier
oil exploration and was not focused on non-conventional hydrocarbon resources. The author
considers that the chance of discovering conventionally reservoired hydrocarbons within
Central's Pedirka Basin acreage is also high.
Rudimentary well data from the 14 conventional oil exploration wells drilled in the Pedirka Basin
to date, along with regional seismic data indicates that thick and widespread coal horizons are
present in the Pedirka and Simpson Desert Basin sequences of Central's acreage. Hence the
potential for coal bed methane extraction exists.
Drilling results in the NT indicate that the Horn Valley Siltstone of the Amadeus Basin sequence
is gas saturated and widespread. Wireline logs and gas detector instrumentation confirm this
high hydrocarbon saturation. Geochemical analyses indicate that the unit is an extremely rich
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source rock with oil generative potential, as has been proven empirically by production. Sub-
economic gas flows have also been obtained from it, again in the NT. This tight unit is a good
candidate for fracture stimulation to enhance gas flow rates, should its depth of burial and facies
aspect prove suitable.
15.1 Indicative undiscovered target size
Figure 6 Depth Map to the top of the Permian Purni Formation Coal Measures showing
the area of coal above 1,250m in the Northern Territory sector of the Basin.
Amadeus Basin sequence
For the Horn Valley Siltstone, more traditional oil industry parameters would be used in a
possible resource determination but there is not enough information, from drilling, to attempt to
quantify the extent and thus the potential resources of hydrocarbons in this tight, low porosity
and low permeability reservoir in Central's Pedirka Basin leases. Hence no possible resource
determinations will be conducted on the sequence.
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Pedirka Basin sequence
After reviewing seismic two way time maps, (prepared by Brent Jensen-Schmidt , a consultant
to the NT Department of Minerals and Energy as part of the NGMA mapping project), to the Top
of the Purni Formation, converted to depth with a representative seismic velocity, it is estimated
that the Purni Formation of the Pedirka Basin sequence, subcropping at depths above 1250
metres, extends over some 8,000 square kilometres in Central's tenements, EPA's 105, 106
and 107. This compares with approximately 20,875 square kilometres for the area of EP 93,
EPA'S 130 &131 and PELA 77A, as discussed in the main body of the report. A depth map for
the NT sector of the basin is included as Figure 6. Similar mapping was used for the SA sector
of the basin, this is discussed in the earlier report. This mapping was tied back to the few wells
present in the area. Well logs were also perused to ascertain the coal thickness It appears that
there is a net coal thickness of 40 metres, in 4.5-7.5 metre seams, in the unit. No gas saturation
values have been determined for these coals, however values from the correlative Bowen Basin
units in Queensland average about 11 cu. metre/tonne, This latter figure will be used in the
possible resource determination for the Purni Formation.
However, other correlatives in the similar aged Galilee basin of Queensland have a gas
saturations of about 3 to 6 cu.metre/tonne. Similar values, to the latter, have been determined
from the less deeply buried Walloon Coal Measures of the Mesozoic aged Surat Basin
sequence, which overlies the Permo-Triassic Bowen Basin. The gas saturation value depends
on the nature of the coal; rank and burial depth, the deeper the coals the higher the gas
saturation. The Pedirka Basin coals are more deeply buried and the average value stated above
is likely to be appropriate.
Simpson Desert Basin sequence
After reviewing two way seismic maps to the Top of the Peera Peera Formation, from the above
mentioned consultant, coverted to depth with a representative seismic velocity, it is estimated
that the Peera Peera Formation of the Simpson Desert Basin sequence, subcropping above
1,250 metres, extends over approximately 8,000 square kilometres in EPA's 105, 106 and 107.
This figure is probably conservative as Simpson Desert Basin deposition oversteps the
underlying Pedirka Basin sedimentation. This map is included as Figure 7. A similar map was
used for the SA sector of the basin, as discussed in the report on EP 93, EPA's 130 and 131
and PELA 77, where the corresponding area of coal above the cutoff value is 21,875 square
kilometres. Again the seismic was calibrated to wells and well logs. There appears to be a
lesser thickness of coal but an increased thickness of carbonaceous shale in this sedimentary
sequence, compared to the Permian unit. If fractured successfully, these shales will also
contribute to the gas flow. It is estimated that the net coal thickness in the Peera Peera
Formation is 20 metres. The Triassic coals in the Ipswich Basin have gas saturations ranging
from 5.8 cu.metres / tonne to 11.1cu.metres / tonne. These values were measured from cores
taken at depths of 300-430 metres and 432-492 metres, respectively, from a well drilled at the
Swanbank Power Station in Queensland. An average value of 11.0 cu.metres / tonne has also
been assumed for this unit.
