Canamax is a TSX-V listed oil and gas company focused on acquiring and developing micro-cap assets. It has completed 5 acquisitions and 1 farm-in in the last 12 months, bringing production to 1200 boe/d as of July 2014. Canamax has a strong balance sheet with $6.7 million in cash and no debt. Key assets include the Flood property with 42 sections of Montney oil plays and infrastructure, providing multiple drilling locations. Management aims to grow production to 2000-3000 boe/d in the next 12-24 months through acquisitions and exploitation of existing assets.

1. Corporate Presentation
TSX.V September 2014
TSXV.CAC
Consolidating Micro Caps, Exploiting Quality Assets

2. CertainstatementscontainedinthisPresentationconstituteforward-lookingstatementsorinformation(collectively"forward-lookingstatements")withinthemeaningofapplicablesecuritieslegislation.Allstatementsotherthanstatementsofhistoricalfactareforward-lookingstatements.Forward-lookingstatementsareoften,butnotalways,identifiedbytheuseofwordssuchas"seek","anticipate",“opinion","continue","estimate","expect", "may","will","project","predict","potential","targeting","intend","could","might","should","believe",“plans”andsimilarexpressions.Thesestatementsinvolveknownandunknownrisks,uncertaintiesandotherfactorsfacingtheCorporation.Risks,uncertaintiesandotherfactorsmaybebeyondtheCorporation'scontrolandmaycauseactualresultsoreventstodiffermateriallyfromthoseanticipatedinsuchforward-lookingstatements. Canamaxbelievesthattheexpectationsreflectedintheseforward-lookingstatementsarereasonable,butnoassurancecanbegiventhattheseexpectationswillprovetobecorrectandsuchforward-lookingstatementsincludedinthisPresentationshouldnotbeundulyrelieduponbyinvestors.ThesestatementsspeakonlyasatthedateofthisPresentationandareexpresslyqualified,intheirentirety,bythiscautionarystatement.Inparticular,thisPresentationcontainsforward-lookingstatementspertainingtothefollowing:futureplansandoperations;reserveestimates;expectationsofinitialandfutureproduction;cashflow;capitalexpenditures; productiontargets;drillinginventoryandlocations;netbacks;developmentpotential;developmentandcompletionplans;productionacquisitioncosts;andacquisitions.
Withrespecttoforward-lookingstatementscontainedinthisPresentation,Canamaxhasmadeassumptionsregarding,amongotherthings,resultsoffutureoperations,thelegislativeandregulatoryenvironmentsofthejurisdictionswhereCanamaxcarriesonbusinessorhasoperations,theimpactofincreasingcompetitionandCanamax’sabilitytoobtainadditionalfinancingonsatisfactoryterms.Canamax’sactualresultscoulddiffermateriallyfromthoseanticipatedintheseforward-lookingstatementsasaresultoftheriskfactorsincludedinthisPresentationsuchas:theimpactofgeneraleconomicconditions;industryconditions;volatilityinthemarketpricesfornaturalgasandcrudeoil;currencyfluctuations;uncertaintiesassociatedwithestimatingreserves;geological,technical,drillingandprocessingproblems;liabilitiesandrisks,includingenvironmentalliabilitiesandrisksinherentinnaturalgasandcrudeoiloperations;stockmarketvolatility;theabilitytoaccesssufficientcapital;incorrectassessmentsofthevalueofacquisitions;and,competitionfor,amongotherthings,capital, acquisitionofreserves,undevelopedlands,equipment,servicesandskilledpersonnel.
Thisforward-lookinginformationrepresentsCanamax’sviewsasatthedateofthisPresentationandsuchinformationshouldnotberelieduponasrepresentingitsviewsasofanydatesubsequenttothedateofthisPresentation.Canamaxhasattemptedtoidentifyimportantfactorsthatcouldcauseactualresults,performanceorachievementstovaryfromthosecurrentexpectationsorestimatesexpressedorimpliedbytheforward- lookinginformation.However,theremaybeotherfactorsthatcauseresults,performanceorachievementsnottobeasexpectedorestimatedandthatcouldcauseactualresults,performanceorachievementstodiffermateriallyfromcurrentexpectations.Therecanbenoassurancethatforward-lookinginformationwillprovetobeaccurate,asresultsandfutureeventscoulddiffermateriallyfromthoseexpectedorestimatedinsuchstatements.Accordingly,readersshouldnotplaceunduerelianceonforward-lookinginformation.
