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Slide 1Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Beach Energy LimitedBeach Energy Limited
Reg Nelson
Managing Director
Reg Nelson
Managing DirectorHong Kong – 4&5 July 2011
Singapore – 6&7 July 2011
‘Evolution and Revolution’
Slide 2Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Overview
Slide 3Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Compliance statements
Disclaimer
• This presentation contains forward looking statements that are subject to risk factors associated
with oil, gas, geothermal and related businesses. It is believed that the expectations reflected in
these statements are reasonable but they may be affected by a variety of variables and changes in
underlying assumptions which could cause actual results or trends to differ materially, including,
but not limited to: price fluctuations, actual demand, currency fluctuations, drilling and
production results, reserve estimates, loss of market, industry competition, environmental risks,
physical risks, legislative, fiscal and regulatory developments, economic and financial market
conditions in various countries and regions, political risks, project delays or advancements,
approvals and cost estimates.
• All references to dollars, cents or $ in this presentation are to Australian currency, unless
otherwise stated. References to “Beach” may be references to Beach Energy Limited or its
applicable subsidiaries.
• Unless otherwise noted, all references to reserves and resources figures are as at 30 June 2010
and represent Beach’s share.
Competent Persons Statement
• This presentation contains information on Beach’s Reserves and Resources which have been
compiled by Mr Gordon Moseby, who is a full time employee of Beach, is qualified in accordance
with ASX listing rule 5.11 and has consented to the inclusion of this information in the form and
context in which it appears.
Slide 4Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Beach Energy Limited - A unique value proposition
Slide 5Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Key catalysts for 2011
Multiple near-term catalysts with material re-rating potential
Slide 6Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Large Resource base to build Reserves
2P Reserves
66 MMboe*
2P Reserves & Contingent Resources
363 MMboe*
* Volumes quoted are as at 30 June 2010 and do not incorporate 12 MMboe (Beach share) of additional
Cooper Basin 2P reserves announced by Santos Ltd in Feb 2011, nor the impact of the Impress Energy acquisition
Material resource additions likely for Cooper Basin gas activity
Cooper / Eromanga Other Cooper / Eromanga 2P Other
2P Reserves
are a fraction
of the total
resource base
Slide 7Beach Energy Limited, Asian Roadshow – 4-7 July 2011
• FY11 guidance of ~ 6.5 MMboe*
• Consistent Cooper Basin production
performance
• Short-term opportunities for
production growth given:
– Better land access for activities
following Cooper Basin floods
– Aggressive exploration and
development drilling for 2011/12
Solid production platform
0
2
4
6
8
10
12
FY 2006 FY 2007 FY 2008 FY 2009 FY 2010
Beach Operated Western Flank Oil
Gross Expected Ultimate Recovery (MMbbl)
* Production guidance is preliminary
Near-term production
uplift potential
Slide 8Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Positioned for growth in Eastern
Australian gas markets
Slide 9Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Beach owns a strategic suite of assets and infrastructure,
positioning it to supply gas for generations to come
Prolific acreage position
Slide 10Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Eastern Australian gas markets are growing
• Current domestic gas demand
~ 715 PJ per annum:
– ~ 100 PJ from Cooper Basin
• Domestic gas demand expected
to grow to ~ 1350 PJ by 2025*:
– Driven by power generation
– Higher demand scenarios
possible
• Gladstone based LNG projects adds
a new dimension to gas market
dynamics
* Core Energy Group 2011