--------------------------------------------------------------------------------
Figure 7 Depth to the Top of the Triassic Peera Peera Formation highlighting the area of
coal and carbonaceous shale above 1,250m.
Using standard conversion factors for long tons to metric tonnes, the amount of coal of unknown
composition per metre depth per square kilometre to coal mass, and for cu.metres to cu.feet,
and using the above gas saturation values the calculation for the likely amount of gas contained
in these coals has been completed. The values, which are indicative, are detailed below.
The economic cutoff value for coal bed methane extraction of 1,250 metres is also indicative,
however coal bed methane drainage from coals at of approximately 1, 000 metres were
considered to be economic by the large US company Enron in the Galilee Basin, in lower gas
saturated coals. The cutoff depth will be dependent on gas saturation and the performance of
crestal wells, however an estimate of 1,250 metres appears reasonable. Most of the coals
expected to be present in EPA's 105, 106 and 107 are located on the Andando Shelf and are
less deeply buried and are expected to be above this cutoff value.
It is thought that for a plant near to the producing fields that the plant gate price will be in the
order of A$ 2.00 per mCFG however this price will be highly volume dependent.
--------------------------------------------------------------------------------
Prospective in place resources EPA 105,106 and 107
Using the above mentioned areas, net effective columns of coal, gas saturation values and the
appropriate conversion factors the likely in place resources possibly hosted in the Pedirka and
Simpson Desert Basins are estimated to be:-
7 Pedirka Basin sequence =17.1 TCF (coal bed methane)
7 Simpson Desert Basin sequence =8.3 TCF (coal bed methane)
7 Total =25.4 TCF
his figure is considerable and compares favourably with values accepted by
T
Halliburton, a specialist service company, for some other significant methane producing
basins. That company estimates that the in place methane resource in the San Juan
Basin of New Mexico, the most gas saturated basin in the USA, is between 68 and 84
TCF. They believe that the Appalachian Basin of the eastern USA holds an in place
resource of 66 TCF and that the Northern Bowen Basin of eastern Australia has an in
place methane resource of 136 TCF. The corresponding value for Central's other Pedirka
Basin tenements, EP 93, EPA's 130 &131 and PELA 77 as estimated by Mulready
Consulting Services is 50.6 TCF.
is expect
It ed that half of this indicative possible resource may be recoverable. Although the
amount of the potential resource ultimately recovered will depend on gas saturation, flow rates,
the number of and the spacing of drainage wells, the success of probable fracture stimulation
operations and other factors. Not enough data is available on reservoir and gas saturation
values to make comprehensive probabilistic estimates of "low", `"best" and "high" cases. Such
estimates have been made on a deterministic basis using a range of expected recoveries.
ospective recoverable resources EPA 105
Pr , 106 and 107
High Estimate (75% recovery)
Pedirka Basin sequence= 12.8 TCF
Simpson Desert Basin sequence =6.2 TCF =
TAL = 1
TO 9.0 TCF
Best Estimate (50% recovery)
Pedirka Basin sequence=8.6 TCF
Simpson Basin sequence=4.2 TCF
TAL = 1
TO 2.8 TCF
--------------------------------------------------------------------------------
Low Estimate (35% recovery)
Pedirka Basin sequence=6.0 TCF
Simpson Desert Basin sequence=2.9 TCF
TOTAL = 8.9 TCF
16.0 RISKS
All petroleum exploration, whether conventional or non-conventional, contains inherent risk. The
main risks in Central's proposed non-conventional program are
7 The gas saturation of the coals, which are unknown
7 The location of water sands within or near the coals
7 The lateral extent of the coals
7 The thickness of the coal beds
7 That economic flow rates are achieved from development wells
7 The success of possible hydraulic fracturing operations
In spite of the above risks there is enough encouragement, in the author's view, to pursue this
high potential reward project.
.0 RECOMME
17 NDATIONS
The prime recommendation of this report is that Central persists with its objective to explore for,
develop and produce hydrocarbons of a non-conventional origin from their Pedirka Basin
acreage. Their innovative ideas of gas, or coal, synthesis to synthetic crude oil are capable of
unlocking a large scale, but un-utilized resource in the basin complex contained within their
tenements. Liquid hydrocarbons command a premium over gas and are more readily
economically transportable and more readily saleable. Ready local and, probably, export
markets exist for liquids in this time of oil shortage and high prices.
