MEC RESOURCES LIMITED — Investor Presentation 2014

Aug 21, 2014

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22 August, 2014

Companies Announcements Office Australian Securities Exchange Limited 10[th] Floor, 20 Bridge Street SYDNEY NSW 2000

Dear Sir/Madam

Company Presentation SEAAOC Conference, Darwin

MEC Resources Ltd (ASX: MMR) is pleased to provide a copy of the presentation at the SEAAOC Conference.

A copy of the presentation is attached.

Yours faithfully,

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David Breeze Executive Director MEC Resources Ltd PO Box 317 North Perth WA 6906 Tel: +61 8 9328 8477

About MEC Resources

ASX listed MEC Resources (ASX: MMR) invests into exploration companies targeting potentially large energy and mineral resources. The Company has been registered by the Australian Federal Government as a Pooled Development Fund enabling most MEC shareholders to receive tax free capital gains on their shares and tax free dividends.

About Advent Energy

Advent Energy Ltd is an unlisted oil and gas exploration company held by major shareholders MEC Resources (ASX: MMR), BPH Energy (ASX: BPH), Grandbridge (ASX: GBA) and Talbot Group Investments. Advent holds a strong portfolio of near term development and exploration assets spanning highly prospective acreage onshore and offshore Australia in proven petroleum basins. Advent Energy’s asset base also incorporates both conventional and unconventional petroleum targets.

Notes: In accordance with ASX listing requirements, the geological information supplied in this report has been based on information provided by geologists who have had in excess of five years experience in their field of activity.

MEC is an exploration investment company and relies on the resource and ore reserve statements compiled by the companies in which it invests. All Mineral Resource and Reserve Statements have been previously published by the companies concerned. Summary data has been used. Unless otherwise stated all resource and reserve reporting complies with the relevant standards. Unless specified, resources quoted in this report equal 100% of the resource and may not represent MEC’s investees’ equity share.

MEC Resources Ltd

ACN 113 900 020

PO Box 317, North Perth, WA 6906 14 View Street, North Perth 6006, Western Australia T: +61 8 9328 8477 F: +61 8 9328 8733 info@mecresources.com.au www.mecresources.com.au

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SEAAOC- BONAPARTE BASIN August, 2014

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If Chevron 1000 ft is winning the lottery what is 5000 ft in Advents Bonaparte basin shale plays?!

Argentina wins shale lottery Monday, 26 May 2014

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“
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ARGENTINA has won the shale “lottery” with a 1000foot-thick Vaca Muerta formation, according to Chevron.

While commercial layers of shale formations may just be slithers of a broader sandwich of unproductive rock, Chevron spokesman Kent Robertson told Reuters that Argentina “kind of won the geological lottery” with its uniquely thick Vaca Muerta find.

“ Vaca Muerta is like one big cake, 1000 feet [305 metres] thick in places, which means one well can be much more productive," Robertson reportedly said.

The region is tipped to host other advantages. “One of the unique things about Vaca Muerta from an international perspective is that it is in an area where you've already got oil industry activity," Robertson told the newswire.

"There is already an established oil industry in the region where the shale is. You've got service companies, you've got pipelines and infrastructure.

“You've got existing assets that do not need to be recreated. Plus, you've also got a head start in that you have knowledge of the rocks." Chevron last month agreed to invest $US1.6 billion ($A1.73 billion) in Argentinian shale development, including to drill 170 wells in the Vaca Muerta with joint venture partner YPF.

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Further Information on Advent Energy’s Bonaparte Basin Unconventional Assets:

• The depositional environment in Australia is predominantly terrestrial vs. marine in North America. The predominant source rocks are coal and lacustrine shales as opposed to marine shales in North America. Advent Energy’s Milligans Formation (primary shale resource target) is shallow marine depositional source material.

The estimated shale resource potential in Australia appears massive with proximity to robust Asia-Pacific LNG markets. Activity in Australian unconventional plays will build momentum. (Circa 1400 TCF)

Nb: Net and gross thicknesses of the shales vary with different published sources

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ADVENT Gas Projects

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EP386 + RL1 RL1
Unconventional Resources Onshore Bonaparte Basin
9.8 TCF prospective Recoverable Conventional Resources
Milligans (shale) Conventional Weaber Gas Field:
Resources 356 BCF Prospective 45.8 BCF 3C Contingent Resources
Recoverable
2,734 km [2 ]
1,261 km [2 ]
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PEP11 (85% Advent) Offshore Sydney Basin Potential Huge Conventional Gas Resources 5.7 TCF Prospective Recoverable Resources

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4,649 km [2 ]
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Source: Basemap, Fred Kroh, Geoscience Australia

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Advent Energy 100% of EP386 & RL1

Advent Note:

The reservoir thickness from which the estimated 6 Tcf in the ACOLA report was based was 36m (120ft) of average net shale thickness in the Bonaparte Basin.