Theforward-lookingstatementscontainedinthisPresentationspeakonlyasofthedateofthisPresentation.Canamaxdoesnotundertakeanyobligationtopubliclyupdateorreviseanyforward-lookingstatements,whetherasaresultofnewinformation,futureeventsorotherwise,unlessrequiredbyapplicablesecuritieslaws.
Unduerelianceshouldnotbeplacedonmanagement'sassessmentofreserveestimates,potentialdrillinglocationsandinitialandpotentialproductionrates.AllreferencestosuchinformationcontainedhereinarebaseduponinternaltargetsaspreparedbymanagementofCanamaxandarenotanestimateofreserves,resourcesorofproductionratesthatmayactuallybeachieved.Suchinformationhasbeenprovidedtoassistthereaderinunderstandingcertainprincipalfactorsuponwhichmanagementhasreliedinmakingcapitalinvestmentdecisionsandforinternalbudgetpreparation.ReservepotentialinformationprovidedinthisPresentationincludesbothdiscoveredandundiscoveredresourcesandrecoverablereservecharacteristics,andthereisnocertaintythatanyportionoftheundiscoveredresourceswillbediscoveredand,ifdiscovered,thatanyvolumeswouldbeeconomicallyviableortechnicallyfeasibletorecoverorproduce.UnduerelianceshouldnotbeplacedonestimatesofreservepotentialintermsofassumingCanamax'sreservesorrecoverableresources.AllestimatesofreservepotentialcontainedhereinarebaseduponinternalestimatesofmanagementofCanamax.
ThisPresentationcontainsreferencestoOriginalOilinPlace("OOIP")whichisequivalenttoestimatesofoilandgasclassifiedasDiscoveredPetroleuminitiallyinPlace("DPIP")whicharenot,andshouldnotbeconfusedwithoilandgasreserves."DiscoveredPetroleumInitiallyinPlace"isdefinedintheCanadianOilandGasEvaluationHandbook(the"COGEHandbook")asthequantityofhydrocarbonsthatareestimated,asofagivendate,tobecontainedinknownaccumulations.DPIPisdividedintorecoverableandunrecoverableportions,withtheestimatedfuturerecoverableportionclassifiedasreservesandContingentResources,asdefinedintheCOGEHandbook.ThereisnocertaintythatitwillbeeconomicallyviableortechnicallyfeasibletoproduceanyportionoftheDPIPexcepttotheextentidentifiedasprovedorprobablereserves.Resourcesdonotconstitute,andshouldnotbeconfusedwith,reserves.ItshouldbenotedthatgiventhecurrentearlystageofdevelopmentofCanamax'sproperties,estimatesofDPIPpotentialmightchangesignificantlyinthefuturewithfurtherdevelopmentactivityandtheamountofContingentResourceshasyettobeestimated.Theresourcepotentialestimatesprovidedhereinareestimatesonlyandtheactualresourcesmaybegreaterthanorlessthantheestimatesprovidedherein.ArecoveryprojectcannotbedefinedforthesevolumesofDPIPatthistime.Thereisnocertaintythatitwillbeeconomicallyviableortechnicallyfeasibletoproduceanyportionofthesepotentialresources.
TheinformationcontainedinthisPresentationdoesnotpurporttobeall-inclusiveortocontainallinformationthataprospectiveinvestormayrequire.ProspectiveinvestorsareencouragedtoconducttheirownanalysisandreviewsofCanamaxandoftheinformationcontainedinthisPresentationandthepublicrecord.Withoutlimitation,prospectiveinvestorsshouldconsidertheadviceoftheirfinancial,legal,accounting,taxandotheradvisorsandsuchotherfactorstheyconsiderappropriateininvestigatingandanalyzingCanamax.AdditionalinformationrelatingtoCanamaxisavailableontheCanadianSystemforElectronicDocumentandAnalysisandRetrieval(“SEDAR”)atwww.sedar.com
Anyfinancialoutlookorfuture-orientedfinancialinformation,asdefinedbyapplicablesecuritieslegislation,hasbeenapprovedbymanagementofCanamax.Suchfinancialoutlookorfuture-orientedfinancialinformationisprovidedforthepurposeofprovidinginformationaboutmanagement'scurrentexpectationsandplansrelatingtothefuture.Readersarecautionedthatrelianceonsuchinformationmaynotbeappropriateforotherpurposes.
2
Reader Advisory and Cautionary Statements