The company's objectives are sound in that they are targeting Permian and Triassic coal rich
intervals, correlatives of which are known to have sourced both conventional and non-
conventional hydrocarbon production in adjacent basins in eastern and central Australia. It is
the author's experience that wells aimed at non-conventional targets perform better when sited
on conventional trapping geometry, the laws of Physics and Chemistry still hold in un-
conventional accumulations. As a consequence it is further recommended that exploration wells
be sited on crestal locations on large tensional structures. This will maximize drainage and
reduce the associated dewatering costs, an expensive ancillary requirement for both coal bed
methane and basin centred gas production. Down flank production wells, probably less
productive, could then be drilled later to develop the field.
An additional recommendation is that wells aimed primarily at the the Pedirka and Simpson
Desert Basin sequences be drilled into the underlying Horn Valley Siltstone of the Amadeus
Basin sequence; despite its tight and dirty nature, as it appears, by analogy with the same
formation drilled in the Amadeus Basin to the west, to be gas saturated over a wide vertical and
lateral extent. This very rich source rock appears to be an ideal candidate for fracture
--------------------------------------------------------------------------------
stimulation and it is known to be oil prone. This unit should be investigated by coring and
conducting fracture stimulation trials.
The Horn Valley Siltstone, under the western portion of the Pedirka Basin and in the Amadeus
Basin proper, much of which is also held by Central, also appears to have potential for
conventional gas and or liquids production.
Given the perceived lack of organic material in the Eromanga Basin sequence in Central's
acreage it is recommended that Mesozoic targets only not be drilled at this stage. The
Eromanga Basin sequence is also very sandy in the area of Central's permits and as a
consequence sealing of conventional reservoirs is believed to be problematic in EPA's 105, 106
and 107.
The Company should be very watchful whilst drilling through the Poolowanna Formation as this
unit is the most prospective in the Mesozoic section.
In the initial stages of exploration the search for conventional and non-conventional
hydrocarbons should be combined to quickly prove up a resource, which could confirm
economic viability.
A final recommendation is that the all early exploration holes be fully cored through the coal
units to accurately gauge their thickness and that the subsequent cores be fully analyzed with a
particular emphasis on gas saturation, cleating and other fundamental properties.
18.0 CONCLUSIONS
7 The major conclusion of this report is that EPA's 105, 106 and 107 along with Central
Petroleum Pty Ltd's current Pedirka Basin acreage are prospective for hydrocarbons,
either reservoired conventionally or non-conventionally.
7 The coals of the Pedirka and Simpsons Desert Basin sequences are rich mature source
rocks and correlatives of them have sourced many oil and gas accumulations in adjacent
basins. The carbonaceous shales of these units are also known to be good, mature
source rocks. Similarly the very rich source rocks of the Horn Valley Siltstone of the
underlying Amadeus Basin sequence are known to be the source interval for the
Mereenie and Palm Valley Oil and Gas Fields, respectively of the Northern Territory, but
the nature of the sequence in Central's permits is largely unknown. If suitable facies are
encountered during drilling then this gas saturated, but tight, unit could be a candidate
for fracture stimulation. It is thought that the Amadeus Basin sequence exhibits much
conventional potential in EPA's 105, 106 and 107.
7 If the Company's exploration programs are successful the sheer size of target resource
should enable the construction of a large scale GTL plant and or a CTL plant. Recent
feasibility studies suggest that these processes are economic at the current oil price.
However the economic viability of these processes is volume dependent.
7 Ready markets exist for the sale of liquids and to a lesser extent gas, and other chemical
by products.
7 Central has a very innovative and elegant proposal to utilize a known, but undeveloped,
--------------------------------------------------------------------------------
possible resource of large magnitude in a remote location.
7 The company has an overwhelming acreage position in the Pedirka Basin area,
enhanced by the recent acquisition of EPA's 105, 106 and 107, and will dominate
production from it if their exploration programs are fruitful.
7 The Pedirka and the associated basins in the company's acreage are virtually
unexplored and potential exists for large discoveries of hydrocarbons either of a
conventional or non-conventional nature.