Beach is well placed strategically and
geographically to supply the market
Slide 11Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Excellent prospects to increase Cooper Basin supply
• Strong predicted growth in Eastern
Australian gas demand
• Strong predicted growth in Asian LNG
demand
• Excellent channels to markets
• 2015+ opens up various domestic and
export linked opportunities
• Cooper Basin gas does not have the
potential challenges that may impact
long-term coal seam gas development
in Queensland and New South Wales
Increasing number of domestic and
export customers looking to buy gas
Source: Core Energy Group 2011
Slide 12Beach Energy Limited, Asian Roadshow – 4-7 July 2011
The impact of eastern Australian LNG projects
• Two projects have achieved FID
committing > 16 mtpa capacity
• BG Group has recently
announced it is marketing for
QCLNG Train 3
• APLNG recently announced a
4.3 mtpa contract with Sinopec
• More projects / contracts to
come in due course
~ 80% of East Coast 2P reserves are
owned by parties developing LNG
projects or with LNG aspirations
* Adapted from Energy Quest, February 2011
LNG markets provide access to oil-
linked gas pricing – a paradigm shift
from traditional domestic pricing
18.7%
17.5%
14.9%13.2%
6.2%
6.2%
9.7%
4.2%
2.3%
7.0%
Australian East Coast 2P Reserves*
BG Group
Santos / PETRONAS
/ TOTAL / KogasOrigin Energy
Conoco Phillips
Shell
PetroChina
BHP Billiton /
ExxonMobilAGL
Eastern Star Gas
Others
Slide 13Beach Energy Limited, Asian Roadshow – 4-7 July 2011
SACB/SWQ JV – Significant long-term
resource potential
Slide 14Beach Energy Limited, Asian Roadshow – 4-7 July 2011
SACB/SWQ JV – Its importance to Beach
• Equity interests of approximately
20% for the SACB JV and 23% for
the SWQ JV
• A significant land holding for these
interests of approximately 22,000 km2
• Situated in a proven and prolific basin
• Cooper Basin cumulative gross
production to date of approximately
6 Tcf
• Provides access to a large onshore
hydrocarbon province with:
– A proven reserve base
– A large booked contingent resource
– Significant upside from technological
development and cracking the ‘codes’
• Significant infill drilling program driving
resource to reserve conversion
Slide 15Beach Energy Limited, Asian Roadshow – 4-7 July 2011
SACB/SWQ JV – Ultimate potential is significant
Source: Santos
Remaining gross unrisked resource potential of over 4 billion barrels of oil
equivalent
Slide 16Beach Energy Limited, Asian Roadshow – 4-7 July 2011
SACB/SWQ JV - GLNG Project supply opportunity
• Discussions ongoing between SACB JV
and Santos for the supply of 750 PJ to
Santos’ GLNG Project*:
– Beach’s share of supply would be
~ 152 PJ
– 15 year contract - proposed to
commence in 2014
– Oil-linked gas pricing
• Highlights strategic importance of
Cooper Basin asset base
• Potentially creates new export supply
opportunities
• Enhances various opportunities in
the Cooper Basin
* Discussions between the South Australian Cooper Basin Joint Venture (SACB JV) and Santos are incomplete, and the terms of any potential
agreement remain subject to ongoing dialogue between all relevant parties
Slide 17Beach Energy Limited, Asian Roadshow – 4-7 July 2011
The Cooper Basin shale gas potential
Slide 18Beach Energy Limited, Asian Roadshow – 4-7 July 2011
• PEL-218 (Permian JV) potential shale gas in
place 40-80 Tcf
• Similar properties to successful US shale plays
• Encounter-1 and Holdfast-1 both successful
due to:
– Target zones either in line or thicker than
anticipated (300-400 metres)
– Gas saturated and over-pressured with no
water through the target zone
• Flow stimulation at Holdfast-1 has
successfully been completed
• First flow results expected July
• Flow results will assist in designing the pilot
well program (early 2012) and booking of a shale
gas resource
A commanding Cooper Basin shale gas acreage position
Encouraging results to date – material resource booking anticipated in 2011
Slide 19Beach Energy Limited, Asian Roadshow – 4-7 July 2011