3. •Corporate and property acquisitions at accretive financial metrics
•Exploit low risk development opportunities
•Top tier technical and financial competence
•Oil weighted producer with low risk core property
•Build focused suite of assets attractive to dividend paying companies
The Opportunity
•Off to a great start in 2014
•Completed 5accretive deals and 1 farm-in in last 12 months
•July exit production –1200 boe/d (61% Oil & NGL’s)
•Closed 3 financings -$20mm gross proceeds since Sept 2013
•Strong balance sheet –No debt
2014 Execution
•Focus onconsolidationin core areas
•Targeting 2,000-3,000 boe/d in 12-24 months
•Combination of acquisition and exploitation
•Multi-year inventory of low risk drillinglocations (80-170 wells currently)
Visible Growth
3
Growing shareholder value

4. Fall 2013
•Flood-Expand Energy acquisition for net $0.7mm, large Montneyoil play, 100% WI, 37 sections
•BrazeauRiver –Acquired 100% WI in 2.25 sections –no up front investment, recompleted 2 wells in Cardium
•Wapiti-Completed farm-in -drilled horizontal Cardiumwell–Stabilized current gross production 115 boe/d
Q1 -2014
•Purchased additional Flood assets –5.0 net sections, 50 boe/d and infrastructure for $1.1mm – continues on strategy to consolidate in core areas
•Acquisition of Ki Exploration for $6.2mm (3.0mm shares and assumed net debt)
•330 boe/d production
•Metrics -$19,000 boe/d and 3.0x trailing cashflow
•Completed financing for $13.0mm to fund Ki acquisition and 2014 Capex
Q2-Q3
2014
•Announced capital budget for remainder of 2014 –increased to net $18.0mm
•Infrastructure will increase corporate netbacks
•Rounded out management and operations team capable for expansion to 3000 -5000 boe/d
•Commenced drilling and recompletion program earlier than expected with favorable initial results
•Sold Delta West for $2.4mm –50 bbls/d
4
Many accomplishments to date –Off to a great start in 2014
Targeted calendar 2014 exit production rate of 1,575-1,675 boe/d (65% Oil & NGL’s)

5. 5
Corporate Snapshot
StockExchange
TSX.V–Symbol CAC
Currentshare price –at Sept 16, 2014
$1.39
Current warrant price –at Sept 16,2014 ($2.40 warrants –expire March 2016)
$0.17
Capital Structure
Commonstock (basic)
(diluted)
(Insider ownership –fully diluted)
Market Capitalization –Diluted (Diluted shares plus trading warrants)
Cash and working capital –May 31, 2014
Enterprise value –Diluted
Banklines available
EV per boe/d (based on July 25, 2014 production)
41.3mm
44.2mm
15%
$62.9mm
$6.7mm
$56.2mm
$10.0mm
~$47,000
(1)Lower netback due to one time maintenance costs on newly acquired Ki Exploration wells
Management is targeting net backs in the low to mid $30.00 range
Production and Reserves
Production –(as at July 25, 2014)
Oil & NGL’s %
1P Value (as at Feb 28, 2014)
2P Value (as at Feb 28, 2014)
Undeveloped land (Net acres)
Field Net Back (quarter ended May 31, 2014) (1)
1200 boe/d
61%
$34mm
$55mm
~53,000
$26/boe