CLA
DE RATIONS
urces of Information
So
Data on Central's Pedirka Basin acreage was supplied by Mr. J Heugh, the Managing Director
of Central, Mr Greg Ambrose, the Exploration Manager and Mr T Rudge, an employee of the
company. It was supplemented by discussions with officers of the SA and NT Department of
Minerals and Energy and by public domain data as listed in the Bibliography (see below).
Previous Independent Geological Reports
A prior report on Central Petroleum Limited's central Australian acreage, with emphasis on the
Amadeus Basin Basin was prepared by Mulready Consulting Services for inclusion in Central
Petroleum Limited's Prospectus. That report is dated 12 September 2005.
This report has been prepared as an addendum to an another earlier report dated March 2007,
prepared by Mulready Consulting Services Pty Ltd on other tenements controlled by Central in
the Pedirka Basin, namely " The Unconventional Petroleum Potential of EP 93, EPA's 130&131
and PELA 77 Pedirka Basin Onshore Northern Territory and South Australia Australia".
Title
Verification of title was not within the brief of Mulready Consulting Services Pty Ltd in relation to
this Report.
Inspection
As is usual for exploration permits we have not undertaken an inspection of the properties dealt
with in this Report.
mment
Co
is our view that the proposed programme,
It to explore for and develop un-conventional
hydrocarbon resources in Central's central Australian acreage, as outlined in this report, is
soundly based on the results of previous exploration, studies by the company and the
appropriate state Departments of Minerals and Energy and by recent developments in the
synthesis of gas and coal to liquid hydrocarbons. We think the proposed project is sound,
appropriate and reasonable.
mitations and risk
Li
In preparing this Report we have relied on the sources indicated above. A draft of this Report
--------------------------------------------------------------------------------
was supplied to Central for comment regarding any errors of fact.
Exploration for and development of hydrocarbons is inherently speculative.
There is as yet no direct method for determining the presence of hydrocarbons prior to
drilling of an exploration well. There is always the risk that any potential trap may not
contain hydrocarbons by virtue of inappropriately located or timed hydrocarbon
generation or migration, or due to ineffective seal or later disruption of the trap. In the
case of un-conventional accumulation there are additional constraints such as the levels
of gas saturation of the coals, depths to the coals and the quality and quantity of the
water which may need to be disposed of, amongst others. A potential trap may also
contain non-commercial volumes due to adverse reservoir conditions or inadequate
charge of hydrocarbons. In this Report discussion of potential traps, including
structures, features and culminations, and of related potential hydrocarbon volumes,
should not be taken to imply that a commercial accumulation is known to exist.
Independence
Mulready Consulting Services Pty Ltd is not operating under an Australian financial services
license in providing this Report.
$10,000 (GST inclusive) plus any out of pocket expenses is all the remuneration (including
commission) or other benefits that any "nominated person" is to receive that might reasonably
be expected to be or have been capable of influencing Mulready Consulting Services Pty Ltd in
providing this Report.
In this context, a nominated person is any of:
(i) Mulready Consulting Services Pty Ltd;
(ii) a related body corporate of Mulready Consulting Services Pty Ltd;
(iii) a director or employee of Mulready Consulting Services Pty Ltd or a related body corporate
of Mulready Consulting Services Pty Ltd;
(iv) an associate of any of the above
Otherwise there are;
-no other interests whether pecuniary or not and whether direct or indirect, of Mulready
Consulting Services Pty Ltd or any associate of Mulready Consulting Services Pty Ltd.
- no other associations or relationships between Mulready Consulting or any
Services Pty Ltd
associate of Mulready Consulting Services Pty Ltd and Central Petroleum Limited that might
reasonably be expected to be or have been capable of influencing Mulready Consulting
Services Pty Ltd in providing this Report.
either Mulready Consulting Service
N s Pty Ltd nor any of its directors, employees or Associates
has any beneficial interest in Central Petroleum Pty Ltd, nor in any of the permits which are the
subject of this Report, nor in any adjacent permits.
nformity
Co
is report
Th has been prepared to conform to the requirements of the Australian Securities and
Investments Commission Policy 75 (Independent expert reports to shareholders) and Practice
Note 42 (Independence of Expert's Reports) and 43 (Valuation Reports and Profit Forecasts) as
applicable.
--------------------------------------------------------------------------------
Date of report
This report is dated June 21st 2007.
Consent
Mulready Consulting Services Pty Ltd consent to the issue of this Independent Geologist's
Report in the form and context in which it is included.
Qualifications
Jack N. Mulready graduated from the University of Melbourne with a B.Sc. (Geology) 1963, Dip.