• Semi desert country
• Strong relationship with one
pastoral owner
• Thick target zone to yield
more gas in place
• Fracture containment not
an operational constraint
• Deep shale target zone at
3,400 metres
• Eromanga aquifers well
above shale target zone and
isolated behind two strings
of casing
Advantages of PEL 218 shale acreage
Eromanga aquifers isolated
from target zone
Slide 20Beach Energy Limited, Asian Roadshow – 4-7 July 2011
• Holdfast-1 fracture stimulation
completed in seven stages
• Stages completed:
– Roseneath shale (3)
– Epsilon formation (2)
– Murteree shale (1)
– Patchawarra formation (1)
Goals
• Design fracture stimulation
program
• Understand gas flow potential
• Book gas resource
• Prioritise targets for
development
• Determine gas in place volumes
Fracture stimulation successfully completed
PEL-218 represents a potential large scale resource play
Slide 21Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Comparison to US plays
Parameter PEL 218 Permian REM Barnett (Texas)
Haynesville
(Louisiana)
Depth (metres) 2,900 – 3,500 1,650 – 3,000 3,050 – 3,950
Shale thickness
(metres)120 – 260 75 – 150 60 – 90
Total Organic Carbon
Av%3 – 5 5 4
Pressure Gradient
(psi/ft)0.72 0.55 0.85
Gas in place (Av)
Bcf/sq.km40 - 80 40 80
Similar properties to successful US shale plays
Slide 22Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Beach has ‘core’ and flank Nappamerri acreage
• Shale gas plays cover
thousands of square
kilometres
• ‘Sweet spots’ (e.g.,
the ‘core’ Haynesville)
may exist particularly
where the shale target
zone is:
– In the deepest parts of
the acreage
– Over-pressured
– Thick
– Gas saturated
• Key to profitability is
large positions in
sweet spots
*
PEL 218 has the potential attributes to form a ‘core’ area
Slide 23Beach Energy Limited, Asian Roadshow – 4-7 July 2011
• Average well recovery: 9 bcf
• BG net wells: 275 (2011-15)
• Average well cost: US$9 million
(~US$1.0/mmbtu)
• Operating cost: US$1.4/mmbtu
• Unit technical cost: US$2.4/mmbtu
• Economic breakeven: US$3.2/mmbtu
BG Group - Haynesville ‘core’ economics*
0
0.5
1
1.5
2
2.5
3
Typical well (bcfpa)
Robust economics
Australian vs US fiscal regime
• No land acquisition costs in Australia, US
acquisition costs of up to US$15,000 per acre
• Government royalties of up to 10% (7.5%
after expense offset)
• US shale gas royalties reported to be 25% for
Haynesville
Source: BG Group - 8 February 2011
* The information contained in this slide is provided for comparative purposes only. This information should not be taken as representative of
expectations or likely outcomes in relation to Beach Group activities.
Slide 24Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Goodrich - Haynesville type curve*
Robust economics
Source: Goodrich Petroleum Corporation
Low (6.5 Bcfe) Base (7.5 Bcfe) High (8.5 Bcfe)
IP rate (MMcf/d) 14.0 15.5 19.5
IP rate (30 day avg. MMcf/d) 10.0 11.0 15.5
Gross EUR (Bcf) 6.5 7.5 8.5
Pretax IRR 20% 30% 49%
F&D ($/Mcfe) $1.87 $1.62 $1.43
PV10 ($MM) $2.0 $3.6 $5.6
Breakeven Price ($M/cf)(1) $3.75 $3.25 $2.75
Acreage Value (PV10/spacing) $25,553 $45,053 $70,027
(1) Natural gas price required to generate a pre-tax 10% rate of return.
* The information contained in this slide is provided for comparative purposes only. This information should not be taken as representative of
expectations or likely outcomes in relation to Beach Group activities. All prices in US dollars.
Note: Pretax IRR, F&D and PV10 figures assume $5.00/Mcf natural gas price (less $0.50/Mcf price differential), $8.5MM drilling and completion cost,
and 100%/70% working interest and net revenue interest, respectively. Acreage values calculated using 80-acre spacing for horizontal wells. LOE
estimated at $0.36/Mcfe over life of well. Severance tax abatement for first two years then $0.165/Mcfe thereafter.
Source: Goodrich Petroleum Corporation, EnerCom’s London Oil & Gas Conference, June 16 2011
Slide 25Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Shale gas - Cost reduction driven by…..