6. 6
CanamaxCore Areas
Alberta
Edmonton
Calgary
Grand Prairie
FLOOD
WAPITI
BRAZEAU RIVER
RETLAW
BrazeauRiver (100%)
•Cardiumand Belly River light oil
•4 producing vertical wells
•Multi-zone development (3 sections)
NORTH WEST ALBERTA
WEST CENTRAL ALBERTA
SOUTHERN ALBERTA
Retlaw(Approx75% WI)
•Mannvillemedium gravity oil & shallow cretaciousgas; 32 net sections; good seismic coverage
•Increased production from 170 boe/d to net 300 boe/d since April 30, 2014 acquisition with minimal capital
Flood (100% WI)
•Montneyoil; 42 sections & infrastructure;
•OOIP 5.0MMboe per section,
•Large vertical well development property
•10 producing vertical wells
•2014 YTD –2 new drills and 4 recompletes –8 more wells Q4
Wapiti (70% WI)
•Cardiumlightoil
•Farm-in earning well drilled
•Horizontal well development property

7. 7
Flood –Large OOIP Montneyoil play –great initial results
July 25, 2014 production 350 boe/d (85% liquids)
Total of 42 net sections with 28.5km2of 3D seismic
All infrastructure to achieve high net backs
True stackable production –not a resource play
Low decline rates, water floodable, vertical wells
Drill, complete and tie-in cost of approx. $0.8mm –85+ locations identified to date
Similar economics to Saskatchewan “Viking oil play”
MontneySiltstone potential on approx. 12 sections – prospective for future vertical or Hz development
Acreage is on trend with Worsley, Dixonvilleand GrimshawMontneyoil fields
Major activity in the area with the majority of the discoveries in mid-2000’s
LEGEND
Canamax100% Lands
Recent Asset Purchase
Montneyformation
CanamaxProducers
MontneyOil Offsetting Production
Pool
Montney A
Montney C
Triassic D
Montney F
MontneyC
Operator
CNRL
Spyglass
Storm
Petrus
Canamax
Founder
Blue Mt
Trigger
Belamont
Devon
Expand
Strike Area
Worseley
Dixonville
Grimshaw
Tangent
Flood
Discovered
2004
2004
2007
2006
2011
Producers
37
111
11
22
10
Injectors
9
81
1
0
1
Production (boe/d)
576
2,687
241
215
350
Cumulative Oil (bbl)
1,751,657
8,305,576
460,155
936,457
200,000
Worlsey
Dixonville
Grimshaw
Information as of March 2014 (Accumap)
3D Seismic Coverage
Oil Battery
Injector Well
Recent drills
Potential Montney
Siltstone Area
Gas Sales Line & Compressor