The thickness estimated from Advent’s well logs shows elevated gas levels from between 300m and 1700m indicating substantial prospective upside in shale gas resource for Advent’s Bonaparte Basin areas.

Source: Cook, P, Beck, V, Brereton, D, Clark, R, Fisher, B, Kentish, S, Toomey, J and Williams J (2013). Engineering energy: unconventional gas production . Report for the Australian Council of Learned Academies, www.acola.org.au

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Bonaparte Milligans Dry 2,752 6 1090 0.40 2.18

Source: Cook, P, Beck, V, Brereton, D, Clark, R, Fisher, B, Kentish, S, Toomey, J and Williams J (2013). Engineering energy: unconventional gas production . Report for the Australian Council of Learned Academies, www.acola.org.au

EP386 + RL1 Summary

• The Bonaparte Basin is a proven hydrocarbon producing basin representing 19% of Australian liquids and 17% of gas (2005 GA report). EP 386 and RL 1 are located on the southern, onshore part of the Bonaparte Basin. EP386 covers 2568km[2] in Western Australia and RL1 covers 166km[2] in the Northern Territory.

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Source: Geoscience Australia

This is an active hydrocarbon system EP 386 & RL/1: 7 conventional gas discovery wells – Onshore High Technical Success Rate

	Well	Well Classification	Flow Rates Observed (unstimulated)
	Bonaparte-1	Oil & gas shows
	Bonaparte-2	Gas Discovery	1.5 MMscf/d
	Keep River- 1	Gas Discovery	3.0 MMscf/d
	Ningbing-1	P& A (Oil & gas shows)
	Weaber-1	P & A (Bypassed pay)
	Weaber-1 (re-entry)	Gas Discovery	4.5 MMscf/d
	Weaber -2a	P & A (Gas shows)
	Garimala-1	Gas Discovery	0.75 MMscf/d
	Waggon Creek-1	Gas Discovery	1.3 MMscf/d
	Ningbing-2	P & A (Gas show)
	Weaber-4	Suspended (Gas)	2.1 MMscf/d
	Vienta-1	Gas Discovery	2.1 MMscf/d

Source: Geoscience Australia

“…organic-rich oil-prone anoxic marine mudstones are present, suggesting that similar units with good source potential may be developed in depocentres adjacent to the Turtle-Barnett High and in the Carlton Sub-basin .” (Australian Geological Survey Organisation)

Bonaparte Basin (WA/NT) EP 386 / RL-1 Shale and tight gas exploration

Ningbing-2: Elevated Gas Shows over Lower Milligans-Langfield Section

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Bonaparte Basin, Australia

Wide distribution of oil and gas shows and tests throughout basin Advent Energy has 100% of EP 386 & RL 1 including conventional gas discovery wells Vienta-1, Waggon Creek-1, Bonaparte-2, Garimala-1 & the Weaber Field

Elevated gas shows over 900m in shale/siltstone section. TOC from Lab matched well with computed value from logs and maximum TOC value can be up to 5% (right column).

This is an active hydrocarbon system

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Weaber-4 (RL1): Elevated Gas Shows over Upper & Lower Milligans Section

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Elevated gas shows over 600m in shale/siltstone section. TOC from Lab matched well with computed value from logs and maximum TOC value can be up to 5% (right column).

Geoscience Australia: GA6928; Petroleum Systems of the Bonaparte Basin

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Bonaparte Basin (WA/NT) EP 386 / RL-1 Shale and tight gas exploration

• Multiple petroleum targets are present in EP 386 & RL1 area:

• Proven conventional gas charged sandstone reservoirs in nearshore marine area of the Milligans Formation (Prospective Resources in EP386 increased to mean 556 Bcf), with potential for deeper prospective shales;

• Unconventional gas-condensate shale play in the shallow marine areas of Lower Milligans Formation;

• Unconventional tight gas sandstone and limestone reservoirs in the Langfield, Ningbing & Cockatoo groups below the Milligans Formation.

• Lower Milligans Formation shale is prospective for shale gas play with considerably large upside potential:

• Marine shale with moderate organic richness: TOC of over 4% from samples in wells within or in close proximity of EP 386. Higher TOC could be present in the area in the north & northeast of EP 386;

• Source rocks are mature for gas and oil generation: Ro range 0.44-2.42% & Tmax range from 430 to 480;

• Limited geochemical data indicates source rocks at depth shallower than c. 1400m are mature for gas/wet gas and oil generating windows, but overmature and in the dry gas generating window at depth below 1400m.