Technology
• Multi-stage fracture stimulation
techniques
• Pad drilling
Techniques
• Restrictive choke techniques being
adopted
• Choke settings reduced along with
initial production rates
• Rate of decline significantly less
(approximately half)
• Compression may be deferred four to
five years
…in turn reducing development
costs and increasing reserves and
production
Rate MMCFD: Conventional (24-28/64 “ choke) vs
‘optimised’ (14/64” choke)
Source: Frank D. Mango, Daniel M. Jarvie and Eleanor Herriman1. Proc Royal Soc, April 21, 2010
Slide 26Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Next steps and indicative timeline
With successful proof of concept:
• Design pilot horizontal wells targeting highest yield zones in REM
• Drill further vertical delineation wells across acreage
• Expand production pilot to multiple wells
• Seek to monetise early production via existing facilities
• Determine market potential and processing requirements
Encounter-1 well site
Drill and core Holdfast-1 & Encounter-1
vertical exploration
wells
Q4 2010/
Q1 2011
Fracture stimulate wells
~ 8 zones/well
Q2 2011
Flow test
Q3 2011
BOOK GAS RESOURCE
Q3 2011
Pilot Production
Wells
Q1/Q2 2012
Slide 27Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Dominant Western Flank oil
acreage position
Slide 28Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Cooper Basin – Western Flank Oil
Western Flank oil is a core contributor due to:
• High net back per barrel (total opex including
transport and royalty of approx. $25/barrel)
• Strong equity positions
• Quick drill and tie-in periods
• Established infrastructure
• High flow rates from wells
• Good understanding of the geology
• Multiple play types
Impress takeover:
• Completed in late April 2011
• Delivered 40% of highly prospective Western
Flank oil acreage with 7.9 million barrels of
oil reserves (gross), as booked by operator
A high profit area with significant
remaining exploration potential
Slide 29Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Potential risked reserves addition of six million barrels of oil
Western Flank drilling program
Beach operated
• Five exploration wells in PEL 91
(Beach 40%)
• Eleven wells in PEL 92 (Beach
75%), five exploration and six
development/appraisal wells
• Success rate to date is 64% from
eleven wells drilled
Senex operated
• Proposed ten well program
including four development
wells on the Growler field
• Identified 25 highly prospective
exploration targets covered by
3D seismic
Slide 30Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Birkhead Formation Channel Sand
Birkhead channels can be imaged on seismic, significantly reducing risk
Source – Senex, 2011
Slide 31Beach Energy Limited, Asian Roadshow – 4-7 July 2011
‘Big oil’ potential, Tanzania
Slide 32Beach Energy Limited, Asian Roadshow – 4-7 July 2011
• Beach 100%
• Underexplored area with high
potential
• Lake Tanganyika South acreage is
approximately 7,000 km2
• Potential for large (> 200 MMbbl)
discoveries:
– Natural oil seeps on Lake
Tanganyika indicate a working
petroleum system
• Airborne gradiometric gravity and
hi-resolution aeromagnetic data
acquired in 2010
• 2D seismic survey planned for
Q3/Q4 2011
Lake Tanganyika, Tanzania – East African Rift
Initial prospect and leads
generation in 2011
Slide 33Beach Energy Limited, Asian Roadshow – 4-7 July 2011
• Tullow identified this East African rift
basin opportunity in 2001
• Lake Albert area approximately
5,300km2
• The Lake Albert rift basin is part of a
string of Pliocene-Miocene age rift
basins that cut through East Africa
• Lake Albert characterised by
abundant oil seeps
• Oil in place estimated at 2.5 billion
barrels of oil
• 37 of 38 wells successful to date
• US$2.9 billion Tullow/Total/CNOOC
transaction* confirms East African
Rift potential
Lake Albert, Uganda – major success to date
Oil discoveries at Lake Albert have
been company and country changing
Source: Tullow Oil plc
* On 30 March 2011, Tullow announced the divestment of two thirds of its Lake
Albert acreage to CNOOC and Total for US$2.9 billion
Slide 34Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Lake Tanganyika natural oil seeps
