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Leverage exposure to conventional, shale and tight oil and gas exploration
April 2012
Disclaimer
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This presentation contains forward looking statements that are subject to riskfactors associated with oil and gas businesses. It is believed that theexpectations reflected in these statements are reasonable but they may beaffected by a variety of variables and changes in underlying assumptions whichcould cause actual results or trends to differ materially, including but not limitedto: price fluctuations, actual demand, currency fluctuations, drilling andproduction results, reserve estimates, loss of market, industry competition,environmental risks, physical risks, legislative, fiscal and regulatorydevelopments, economic and financial market conditions in various countriesand regions, political risks, project delay or advancement, approvals and costestimates.
All references to dollars, cents or $ in this presentation are to AUD currency,unless otherwise stated.
Corporate Snapshot• Shares on issue: 3,026m
• Market Cap: $54m (1.8c)
• Group Cash: $4.7m (at 31 March, $2.4m net to TSV)
• Debt: $7 million facility; drawn down $2 million
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Board of Directors Role
Bill Bloking Non Executive Chairman
Stephen Keenihan Managing Director
Brett Mitchell Executive Director
Will Barker Non Executive Director
Andrew Leibovitch Non Executive Director
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Apr‐11 May‐11 Jun‐11 Jul‐11 Aug‐11 Sep‐11 Oct‐11 Nov‐11 Dec‐11 Jan‐12 Feb‐12 Mar‐12
Million Shares
Closing Price (A$)
Daily Volume Traded On‐Market Daily Close Price
13.50%10.50%
10%
10%8%8%
40%
Craig Burton
Stephen Keenihan
Argonaut Investments
Charles Morgan
Brent Villemarette
Russell Stephenson
Others
The Assets
• Four Key Projects in Unconventional Plays– Warro Gas Project in Western Australia: 35-55% of ~40,000 gross acres
– Duvernay Shale and Rock Creek Project in Alberta, Canada: 34% of 84,500 acres
– Genesee tight oil project Alberta: 50% of 39,000 acres
– Carnaby Conventional and unconventional Oil and Gas Projects in British Columbia: 55% of 70,000 acres
• Land Acquisition Completed- Aggressive Drilling Program across all Projects in 2012
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Management Team
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TranservStephen KeenihanBrett Mitchell
Brent VillemaretteJo‐ann Long
CarnabyBil MathesonGarth Nicolson
Grant OhGord Oliver
WomaStephen Keenihan
Terry MeekMarcel Zowtuk
GeneseeTerry MeekJohn ThortonAl Pickering
Marcel Zowtuk
AJVMako
Terry MeekAl Pickering
Transerv Drilling Program & Outcome
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Location TSV interest Drilling Commencement Well type Target Depth
Reserveexpectation Gross Resource Cost to TSV
A$000 Current Status
per well Opportunity Warro
Warro‐5 35% 1st qrt 2013 vertical 4200mRT N/ATo confirm approx 3.2
TCF 1.1 TCF net
Nil proposed
Warro‐6 35% 2nd qrt 2013 vertical 4250mRT N/A Nil proposed
Warro‐7 35% 2nd qrt 2013 vertical 4300mRT N/A Nil proposed
Carnaby Energy
Belloy‐1 25% 3rd qrt 2012 horizontal 1800mRT+1000m hor 200k bbl 800k oil 475 identiffied
Conventional‐1 Gething 25% 3rd qrt 2012 vertical 1000mRT 75k bbl 600k oil 275 identified
Conventional‐2 tba 25% 4th qrt 2012 vertical 1300mRT 500k oil 275 under
review
Conventional‐3 tba 25% 5th qrt 2012 vertical 1500mRT 500k oil 275 under
review
Montney 55% 4th qrt 2012 horizontal 1900mRT+1000m hor N/A 36,000k oil 2420 under
review
Nordegg 55% 4th qrt 2012 core well 1000mRT N/A 4,000 550 underreview
Alberta JV
Duvernay‐1 6.80% 2/3 rd qrt 2012 vertical 3500Mrt N/A cored well Nil proposed
Duvernay‐2 6.80% ~4th Qrt 2012 horizontal 3500mRt+1500m hor 450k bbl 80,000k boe Nil pending
vretical
Rock Creek 1 34% 3rd qrt 2012 horizontal 2500mRT+1500m hor 200k boe 33,000k boe 1530 under
review
Rock Creek‐2 25% of 34% 4th qrt 2012 horizontal 2500mRT+1500m hor 200k boe 380 under
review
Genesee JV