• The thickness of the prospective shale gas play is varied from 300m to over 1500m. This would provide significant upside in prospective shale gas resources

Unrisked OGIP for EP 386 & RL 1 could be in the range from c. 19 TCF to 141 TCF

Vienta-1: Elevated Gas Shows over mid-Upper & Lower Milligans Section

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Elevated Gas Shows Over Shaly & Silty Section of approximately 850 m

Garimala-1: Elevated Gas Shows over Milligans-Langfield Section

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Waggon Creek-1A: Elevated Gas Shows over Milligans Section

Elevated gas shows over 800m in shale/siltstone section. TOC from Lab matched well with computed value from logs and maximum TOC value can be up to 5% (right column).

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Elevated gas shows over 1700m in shale/siltstone section. TOC from Lab matched well with computed value from logs and maximum TOC value can be up to 5% (right column).

Bonaparte-2

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Gas Produced Zone

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Gas Producing Zone:
Sandstone with low GR, higher
density, Rt-deep > Rt-nor,
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1690-1694m/4m Potential Zones need further
investigation:
1711-1712m/1m 1: Similar Log properties to the
gas producing zone
2: Reservoir been contaminated
by drilling mud and DST tests
1740-1750m/10m not thoroughly conducted
1755-1756m/1m
1783-1784m/1m
1793-1796m/3m
1813-1822m/9m
1848-1860m/12m
1875-1890m/15m
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Bonaparte-2 (Con’)

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Gas Producing Zone:
Gas Produced Zone Sandstone with low GR, SP higher
density, Rt-deep > Rt-nor,
Potential Zones need further
investigation:
1: Similar Log properties to the
gas producing zone
1940-1942m/2m
2: Reservoir been contaminated
by drilling mud and DST tests
not thoroughly conducted
1970-1971m/1m
1979-1980m/1m
2054-2058m/4m
2080-2080.5m/0.5m
2086-2087m/2m
2091-2093m/2m
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Waggon Creek-1
Gas Producing Zone
416-417m/1m
492-495m/3m
563-569m/6m
Gas Producing Zone
606-612m/6m
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Gas Producing Zone: Sandstone with low GR, higher density, Rt, SP anormaly

Potential Zones need further investigation: Similar Log properties to the gas producing zone

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Weaber-4
1245-1246m/1m
1270-1281m/11m
1289-1290m/1m
1333-1345m/12m
Gas Produced Zone
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Gas Producing Zone: Sandstone with low GR, higher density, Rt, SP anormaly

Potential Zones need further investigation: Similar Log properties to the gas producing zone

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Garimala-1
1469--1479m/10m
1841--1850m/9m
1899--1902m/3m
1955--1972m/17m
2210--2216m/6m
Gas Producing Zone
2401--2211m/10m
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Gas Producing Zone: Sandstone with low GR, higher density, Rt

Potential Zones need further investigation: Similar Log properties to the gas producing zone

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Bonaparte Basin:

The Bonaparte Basin is currently Australia’s third most prolific offshore hydrocarbonproducing basin. A proven hydrocarbon producing basin representing 19% of Australian liquids and 17% of gas (2005 Geoscience Australia report). EP386 and RL1 are located on the southern, onshore portion of the Bonaparte Basin. EP386 covers 2568km[2] in Western Australia and RL1 covers 166km[2] in the Northern Territory.

Production development offshore was established since the 1980s at the Challis-Cassini, Jabiru, Laminaria, Laminaria East, Corallina, Buffalo, and Elang-Kakatua oilfields. The BayuUndan field is the key driver of the NT’s LNG export boom. (source)

Advent’s acreage is underexplored – 14 wells in 2,734km[2] – only 1 well for every 195km[2] .

Bonaparte Basin

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Bonaparte Basin

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Bonaparte Basin:

• Well-understood basin with readily available

• database of digital well and seismic.

• Known very thick accumulations of shale mature source rocks (up to 5000 feet).

• Multiple unconventional play types – tight gas, tight oil, shale gas and shale oil.

• Good gas indications on mudlogs throughout unconventional reservoirs.

• Significant resources assessed by Advent Energy.

• Strong commercial viability

• Excellent technical historic drilling success rates for hydrocarbons (65%).

• Existing infrastructure

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Bonaparte Basin:

Database on shale distribution.

Thermally mature shale source packages thorughout basin.

Bonaparte Basin

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Shale resource extent
constrained by limits of
seismic data
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Potentially both wet & dry shale gas plays throughout basin.

Advent Energy holds 2734km[2] of prospective acreage at 100%.