Slide 35Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Lake Tanganyika South Seismic Line – 2D
Lake Tanganyika South vs Lake Albert - Analogy
1.5 sec -
2.0 sec -
2.5 sec -
Lake Albert Seismic Line – 3D
Deeper water in Lake Tanganyika
Source: Tullow Oil plc – EAPCE, 2011Source: Beach Energy Ltd – Project Probe data
Slide 36Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Lake Tanganyika North – Gazettal tender
• Tanzanian government recently
gazetted the Lake Tanganyika North
block
• Similar potential to South block based
on available seismic
• A competitive gazettal process with
nine companies submitting tenders
• Government evaluation of tenders
expected to be completed in
September
• Beach identified potential of the South
block and acquired it in 2008, PSA
finalised in 2010
Beach identified Lake Tanganyika
South potential ahead of competitors
Slide 37Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Egypt – Established and growing portfolio
Slide 38Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Egypt overview
• Beach interests range 15 – 22%
• An established and growing
portfolio
• Exposure to prolific and emerging
hydrocarbon basins:
– Portfolio of near-term
development & exploration
opportunities
• North Shadwan expected to
produce first oil in 2011
• Abu Sennan six well appraisal /
exploration program commenced
in December 2010
• Mesaha* has the potential to
contain 100 MMbbl+ targets
* Subject to Ministerial approval
Slide 39Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Abu Sennan concession
• Beach 22%
• 3D seismic coverage over whole
concession which has been the
key to success for Apache in the
surrounding tenements
• Apache recently acquired
tenements from BP adjacent to
Abu Sennan
• Initial six well program
underway, with the potential for
at least ten wells
• ZZ-4 well completed, oil shows
being evaluated
• Al Ahmadi well to spud
imminently
Slide 40Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Gulf of Suez
• Beach 20% interest
• High potential Gulf of Suez
acreage
• Three existing oil discoveries:
– NS 377 and 385
(‘near shore fields’)
– NS 394 ‘Burtocal’
• First oil expected in 2011
• North Shadwan delays due
to pipeline operator sign off
on oil mix in pipeline
• Proposed exploration well
for South East July in late
2011
Slide 41Beach Energy Limited, Asian Roadshow – 4-7 July 2011
• Beach interest 15%*
• One of the largest concession
areas in Egypt at 57,000km2
• Wildcat basin with the right
ingredients
• Possible rift basin similar to Gulf
of Suez/Lake Albert/Lake
Tanganyika
• Potential for very large oil fields
(~ 100 MMbbl+)
• 2D seismic activities completed
to delineate basin architecture
• Southern infill seismic being
acquired
Mesaha concession
*Subject to Ministerial approval Source: Melrose Resources plc - Investor presentation, 18 January 2011
Wildcat exploration with rift
graben potential
Slide 42Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Appendices
Slide 43Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Australian pipeline growth
Pre - 1995 Post - 1995
• Approx 10,500 km
• Point-to-point pipelines
• Majority government owned
• Approx 20,000 km
• Interconnected pipelines
• Privatisation
Source: APA investor presentation, April 2010
Slide 44Beach Energy Limited, Asian Roadshow – 4-7 July 2011
The importance of REM section for shale & tight gas
• Thick target section
• Gas charged
• Over-pressured
• Favourable mineralogy
• Lacustrine play, with similar
litho/geochem properties to
North American marine
shale plays
Key attributes confirmed to
date provide significant
encouragement
Slide 45Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Nappamerri Trough – thick Early Permian shale sequence
Shale play thickness:
• Roseneath 80-200 metres
• Epsilon ~100 metres
• Murteree ~80 metres
Over-pressured tight gas play:
• Epsilon – mid and basal zones
sandier
• Patchawarra – multiple sands
Other tight gas in section:
• Daralingie
• Toolachee
US shale plays:
• Haynesville 200 metre gross section
• Barnett 100 metre gross section
The REM target zone is a substantial shale gas target
Slide 46Beach Energy Limited, Asian Roadshow – 4-7 July 2011