8. 8
Flood -Comparison to Viking play
Company
Raging River
Whitecap
Beaumont
Canamax
Asset
Dodsland
Lucky Hills
Kerrobert
Flood
Assumptions
Well Cost
($MM)
$0.90
$0.93
$0.90
$0.80
IP 30
(boe/d)
60
120
85
70
Liquids
(%)
95%
80%
96%
86%
Yr1 Decline
(%)
60%
80%
80%
50%
Yr2 Decline
(%)
10%
20%
8%
10%
Yr3 Decline
(%)
5%
5%
3%
9%
Yr4 Decline
(%)
5%
5%
3%
9%
EUR
(mboe)
49.5
80.0
56.5
75
Liquids Content
(%)
96%
80%
98%
85%
Economics
1
2
3
4
IRR
(%)
85.0%
127.4%
121.9%
137%
NPV(10%)
($MM)
$1.2
$1.8
$1.9
$1.7
Payout
(years)
1.0
0.5
0.7
1.0
F+D
($/boe)
$18.18
$11.63
$15.93
$11.10
Recycle
(netback/F+D)
2.8x
3.9x
4.1x
5.4x
Investment Ratio
(NPV10/inv)
129%
188%
210%
212%
0
20
40
60
80
100
120
1
3
5
7
9
11
13
15
17
19
21
23
25
27
29
31
33
35
RRX - Dodsland
WCP - Lucky Hills
Beaumont - Kerrobert
CAC - Flood
Key assumptions include:
•Typecurve based on average of first three wells with over 30 days production and production history of acquired wells
•EUR is based on primaryrecovery
•Formation is good candidate for waterfloodand could increase recovery by approximately 25,000 boe/well and reduce F&D costs to $8.00/boe
Months on production
Daily Production (boe/d)
Type Curve Comparison

9. 9
Flood –Current development plan –low risk development
Phase 1 -2014
Bring on water disposal facility and reactivate 4 wells
Recomplete 4 acquired wellbores
Drill and complete 2 wells
•Drill and complete 8 wells –Q4
•Complete infrastructure including pipeline to injection facility, and tie in to gas sales line
•Capex spend $15.0mm
Second Phase 2015
•10 Vertical Wells
First Phase 2014
•10 Vertical Wells
Reserve Parameters
Unit
MontneyOil
OOIP (* per section)
MMbls
5.0
API
Degree
27
Recovery Factor
%
19
Recoverable Oil *
MMbls
0.98
Recoverable Gas *
BCF
1.1
Recoverable Boe*
MMBOE
1.15
Singlewell economics
NPV10
$1.7mm
•Pool size and future development could increase based on delineation and operational success
Phase 2
•Second phase drilling commences H1 of 2015
•Drill and complete an additional 10 vertical wells
•Capex spend $8.0mm
LEGEND
CanamaxLands
Phase 1 Location
Phase 1 Completed
Phase 2 Location
Work-over Well

10. 10
Management internal reserve estimates @ 100% WI
Wapiti –CardiumOil
Newly Acquired Section
New 9-21 Hz Cardium Well on Production
Reserve Parameters
Unit
Wapiti
OOIP (per section)
MMbls
4.7
API
Degree
42.0
Recovery Factor
%
8.1
Recoverable Oil
MMbls
0.5
Recoverable Gas
BCF
1.5
Recoverable Boe
MMBOE
0.8
Singlewell economics
NPV10
$3.2mm
LEGEND
Producing Well
Horizontal Location
•Prolific sections –can add 500bbl/d of stabilized, low decline production and 1.0mmbbls recoverable
•Farm-in –net interest 70% in 2.25 sections
•Earning well at 9-21-67-8W6 has been drilled & completed as Cardiumoil well –on production March 25
•IP 30 rate 405 BOE/d (net 284 boe/d -86% Oil & NGL)
•Stabilized production of gross 115 boe/d
•7 additional development locations –all horizontal wells
•Gross cost to drill, complete and equip -$3.5mm
•2014 Capex budget = 1 Hz well $2.5mm net –spud mid October

11. Canamax holds 100% WI in 3.0 sections
4 Producing wells
1,320 mmcfgas production (220 boe/d)
120 bblsper day oil production
Gas compressor installed to improve efficiency and remove third party fees
Canamaxowns drilling pads and pipelines
Multi-zone potential
Proven Cardiumoil
Belly River –“G” & Basal Zones
Potential to add 600bbls of stabilized production
8 potential locations
11
BrazeauRiver –multi-zone potential –large OOIP
Management internal reserve estimates @ 100% WI
Multi-Zone Potential Reserve Parameters
Unit
Middle Belly River (G Zone)
Basal Zone
Cardium
OOIP (per section)
MMbls
8.1
6.1
4.5
API
Degree
42.0
42.0
45.0
Recovery Factor
%
3.7%
4.9%
5.3%
Recoverable Oil
MMbls
0.3
0.3
0.2
Recoverable Gas
BCF
0.7
0.7
1.5
Recoverable Boe
MMBOE
0.4
0.4
0.4
CanamaxLands
DeethreeLands
Belly River Production
CardiumProduction
MannvilleProduction
Belly River G
Basal Belly River
Belly River Play
Vertical Well Locations
CardiumPlay
Upper Mannville(Wilrich) Play
WilrichRecomplete