Gas-in-place Prospective Resources range from 24 - 101 Bcf/km[2] .

Exploration & appraisal programme in place

Bonaparte Basin

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Bonaparte Basin:

• Lower Milligans Formation shale is prospective for shale gas play with considerably large upside potential:

Garimala-1: Elevated gas shows over 1700m in shale/siltstone section. TOC from Lab matched well with computed value from logs and maximum TOC value can be up to 5% (right column).

• Marine shale with moderate organic richness: TOC of over 4% from samples in wells within or in close proximity of EP 386. Higher TOC could be present in the area in the north & northeast of EP 386;

• Source rocks are mature for gas and oil generation: Ro range 0.44-2.42% & Tmax range from 430 to 480;

• Limited geochemical data indicates source rocks at depth shallower than c. 1400m are mature for gas/wet gas and oil generating windows, but overmature and in the dry gas generating window at depth below 1400m.

• The thickness of the prospective shale gas play is varied from 300m to over 1500m. This would provide significant upside in prospective shale gas resources

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600 –
1700m
continuous
gas column
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Bonaparte Basin

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• Tight gas recognised as a major play in onshore basin (Geoscience Australia).

• Multiple tight gas & oil zones and discoveries in structural, stratigraphic and continuous accumulations

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Basin Comparison

Advent Energy’s Bonaparte Basin EP386 & RL1 Unconventional Assets Cooper Basin (source: Drillsearch, Beach Energy, Chevron)	Advent Energy’s Bonaparte Basin EP386 & RL1 Unconventional Assets Cooper Basin (source: Drillsearch, Beach Energy, Chevron)	Advent Energy’s Bonaparte Basin EP386 & RL1 Unconventional Assets Cooper Basin (source: Drillsearch, Beach Energy, Chevron)
Contribution to Australian Petroleum	A proven hydrocarbon producing basin representing 19% of Australian liquids and 17% of gas (2005 Geoscience Australia report).	Australia’s largest onshore Oil & Gas Basin
**Exploration Density **	Advent’s acreage is underexplored – 14 wells in 2,734km2– only 1 well for every 195km2	1 well per 20km2
Data	Well understood basin with readily available database of digital well and seismic	Well understood database of digital well and seismic
Hydrocarbon Source	Milligans formation up to 5000 feet thick (1500m+)	“REM” Shale Gas Play sequence 120-400m thick across the fairway
Risk	Excellent technical historic drilling success rates for hydrocarbons (65%)	Lower exploration risk than normally associated with oil and gas
Maturity	Potentially both wet & dry shale gas plays throughout basin	Potentially both wet & dry shale gas plays throughout basin
Resource Density	Gas-In-Place Prospective Resources range from 24- 101 Bcf/km2	Potential gas-in-place estimates range up to 20-100 Bcf/km2

Chevron / Beach SEA Mississippean Cooper Basin Sth Aust Niobra, Eagle Ford Beach / US ~$5,000 /acre ~$900/acre; Feb Adelaide Baytex/Aurora 2013 ( WSJ ) Cooper Basin Eagle Ford Texas Statoil / Beach core Petrofrontier Sth Aust ~$100,000 /acre ~$805/acre; Nappamerri ( The Aus. ) Georgina Basin 2011 ( WSJ ) Trough Sth Aust NT ~$26/acre; ~$1656/ acre 2012 ( Baraka ) (MPW)

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References:

Redfork Energy Feb 2014, IFM 2014, and Pawnee Energy Ltd MPW: Macquarie Private Wealth Baraka: Baraka Petroleum website, accessed 20/03/2014 WSJ: Wall Street Journal, accessed 20/03/2014 The Aus.: The Australian, accessed 20/03/2014

ACOLA Shale Gas Report

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Advent Energy’s 100% Owned Bonaparte Basin Acreage:

• •EP 386: 634,567 Acres = 2568 km[2 ]

• •RL 1: 41,019 Acres = 166 km[2 ]

• •Thermally Mature, Thick Source Rock (>500m)

•Large Unconventional Resources Complex (Gas & Oil) •Many Large Structures With Conventional Gas and Oil Discoveries

• ACOLA study confirms play

• extent in Bonaparte

Morgan Stanley June 2011:

“ 86 acreage transactions in the US since 2009 shows an average price per acre of US$5,500. ”

Mitsubishi Corp: $40m of work under Buru’s 2012 unconventional gas exploration program

ConocoPhillips: $109M Shale Gas JV with New Standard Energy Australia

Beach: HESS: $65 M Shale $36 M JV Gas JV with Falcon with Australia in Beetaloo Territory Basin Oil