PEL 218 Shale - Favourable mineralogy
The REM has similar mineralogy to major US shale plays
40-60% Clay:
• Similar to Barnett and Haynesville
10-20% Carbonate:
• Carbonate in the form of siderite
25-50% Quartz:
• Important for brittleness
Total Organic Carbon:
• Gas volumes – both adsorbed and
free
• Preliminary 3-5%
• Barnett/Haynesville/Eagleford 4-5%
0
20
40
60
80
100
Cla
ys %
020406080100
Carbonate %
0
20
40
60
80
100
Sil ica + other %
BarnetEagle FordHaynesvilleUticaNappamerri
BarnetHaynesvilleEagle FordUticaNappamerri
Slide 47Beach Energy Limited, Asian Roadshow – 4-7 July 2011
PEL 218 Shale - Over-pressured at REM level
0 2000 4000 6000 8000 10000
Pressure (psi)
0
1000
2000
3000
4000
Dep
th (m
)
Regional pressure data –over-pressures confined to Nappamerri Trough
Beach Acreage
The REM target zone is over-pressured
- desirable in US gas plays
Formations outside Trough
• Normally pressured - hydrostatic
gradient
• All 0.43 psi/ft
Exploration wells – in Trough
• Over-pressured
• DST information – Epsilon and
Patchawarra
• Mud weights Roseneath and deeper
• ~0.72 psi/ft
Pressure advantage:
• More gas stored
• More drive
• Eagleford 0.65 psi/ft
• Haynesville 0.85 psi/ft
Slide 48Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Parsons-1
Namur
PARSONS-1
Western Flank oil - Namur Sandstone
Namur Sandstones plays:
• Widespread high net to gross braided channel
environment
• Subtle structures delineated on 3D seismic data
• Very high permeability
• Parsons-3 clean up flow 5,200 bopd
Slide 49Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Western Flank oil - Birkhead Formation Channel Sand
Growler 3
Birkhead Sandstones plays:
• Deposited in meandering channels
• Do not necessarily rely on structural traps
– can be extensive accumulations
• Can be imaged on seismic data
Slide 50Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Tanzania – Attracting the majors
• Various phases of exploration
undertaken since 1952 with very
few exploration wells drilled
• Early wells drilled with poor quality
or inadequate seismic control
• Tanzania has now attracted
attention of the large players, eg:
– Shell
– Statoil
– Petrobras
– Exxon Mobil
– Total
Tanzania is becoming a frontier
exploration ‘hotspot’Source – TPDC, 2010
Slide 51Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Rift systems - Gulf of Suez vs Lake Tanganyika
Gulf of Suez:
• Rift valley system
• Area approximately
9,000km2
• 800+ exploration wells
drilled
• 9.5 billion barrels of oil
discovered
Lake Tanganyika
• Rift valley system
• Area approximately
32,900km2
• Two exploration wells
drilled
• No discoveries to date
Gulf of Suez Lake Tanganyika
Lake Tanganyika is more than three times the size of the Gulf of Suez
Slide 52Beach Energy Limited, Asian Roadshow – 4-7 July 2011
• Typical rift graben/half
graben geometries
• Seismic indicates large
structures with
bounding faults
• Play types are:
– Stratigraphic traps
– Fault traps
– Three way structured
traps against
basement
– Anticlinal traps
• These are similar to
successful play types in
Uganda, Lake Albert
Lake Tanganyika South – play types
Large stacked structures under Lake Albert appear similar to
those within the Lake Tanganyika South concession
Slide 53Beach Energy Limited, Asian Roadshow – 4-7 July 2011
• Eleven year PSA structured into
phases of 4 + 4 + 3 years
• Phase 1 minimum commitment
expenditure of ~ US$7 million
• One exploration well required in
Phase 2 & Phase 3
Phase 1 planned exploration
• Seismic reprocessing of previous
seismic data (in progress)
• Aeromagnetic, gradiometric
aerogravity and bathymetry survey
over entire PSA area (completed)
• Acquisition of 1,800 kilometres of
new 2D seismic data
• Review drilling options
Lake Tanganyika South – Beach exploration program
Beach will be undertaking the first multi-faceted
exploration program in Lake Tanganyika
Slide 54Beach Energy Limited, Asian Roadshow – 4-7 July 2011
Beach Energy Limited – Head office
25 Conyngham Street
Glenside SA 5065
Tel: +61 8 8338 2833
Fax: +61 8 8338 2336
Website: www.beachenergy.com.au
Chris Jamieson
Investor Relations Manager
Tel: +61 8 8338 2833
Mob: +61 8 (0)487 173 244
Email: [email protected]
Contact information