12. 12
Retlawarea
Producing net 300 boe/d (40% oil & liquids)
75% of production is operated
Large land position of 51.1 gross sections (31.9 net)
Good seismic coverage on Upside lands; 56km2of 3D and 116 km of 2D
Pipelines with access to facilities
Year round access
Glauconiterecomplete identified new channel –2 follow-up wells
Multi-zone potential
Shallow low cost targets <1200 m depth
RETLAW FOCUS AREA MAP
Many acquisitions in the area, followed up by successful drilling
Horizontal Glauconitechannels being targeted with results over 200 boe/d IP30 rates in the direct area
Good divestment candidate once developed, many active suitors
Area Activity Heating Up
Re-evaluate seismic data
Low cost recompletions to test concepts
Upcoming drilling location Q4 2014
Near Term Development Plan
LEGEND
CanamaxLands
CanamaxWells

13. 2014 Capital Budget -$20.5mm (1)
Flood $15.0mm
Wapiti $2.9mm
Brazeau $0.5mm
Retlaw $2.1mm
13
June –Dec 2014 Capital Budget
•Recomplete 4 wells
•Drill and complete 10 wells
•Tie-in’s and infrastructure
•Land, production & royalty purchases
•Drill, complete and equip 1 well (0.7 net)
•Recomplete 1 Wilrichwell
•Drill and complete new Glauconitewell
•Recomplete and equip 4 wells
Estimated incremental production range for 2014 Capital Budget 950-1,050 boe/d (IP 90)
Resulting flowing efficiency rate of approximately $20,000 per boe
(1) Net capex of $18.0mm after sale of Delta West property for $2.4mm
* Canamaxmay make changes to its capital expenditure budget depending on a number of factors, including drilling and and completion results, business conditions, commodity
prices and prospective acquisitions and divestitures.

14. 400
600
800
1,000
1,200
1,400
1,600
1,800
Dec-13
Jan-14
Feb-14
Mar-14
Apr-14
May-14
Jun-14
Jul-14
Aug-14
Sep-14
Oct-14
Nov-14
Dec-14
Estimated Production Growth
High Case
Low Case
14
Production + Cash Flow Summary –Actual & Forecast
Estimated production additions in second half of 2014 reflect capital budget
BOE/D
June/July Production
Note: BrazeauRiver production was
shut in due to plant turnaround
from June 15 to July 7
Target Exit Production
Target 65% Oil
& NGL’s
-20% 20% 60% 100% 140% Dec-13Jan-14Feb-14Mar-14Apr-14May-14Jun-14Jul-14Aug-14Sep-14Oct-14Nov-14Dec-14 Relative Performance (%) Share Price VS Cash Flow & Production per ShareShare PriceCF/ShareProduction/Share