EP386 & RL/1 Advent Energy 100%

Statoil: Contributing $25M JV with Petrofrontier for 1[st] phase in South Georgina Basin. Could escalate to $200M through phase 2 and 3

Chevron: $349M farmin with Beach Energy for 60%

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BG: $130M
Shale Gas
JV with QGC
in Cooper
Basin
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• “ two dozen companies are collectively intending to spend >US$500mn this year ”

Source: Cook, P, Beck, V, Brereton, D, Clark, R, Fisher, B, Kentish, S, Toomey, J and Williams J (2013). Engineering energy: unconventional gas production . Report for the Australian Council of Learned Academies, www.acola.org.au

	Lower Milligans Fm Upper Milligans Fm Tanmurra Fm		1.5 MMscf/d 2.1 MMscf/d Waggon Creek-1 1.3 MMscf/d
	Langfield Group		Weaber-1
			4.5 MMscf/d
			EP 386:Well-Well Correlation in EP386

U.S.G.S - Advent’s conventional / unconventional gas area / existing wells in EP386 / RL1 and U.S.G.S. inset showing “pod of Active Source Rocks Boundary”- U.S.G.S. onshore mean 56 MMBO (oil) and 460 B.C.F Gas Undiscovered Resource – Conventional Resource Assessment

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U.S. Geological Survey

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Bona arte Basin: Ke Information p y

Carboniferous Milligans Formation: Tight Gas, Shale Gas & Liquid Hydrocarbon Potential

• Key gas-prone source rocks

• Over 500m marine shale/mudstone

• TOC up to 4.3%

• Mature for oil and gas generation

• Elevated gas shows while drilling through the shaly and silty section

• Gas produced in conventional sandstone reservoirs from Waggon Creek-1 & Bonaparte-2 in EP386

• Oil recovered from Waggon Creek-1 on DST

Carboniferous Langfield Grp + Devonian Ningbing Grp & Cockatoo Grp: Tight Gas & Liquid Hydrocarbon Potential

• Stacked-carbonate and sandstone reservoirs

• Devonian source rock mature for oil and gas generation

• Gas produced from Weaber gas field in RL1 and Ningbing-1, Vienta-1 and Garimala-1 wells in EP386

• Oil sample extracted from core of Ningbing-1

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Australia tipped to overtake China in shale boom MATT CHAMBERS, THE AUSTRALIAN , JANUARY 20, 2014

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AUSTRALIA is being touted as the place most able to replicate the shale gas and oil success of the US, overtaking China, where exploration is struggling to gain traction, and other nations that pose too much regulatory risk. Boston consultant Lux Research has issued a study declaring Australia "the next big energy market" for shale ahead of China, which was once seen as having similar potential to the US. Australia beats other nations with potential shale and other unconventional resources because of know-how and government stability, Lux says.

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Source: Australian Unconventional Oil & Gas; Time to Ride the Wave, September 2013, RFC Ambrian

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For shale gas, TOCs should ideally be between 2.0% by weight (wt%) and 7.0wt%.

A value of approximately 0.5wt% is considered the minimum for an effective conventional source rock.

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Many of the North American plays have TOC values that exceed the ideal range, whilst most Australian plays fall comfortably within the optimum range.

Source: Australian Unconventional Oil & Gas; Time to Ride the Wave, September 2013, RFC Ambrian

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The graph below shows that the average vitrinite reflectance values for most of the plays fall into the optimum range of 1.0-3.0%.

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Source: Australian Unconventional Oil & Gas; Time to Ride the Wave, September 2013, RFC Ambrian

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Geoscience Australia Report

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EP 386: Key Deposition Centres in EP386

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Moogarooga Deep Waggon Creek Deep Vienta Deep
Tanmurra
Fm
Upper Milligans Fm
Lower Milligans
Fm
Langfield Group
Ningbing Group+
TWT
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Bonaparte Basin (WA/NT) EP 386 / RL-1 Shale and tight gas exploration