Mannville‐1 50% 3rd qrt 2012 horizontal 1500mRT+1000m hor 200k bbl 1100 proposed
Mannville‐2 50% 4th qrt 2012 horizontal 1500m+10000m hor 200k bbl 23,000k bbl 1100 identified
The Warro Gas Project
• Warro located 200km north of Perth in the Perth Basin
• Onshore gas field discovered by WAPET in 1977
• One of the largest undeveloped onshore gas fields in Australia – total gas in place of 8-10TCF confirmed by recent studies
• Only 35km from key gas pipelines
• Transerv is operator with a 35% stake (post Alcoa farm in)
• Alcoa earning up to 65% stake by spending up to $100m (half spent to date) on exploration and development
• Alcoa are likely buyer of gas
Warro – The Story So Far• Four wells drilled to date – the last in
October, 2011
• First two wells (1977) confirmed presence of substantial gas but tight sands inhibited flow rates significantly
• Fraccing successfully employed at Warro 3 and 4 (2009 & 2011), resulting in significant gas flows
• Warro 3 and 4 produced associated water which limited gas flows
• Expert study has confirmed that wells that should produce commercial flow rates even with water production experienced
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Warro – The Independent Expert’s ViewShanley Review concluded :
• Warro contains significant gas accumulation with potential to flow at high rates
o 8 -10 TCF in place
o ~3.2 TCF recoverable
• Wells capable of 4 -10 BCF each (50 acre spacing) with existing water results and more (7 – 12 BCF) if it can be reduced or avoided
• Water is not the issue - similar to other tight gas fields in USA where water management is routine
• Water came from deep seated faults intercepted by wells
• 3D clearly shows these faults are localised and that there large parts of the field where they can be avoided to enhance production
• More drilling and testing is needed
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Fault Identification
Transverse Arbitrary LineWarro-3 Well
NW SE
Top Gas Sand
Transverse Arbitrary LineWarro-4, Warro-1 Wells
Top Gas Sand
3D clearly shows the location of faulting
Warro-3 and Warro-4 Wells lie in area with strongest faulting
Large areas without faulting
Warro – The Next Chapter
• Transerv believes review shows Warro is economic to develop
• Water is a manageable operational issue, as seen in analogous US fields
• Planning underway for Program of Work to drill, frac and test further wells in late 2012 or early 2013
• Discussions underway with Alcoa on details of drilling, scope, timing of work etc
• Depending on rig availability looking at single and/or 3 well back-to-back programme commencing late 2012/early 2013
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Business in Canada• Why Canada?
– Huge oil and gas area
– Very open system with plenty of opportunities (oil) and unconventionals at early stage
– Lots of information, low costs, extensive infrastructure and good terms
• Transerv in Canada
– After 2 years, land acquisition strategy complete
– Concentrating on oily unconventional resource plays
– Built a large, low cost acreage position >180,000 gross acres and 72,600 net acres at <$50/acre
– Leverage: a few wells will prove up substantial resource plays similar in size to Warro
– Drilling each play this year
– Strong Calgary based team
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3 mmbbl/d15 BCF/d
Unconventional Successes in Canada
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VikingBakken
Cardium ?Duvernay, MannvilleMontney, Nordegg
BritishColumbia
Alberta
Sask.
Location of Canadian assets
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Interests in over 290 sections across 2 provinces.
Approx 250km
Approx 30km
Duvernay and Rock Creek Alberta (TSV 34%)
Rock Creek and Duvernay Shale Assets
Original 132 gross sections (~83,500 acres).
– JV Average Cost $80/ha ($32/acre).
– Major emerging trend in shale and tight gas
– Partial divestment:
• 38 sections sold for $24 million
• Retained 20% (gross) in 30 with and carry through 2 wells (approx gross $20million cost).