15. 15
Exploitation program –Low risk development
(1) Management estimates
Total Development Potential(1)
Area
Description
Zone
WorkingInterest
Net CapitalRequired
Low Case
NetCapitalRequired
High Case
Est NetProduction
IP (365) LowCase
Est Net Production
IP (365) High Case
%
($mm)
($mm)
(Boe/d)
(Boe/d)
Flood
60–150 Vertical wells
Montney
100
$51.0
$127.0
2520
6,300
Brazeau
2 –Hz wells
Belly River G
100
$9.0
$9.0
300
375
4–Hz wells
Basal Belly River
100
$18.0
$18.0
600
750
2 –Vertical wells
Cardium
100
$3.5
$3.5
170
265
2 –Hz wells
Wilrich
100
$17.0
$17.0
1,000
1,790
Wapiti
7 –HZ wells
Cardium
70
$14.7
$14.7
700
1,050
Hines Creek
1–Hz well
Montney
75
$1.5
$1.5
60
100
Retlaw
1 –Recompletion
Glauconite
100
$0.3
$0.3
20
40
Retlaw
2–Vertical wells
Glauconite
100
$2.0
$2.0
150
200
Retlaw
1–HZ well
Glauconite
100
$2.0
$2.0
100
160
Totals
82-172 Wells
$110.0
$186.0
5,620
11,030

16. 16
Experienced Management and Board
MANAGEMENT
Brad Gabel –President & CEO and Director
•Involved in numerous acquisitions and divestitures (private and public companies) -$360mm
•President of Pure Energy Services (TSX Listed sold for $280m),
•Founder & CEO of Canadian Sub-Surface (was TSX listed)
Jeremy Krukowski, P.Eng–Chief Operating Officer
•VP Operations for RimfireEnergy Inc. start-up to 600 boe/d, Manager of Operations at Onyx (2006) Inc.–start-up to 600 boe/d, Manager of Operations at Onyx O&G Ltd.–start-up to 1,600 boe/d
Chris Martin, C.A. –VP Finance and CFO
•VP Finance and CFO of Pure Energy Services, Canadian Sub- Surface Energy Services, Jet Energy and CalvalleyPetroleum
•Involved in numerous acquisitions and divestitures
Karen Genoway–Landman
•VP Land at Onyx O&G Ltd. and RimfireEnergy Inc., VP Land at EnerplusCorp.
Nabil Khouri, P. Geol–Geologist
•Over 45 years experience in WCSB. Worked with Pan Canadian, Amerada Hess, Onyx, Ascot and Rimfire
BOARDOF DIRECTORS
Kevin Adair –Executive Chairman –President & CEOof Petrus Resources
Hugh Ross –Director –President &CEO of Novus
Mark Shilling –Director
Stuart McDowall–Director
Allan King –Director
Kevin Delaney -Director
OPERATIONAL & EXECUTIVE TEAM
IanBuchanan –Internal legal counsel and corporate secretary
Jeremy Yee –Land Manager
Jeff Lane, P.Eng–Operations& Production Manager
Bonnie Lamming CA-Controller
Gary Sveinson–Production manager

17. 17
Investment highlights
•Littlecompetition in microcap acquisition space –management has proven track record
•Top tier technical competence –demonstrated by recent optimization and recompletion programs
•Focused on capital efficiency –most accretive development
How we are different
•Relationships with financial institutions to access potential acquisition targets
•Additional prospects identified
•Environment remains rich with opportunities
Acquisition Pipeline
•Focus on consolidation of quality assets in core areas
•Maintain strong balance sheet
•Acquisition, low risk exploitation, and asset optimization
•Multi year inventory of drilling locations
Disciplined & Focused

18. June 2014
Appendix

19. 19
Options and Warrants
Options and Warrants
Stock Options
Exercise Price
ExpiryDates
Proceeds
273,833
$0.60
Feb-17
$164,300
1,079,168
$1.08
Oct-18
$1,165,501
934,999
$1.36
Apr-19
$1,271,599
110,000
$1.42
May-19
$156,200
525,000
$1.69
Aug-19
$887,250
2,923,000
$3,644,850
Warrants
Exercise Price
ExpiryDates
Proceeds
500,000
$0.60
Oct-14 & Feb-15
$300,000
3,775,571
$0.60
Sept-15
$2,822,155
575,481
$1.25
May-15
$719,351
8,489,254
$2.40
Mar-16
$20,215,716
13,340,306
$24,215,716
Totals
16,263,306
$27,862,566