EP 386 Shale Gas Unrisked Prospective Resource Estimates

Lower Milligans Fm EP 386 & RL 1	Lower Milligans Fm EP 386 & RL 1	Lower Milligans Fm EP 386 & RL 1	Lower Milligans Fm EP 386 & RL 1	Lower Milligans Fm EP 386 & RL 1
Parameters	Unit	Low	Best	High
Area - A	Acres	197,683	296,525	345,946
PayThickness -h	Ft	1310	1640	1968
Net toGrossRatio- r	Dec. fraction	0.6	0.6	0.6
Effective Matrix Porosity-F~~m~~	Dec. fraction	0.02	0.03	0.04
Fracture porosity-F~~f~~	Dec. fraction	0.04	0.05	0.06
Formation VolumeFactor - FVF		70	75	75
Matrix WaterSaturation -S~~wm~~	Dec. fraction	0.6	0.58	0.55
Water saturation of the fracture porosity-S~~wf~~	Dec. fraction	0.5	0.4	0.3
Adsorbed Gas Storage Capacity -Gs	Scf/Ton	15	30	50
ShaleDensity-r	G/cm3	1.9	2.1	2.2
Original Gas In Place - OGIP	BCF	19,287	65,603	141,170
OGIPper sq.miles (per Section)	BCF	62	142	261
Assumed RecoveryFactor % 10 15 18
Prospective Gas Resources	BCF	1,929	9,840	25,411
Average Prospective Gas Resourcesper sq.km.	BCF	2.4	8.2	18.2
Average Prospective Gas Resourcesper sq.miles	BCF	6.2	21.2	47.0

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Shale resource extent
constrained by limits
of seismic data
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EP 386 & RL/1: Prospects/Lead Summary (showing Seismic lines)

- mean conventional recoverable 556 BCF

EP386 RL1 Prospect on Top Ningbing Grp Prospect on Top Langfield Grp Prospect on Top Lower Milligans Fm Waggon Creek Stratigraphic Trap	Unrisked OGIP & Prospective Recoverable Conventional Hydrocarbon Resources in EP386	Unrisked OGIP & Prospective Recoverable Conventional Hydrocarbon Resources in EP386	Unrisked OGIP & Prospective Recoverable Conventional Hydrocarbon Resources in EP386	Unrisked OGIP & Prospective Recoverable Conventional Hydrocarbon Resources in EP386	Unrisked OGIP & Prospective Recoverable Conventional Hydrocarbon Resources in EP386
		Low Estimate (BCF)	Best Estimate (BCF)	High Estimate (BCF)	Swanson’s Mean (BCF)
	OGIP	88.9	548	1,895	814.21
	Recoverable Gas	53.3	355.9	1,326.3	556.27
	Recoverable Condensate (MMbbl)	0.53	7.12	39.79	14.94
	Weaber Field 1C 2C 3C Mean Gas Initially In Place (Bcf) 0.33 13.9 54.1 21.9 Contingent Resources (Bcf) 0.25 11.5 45.8 18.4 Independently Assessed Contingent Resources in RL1: Weaber Gas Field

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EP386 / RL1 Gas Composition compared with industry standard

Name	Unit	Industry Average Natural Gas Composition / properties	Weaber- 1	Weaber- 4	Bonaparte- 2 (DST No6: 4712- 4819ft)	Garimala-1 (DST No2: 2381- 2401m)	Ningbing-2 (DST No3: 535-598m)	Ningbing-2 (DST No5: 410-412m)	Vienta-1	Waggon Creek-1	EP 386 Average
Methane (C1)	Mol %	86.98	92.85	94.45	79.90	94.3300	92.16	86.490	83.48	93.13	89.60
Ethane (C2)	Mol %	2.56	3.90	3.80	5.30	1.4579	2.48	1.820	9.98	4.02	4.09
Propane (C3)	Mol %	0.83	0.65	0.59	2.43	0.1060	1.26	0.810	3.34	1.27	1.31
Iso-Butane (iC4)	Mol %	0.12	0.06	0.05	0.42	0.0052	0.29	0.180	0.40	0.10	0.19
n-Butane (nC4)	Mol %	0.22	0.08	0.06	0.39	0.0079	0.33	0.090	0.74	0.21	0.24
Iso-Pentane (iC5)	Mol %	0.06	0.03	0.03	0.13	0.0033	0.14	0.040	0.05	0.05	0.06
n-Pentane (nC5)	Mol %	0.05	0.01	0.01	0.03	0.0009	0.11	0.120	0.21	0.04	0.07
Nitrogen (N2)	Mol %	7.99	0.92	0.97	7.90	0.9375	2.48	9.710	1.69	1.06	3.21
Carbon Dioxide (CO2)	Mol %	1.07	1.50	0.00	0.35	3.1468	0.30	0.260		0.00	0.69
Hexanes (nC6)	Mol %	0.06	0.01	0.02	Traces	0.0006	0.14	0.400	0.11	0.05
Heptanes (nC7)	Mol %	0.05	0.01	0.02		0.0019	0.12	0.050		0.03
Octanes (nC8)	Mol %	0.01	0.00			0.0070	0.10	0.030		0.03
Nontanes (nC9)	Mol %	0.00					0.09	0.000		0.01
O2	Mol %	0.00	<0.01		3.20
Total Un-normalised	Mol %	99.70
	MJ/m
Heating Value	3	36.18	38.39			36.6700	39.57	35.958		39.65	38.05
Wobbe Index		45.60
Compressibility		1.00
Specific Gravity		0.63	0.60			0.5970	0.62	0.632		0.60	0.6096
HCDP	Deg C	-4.02
Cricondentherm	Deg C	-1.49