• Retained Rock Creek 132 sections and 121 Duvernay sections (~80,000 gross acres)
– Potential: 30 mmboe net to TSV (TSV estimate using Macquarie Tristone resource assessment)
Drilling activity in 2012
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SIRIUS
Antelope
Conoco Est . 80+ bbl/mmcf from testBellatrix
Encana
Black Swan Proposed loc
Rock Creek drilling
2012 Duvernay Drilling activity
Duvernay Divestments
Future Well Locations
Carnaby – British Columbia (TSV 55%)
• Carnaby holds interests in over 103 sections (65,300 acres)
• 240 boe/d production, 1.14 mmboe 2P reserves, Operator on most project interests.
• Strong land position in proven oil and gas area
– 8+ pay zones in conventional plays
– On trend with recent discoveries in unconventional oil plays
• Well activity in 2012
– Unconventional Resource Plays (Montney and Nordegg)
– Field extension - Belloy.
– Bypassed pay.
• Potential: 23 mmboe net to TSV (TSV estimate using Discovery Group resource assessment)
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Montney Potential
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ARC res 13-18-82-17W6300 bopd, 1.8mmcfd7 wells planned in 2012
Crew 4-31-81-17W6342 bopd, 1.7 mmcfd
Chinook 6-31-85-13W640bopd
Carnaby recomplete6-17-83-14W6
West Energy Vert 8-31-82-14W6 (40bopd)
Genesee - Mannville in Alberta (TSV 50%)
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• Built resource play in Alberta on local knowledge and experience.
• Created large land position (50% of 39,000 acres) in areas of shallow, low-cost oil.
• Technology initiative as many wells with “by-passed” pay.
• Plenty of roll-out potential : 12mmbbl net
• Drilling in 2012.
Identified Well Locations
Mannville Offsets• Ravenwood HZ 4-31-48-1W5
190 bopd, 1750mcfd, 70 bwpd
• 13-6-49-1W598 bopd, 724 mcfd, 41 bwpd
• 3 more wells licensed
Asset Potential
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All figures are TSV estimates
470
70253334
58
Net Relative Risked Valueof Each Asset (A$m)
Warro
Carnaby
Duvernay Farmout
Divernay residual
Rock Creek
Genesee
59
23
6
1311
12
Net Unrisked Reserve Potential of Each Asset
(mmboe)
Value PropositionAggressive drilling programs across all four assets in second half of 2012
Western Australia– Warro decision to drill mid 2012
Canada – Proving the Resource Plays– Land acquisition completed
– Duvernay drilling underway mid 2012
– Rock Creek Drilling mid 2012
– Genesee tight oil drilling second half of 2012
– Carnaby Montney drilling in second half of 2012
Allocation of 2012 drilling funds
UnconventionalResource Plays
Conventional
Apr-12 May-12 Jun-12 Jul-12 Aug-12 Sep-12 Oct-12 Nov-12 Dec-12
Carnaby Carnaby and Genesee well prep
Siphon & Gething DevWells Belloy and Montney Wells
Genesee Tight Oil Seismic Tight Oil
Mako Rock Creek well
Duvernay well
Registered OfficeGround Floor1292 Hay Street West Perth WA 6005
Telephone
+61 8 6313 5790
Facsimile
+61 8 6313 5799
Website
www.transerv.com.au
This presentation contains forward looking statements that are subject to risk factors associated with oil and gas businesses. It isbelieved that the expectations reflected in these statements are reasonable but they may be affected by a variety of variables andchanges in underlying assumptions which could cause actual results or trends to differ materially, including but not limited to: pricefluctuations, actual demand, currency fluctuations, drilling and production results, reserve estimates, loss of market, industrycompetition, environmental risks, physical risks, legislative, fiscal and regulatory developments, economic and financial marketconditions in various countries and regions, political risks, project delay or advancement, approvals and cost estimates.
All references to dollars, cents or $ in this presentation are to AUD currency, unless otherwise stated.
Stephen KeenihanManaging Director
Brett MitchellExecutive Director