Ed.(1966) and B.A. (1999) and from R.M.I.T. with a Fellowship Diploma in Management in
1978. He has over 38 years of experience within the petroleum exploration and production
industry in Australia, New Zealand, USA, Indonesia, China and PNG.
He is a member of the Petroleum Exploration Society of e Geologica
Australia, th l Society of
Australia and the American Association of Petroleum Geologists (Certified APPG Geologist No.
5321), and is subject to the code of ethics of these bodies.
He has prepared numerous independent geologist's reports and valuations for a variety of
Australian companies in accordance with the requirements of the Australian Stock Exchange.
Jack Mulready
B.Sc., B.A., Dip. Ed., F.Dip. RMIT, MGSA, MPESA,
Certified APPG Geologist #5321.
Roger Meaney, Associate Consultant Petroleum Geologist, graduated from LaTrobe University
with a B.Sc. (Honours) in Physics and a Diploma of Education in 1973.He later completed the
requirements for a B.Sc. in Geology from the same institution, part time. He has more than 28
years experience in oil and gas exploration. He was employed as a Petroleum Geophysicist by
Esso Australia Limited, AAR Limited and Santos Limited and worked in all facets of hydrocarbon
exploration. He has extensive technical experience in both the onshore and offshore sectors of
the industry in Australia and some in the United States of America, Canada and Papua New
Guinea and in management. Roger also has experience in the coal bed methane drainage
industry.
He is a member of the Society of Exploration Geophysicists and of the Petroleum Exploration
Society of Australia, and is subject to the code of ethics of these bodies. Roger has completed
several independent geologist's reports for Australian companies in accordance with the
requirements of the Australian Stock Exchange.
A. Meane
R. y
B.Sc. (Hon), Dip. Ed., MSEG, MPESA
--------------------------------------------------------------------------------
19.0 SELECTED REFERENCES
The reports and publications, listed below, along with internal reports, supplied by
Central were used in the compilation of this report, as was knowledge in the possession
of the author.
7 Petroleum Potential of the Eringa Trough in S.A and the N.T. E.M. Alexander, D.
Pegum, P. Tingate, C.J Staples, B.H. Michaelsen and D.M. McKirdy. APEA Journal
1986.
7 Pre-Feasibility Study for a 10,000 bbl/day FT GTL plant in central Australia with
notes on a 50,000 bbl/day option
7 New Petroleum Models in the Pedirka Basin, Northern Territory, Australia. G.J.
Ambrose, K. Liu, I. Deighton, P.J. Eadington and C.J Boreham. APEA Journal
2005.
7 Permits OP 238 and EP 2 Pedirka/Simpson Desert/ Western Eromanga Basins
Geohistory Study 1987. Darryl Kingsley.
7 Hydrocarbon Potential of the Pedirka Basin Northern Territory Australia. N.T.
Department of Mines and Energy.2000.
7 Landsat MSS Interpretation of the Eringa Trough South Australia and Northern
Territory. R. Russell. 2000.
7 Australian Petroleum Accumulations Report1 Amadeus Basin. Bureau of Mineral
Resources, Geology and Geophysics. 1986.
7 Coalbed Methane Technology, Halliburton Company, Duncan, Oklahoma
7 The Cooper and Eromanga Basins Australia, Edited by B.J.O'Neill, 1989
7 Handbook of South Australian Geology, Geological Survey of South Australia,
1969
7 Field Geologist's Manual, Monograph 9, Australian Institute of Mining and
Metallurgy, 1987
7 Pre-feasibility Study for a 10,000bbl/day FT GTL Plant in Central Australia with
--------------------------------------------------------------------------------
Notes on a 50,000bbl/ady Option, Technical Note. Holt Campbell Payton Pty Ltd.
Report to Central Petroleum Limited
7 Gas-to Liquids and Coal-to Liquids An Obvious Solution. Dennis. L. Yakobsen
Rentech Inc.
7 Eringa Trough Exploration Opportunity. Elinor Alexander and Brent Jensen-
Schmidt.Department of Mines and Energy, South Australia. Report 95/36.
7 Jogmec's GTL Research and Development for Utilization in the Future. Yoshifumi
Suehiro, Japan Oil and Gas National Corporation
7 Sustec-Syntroleum Coal to Liquids Integrating Gasification, Fischer-Tropsch and
Refining Technology. Gas-to Liquids and Coal-to Liquids. Ken Roberts,
Syntroleum Inc.
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