Bonaparte Basin- A Proven Hydrocarbon Producing Basin

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EP386 & RL1 Gas Reservoirs

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38

State of Western Australia

 Economy of Western Australia is equal to 50[th] biggest country globally underpinned by resources including LNG, Iron Ore, Diamonds, Coal, Agriculture, Gold and Aluminium

• Australia forecast to be world’s largest LNG exporter

 “WA exports more than half the value of all of the USA’s merchandise exports to China. WA by itself matters in China” WA Premier Colin Barnett

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Onshore Bonaparte Basin Advent gas project area

Resource projects proximal to Advent gas project area

Argyle Diamond Mine

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39

Lake Argyle

Ord Irrigation Area

Lake Argyle:

• Stage Two of the Ord River scheme has significantly enhanced road access to the Vienta Gas Field

Surface area of 1,000 square km (18 times the size of Sydney Harbour)

• Stage Two Ord roads capable of road train access are to be constructed during 2012/2013 - allows for construction CNG /MINI LNG

Storage capacity of 10,763,000 ML

• WA Govt. is completing construction of infrastructure for Stage Two of the Ord scheme and expects to complete key roadworks by 2013

Largest reservoir in Australia

Ord Irrigation Area Phase II

40

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Blacktip Pipeline 75km
Ichthys Pipeline 260km
WA Resources Ltd
Sea Dragon Project
Darwin-Amadeus
Pipeline 300km
Planned future
Wyndham Port:
Import/Export Facilities Northern
Sorby Hills
Pb/Zn/Ag Mine Territory Stage
Ord Scheme
Ord Phase 1
Stage Two Ord
Scheme (2013)
Dampier-Bunbury
Argyle Diamond Mine (150km)
Natural Gas Pipeline Savannah Nickel Mine (250km)
1350km Panton PGM Project (300km)
EP386 & RL1 – Onshore Bonaparte Basin, Northern Australia
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Adjacent Port of Wyndham:

Wyndham Port is the only deep-water port between Broome and Darwin. Exports include oil, iron ore, live cattle and nickel. Imports include fuel oil, ammonium nitrate for the mining industry (in particular Argyle Diamond Mine) and general cargo. The port is predominantly for servicing of commercial and trade vessels and is a designated maritime security facility. LNG tankers can access Wyndham Port.

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LNG Plants

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Our LNG production facility in Snurrevarden, Norway, fully fitted with remote monitoring and control capabilities, was the first free-standing small scale LNG plant in Northern Europe.

http://www.wartsila.com/en/oil-gas/onshore/applications/lng-terminals

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44

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LNG

Production, Storage, Distribution & Use

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Advent Growth Strategy

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PEP11
Field Development: Domestic Gas
Offshore Sydney Basin Exploration /
Sales /
5.7 Tcf Prospective Appraisal;
Export Gas (LNG)
Conventional Gas Resources
EP386 & RL1
Onshore Bonaparte Basin Exploration /
Field Development
9.8 Tcf Prospective Appraisal; Pilot
Export Gas (LNG)
Unconventional / Shale Gas Production
Resources
Domestic Gas Sales –
EP386 Exploration / Appraisal;
Remote Power Generation
Onshore Bonaparte Basin Field Development
Long Haul Vehicles, Mine Heavy
356 Bcf Prospective Pipeline Sales + Virtual
Vehicles
Conventional Gas Resources Pipeline: CNG / micro-LNG
Chemical Industry
RL1 – Weaber Gas Field
Field Development
Onshore Bonaparte Basin Domestic Gas Sales – Remote Power
Virtual Pipeline:
11.5 Bcf 2C Contingent Generation
CNG / micro-LNG
Conventional Gas Resources
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46

Mid Term

Short Term

Long Term

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ADVENT Ener Ltd. – Summar gy y

Late stage Exploration with early stage Production wells

Low-risk, high-return pipeline 4 petroleum titles and 20 validated wells

Focus on low-entry-cost projects with massive deposits

Booming demand for gas and shortage of supply in Asia

Experienced and high-demand management team in place

• ADVENT’s four key petroleum titles contain all the elements seen in other producing, world class petroleum basins, and have an aggregate Prospective recoverable Resources of over 15 TCF (Best Estimate).

• The aggregate area of all four permits exceeds 6,800 km[2]

• Multiple petroleum targets are present in EP386 & RL1 – Lower Milligans Fm shale is prospective for shale gas play with considerably large upside potential. All wells have been independently validated for gas/methane content.

• The thickness of the prospective shale gas play varies from over 300 m to over 1,500 m.

• Unconventional OGIP for EP386 & RL1 estimated in the range from 19 TCF to 141 TCF in Milligans Formation shales, with additional potential in deeper prospective shales. Conservative independent assessments for the region provide a 6 TCF Prospective Resource

• Federal and State Government investment into the Kununurra/East Kimberley region exceeding $500 million and will bring infrastructure within 15 km of the Vienta gas discovery.

• Management & board members hold over 75 years combined oil industry experience, mainly from Schlumberger Asia.

• Exceptional advisory panel with international oil industry experience.

44 7

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Public Disclaimer

This company presentation (the “Company Presentation”) of Advent Energy Limited (the “Company”) has been prepared by the Company solely for information purposes and for the sole use of the person to whom it is delivered. The Presentation is prepared for discussion purposes only. The Presentation does not constitute, and should not be construed as, any offer or invitation or recommendation to buy or sell any of the securities mentioned or described herein. This Company Presentation and the information contained herein is strictly confidential and may not be distributed, reproduced or used, in whole or in part, without the consent of the Company and may not be used for any purpose other than the evaluation of the business of the Company by the person to whom this Company Presentation is delivered. The distribution of it and any offering, subscription, purchase or sale of securities issued by the Company may in certain jurisdictions (including but not limited to USA, Canada, Japan, Australia and Hong Kong) be restricted by law. Applications for shares (if any) will only be considered on the terms of the final application terms if and when issued. This Company Presentation has not been and will not be reviewed or registered with any public authority or stock exchange.

The Company does not make any representation or warranty (whether express or implied) as to the correctness or completeness of the information contained herein, & the Company nor any of its respective parent or subsidiary undertakings or any such person’s affiliates, directors, employees, representatives or advisors assume any liability connected to the Company Presentation and/or the statements herein.

The contents of this Company Presentation are not to be construed as financial, legal, business, investment or tax advice. Each recipient should consult with its own financial, legal, business, investment and tax advisers as to financial, legal, business, investment and tax advice. By attending or receiving this Company Presentation you acknowledge that you will be solely responsible for your own assessment of the market and the market position of the Company and that you will conduct your own analysis & be solely responsible for forming your own view of the potential future performance of the Company’s business & an investment in the Company. An investment in the Company involves significant risks, & several factors could cause the actual results, performance or achievements of the Company to be materially different from any future results, performance or achievements that may be expressed or implied by information in this Company Presentation.

Included in this Company Presentation are various “forward-looking statements”, including but not limited to statements regarding the intent, opinion, belief or current expectations of the Company and/or its management with respect to, among other things, (i) goals and strategies, (ii) plans for new business development, (iii) marketing plans and the Company’s target markets, (iv) evaluation of the Company's markets, competition and competitive position, and (v) trends which may be expressed or implied by financial or other information or statements contained herein. Such forward-looking statements are not guarantees of future performance and involve known and unknown risks, uncertainties and other factors that may cause the actual results, performance and outcomes to be materially different from any future results, performance or outcomes expressed or implied by such forward-looking statements.

The distribution of this Company Presentation and the offering, subscription, purchase or sale of shares, issued by the Company in certain jurisdictions is restricted by law. Persons into whose possession this Company Presentation may come are required to inform themselves of and to comply with all applicable laws and regulations in force in any jurisdiction in or from which it invests or receives or possesses this Company Presentation and must obtain any consent, approval or permission required under the laws and regulations in force in such jurisdiction, and the Company shall not have any responsibility or liability for these obligations. This Presentation does not constitute an offer to sell or a solicitation of an offer to buy any securities in any jurisdiction to any person to whom it is unlawful to make such an offer or solicitation to in such jurisdiction. The Company’s Securities have not been and will not be registered under the U.S. Securities Act of1933, as amended (the "Securities Act") or the securities laws of any state of the United States.

The Company Presentation is made and reflects views as of August 2014. As a recipient of the Company Presentation you accept that the information contained herein may be subject to changes. The Company does not intend, and does not assume any obligation, to update or correct any information included in this Company Presentation.

This Company Presentation is subject to Australian law. Any dispute arising from this Company Presentation is subject to the jurisdiction of the Australian courts.

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David Breeze Director

Advent Energy Limited 14 View Street North Perth WA 6006 Australia

Ph +61 8 9328 8711 Fax +61 8 9328 8733

david@adventenergy.com.au www.adventenergy.com.au