Artificial Lift Techniques And Production Optimization Canada 2014

Canada’s Only Congress Designed 100% For Production Professionals Seeking To Maximize Recovery, And Reduce Downtime And Production Costs In Western Canada’s Tight Oil Plays. Optimizing Production Strategies For The Full Lifecycle Of The Well To Maximize Long-Term Recovery

Examining How Operators Are Optimizing Artificial Lift And EOR TechniquesIn Horizontal Wells To Manage Steep Declines, Reduce Downtime And Maximize Ultimate Recovery In Canada’s Shale & Tight Oil Plays

Main Topics To Be Addressed Include:

March 25-26, 2014 | Calgary | Canada

HEARING FROM E&P OPERATORS INCLUDING...

Organized By: Headline Sponsor:

w w w . a r t i f i c i a l - l i f t - p r o d u c t i o n - c a n a d a - 2 0 1 4 . c o m

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•ARTIFICAL LIFT SELECTION: Comparing rod pumps, PCPs, gas lift, jet

pumps & ESPs to determine which yields the highest economic recovery at the

lowest failure rate

•LANDING THE PUMP: Evaluating best practices for lowering pumps into the

lateral to increase production whilst minimizing wear on the curve

•MITIGATING SAND & GAS HAZARDS: Assessing strategies for controlling

sand, fines and gas locking to reduce damage to surface equipment and

prevent costly workovers

•CHEMICAL TREATMENTS: Evaluating the use of inhibitors and dispersants to

effectively reduce wax, asphaltenes and scale build up and ensure optimal run

time of the artificial lift

•AUTOMATION: Evaluating the accuracy of automation to remotely monitor and

diagnose operational issues in surface and downhole equipment

•WATERFLOOD & EOR CRITREA: Evaluating results from EOR methods to

assess their effectiveness in maximizing ultimate recovery in WCSB wells

Ron DavisonVP EngineeringBeaumont Energy

Matthew WortmannSenior Production EngineerHalcón Resources

Mike DupontSenior Staff Reservoir EngineerPenn West Exploration

Chandran PeringodSenior Staff Production EngineerShell

Chris ClarkProduction ManagerLiberty Resources

Register By FridayDecember 13, 2013

Glenn WildePresidentRevive Energy Corp

Richard SuffronVP OperationsHarvest Operations

Ransis KaisSenior Staff Production EngineerApache Corporation

Last year, CAPP estimated that tight oil

production in Alberta would reach 408,000

bpd by 2030. This year CAPP increased that

prediction to 703,000 bpd by 2030. Indeed,

the influx in Canadian tight oil production

is evident with some unconventional oil

producers boasting growth in reserves and

production as high as 18% and 7% annually

over the past 10 years with increased

exploitation of oil fields such as the Duvernay,

Montney and Bakken. However, in order

for the full potential of these estimates

to be realized, operators need to reduce

production costs and plan for the full life

cycle of the well; from artificial selection,

landing the pump, mitigating sand and gas

hazards, to chemical treatments, automation,

and EOR. It is believed that with time,

production costs can be driven below $60/bbl

in light, tight oil production. However, in order

to achieve this operators must first optimize

every stage of the production cycle.

The Artificial Lift Techniques And

Production Optimization Canada 2014,

taking place in Calgary on March 25 and

26, is the first congress designed solely

for production professionals in Western

Canada. The E&P-led congress will deliver a

comprehensive technical agenda that seeks

to reduce downtime and maximize recovery

in Canada’s low-perm, shale and tight oil

plays such as the Montney, Cardium, Viking,

Duvernay, Bakken, Slave Point, and Swan

Hills. Production executives, VPs, managers

and technical experts will be will evaluate

primary production economics, equipment

selection and field development to reduce

production costs. Operators will be delivering

case studies on how to optimize artificial

lift and EOR techniques in shale and tight

oil wells to lengthen production between

workovers and maximize ultimate recovery.

Day one will focus on artificial lift selection

and execution of ESP, PCP, jet pump, gas

lift, and rod pumping in tight oil reservoirs.

This will be followed by discussions on pump

placement in the deviated section, pump rate

and how to optimally manage pressure loss

downhole and specifically outline the criteria

for selecting the most cost effective, high

return artificial lift method.

Day two will examine how operators are

designing field development for the full

lifecycle of production and evaluating EOR

potential in tight oil plays. Case studies will

examine chemical treatment and separator

technology for mitigating operational hazards

such as sand and fines migration, wax

precipitation and gas locking to lengthen

production between workovers and reduce

downtime. Operators will outline successful

applications of EOR schemes including

water and gas flooding.

Venue InformationSponsorship And Exhibition Opportunities Available At The Congress

Need to generate new sales leads, launch a new product, engage key decision makers, build new future business relationships in key markets, or simply educate the industry about a new product? Then you need to exhibit at the Artificial Lift Techniques & Production Optimization Canada 2014. Our busy exhibit area is an integral part of the Congress and is of genuine practical value to delegates, who are looking for new solutions and technologies. Exhibiting at the congress will help you position yourself as a market leader and centre of excellence to the key decision makers in the industry.

For further information, please contact: [email protected]

or + (1) 800 721 3915

Artificial Lift Techniques & Production

Optimization Canada 2014 will be held at:

BMO Centre

20 Roundup Way

Calgary, Alberta, Canada

T2G-2W1

Phone: (403) 261-0531

www.artificial-lift-production-canada-2014.com + (1) 800 721 3915 [email protected]

SAVE $400

Register By FridayDecember 13, 2013

ARTIFICIAL LIFT SELECTION AND OPTIMIZATION: Day one will examine how operators select artificial lift methods, manage pressure loss downhole and evaluate the optimal application of pumping methods in tight reservoirs to quickly recovery well costs and enhance primary recovery

Day 1Tuesday March 25, 2014

8.30 Chair’s Opening Remarks

Chaired by: Dhunay Nav, CTO, PumpWELLKEYNOTE ADDRESS: PRODUCTION ECONOMICS

8.40 How Operators Are Planning Flexible Primary Recovery Schemes To Reduce Downtime And Maximize Production Economics

•Analyzingsitelogisticsandoperationalmanagementsuchasautomationandcrewrequirementstodetermineoptimalmeansofmonitoringproductiontoreducedowntimeandoperationalcost

•Evaluatingstrategiesforoptimizingartificialliftequipmentselection,sizing,anddesigntoensurelongevityoftheequipmentandcontinuedproduction

•Examiningstrategiesforextendingproductiontimebetweenfailuresandensuringworkoversarebeingexecutedproperlytosaveonlongtermexpenditure

•Understandinghowtodevelopproductionfacilitiesandsurfaceinfrastructuretomaximizeproductionandenablelongtermfielddevelopment

Richard Suffron, VP Operations, Harvest OperationsKrzysztof Palka, President & CEO, PumpWELL9.40 Question & Answer Session

ARTIFICIAL LIFT SELECTION CRITERIAIdentifying The Optimum Artificial Lift System To Manage

Sharp Declines In Production

ARTIFICIAL LIFT SELECTION AND NEW TECHNOLOGIES PANEL

10.00 Examining New Artificial Lift Technologies And Optimizing Artificial Lift Design For The Whole Life Cycle Of The Well: Equipping The Well For Initial And Declined Production To Maximize Reserves

•Evaluatingreservoircharacteristicsandinfrastructurecriteriatoselectoptimalpumpsizeandartificialliftapplicationforprimaryproduction:° Potentialsandandfinesmigration° Forecastedinitialflowrateandprojecteddecline° Accesstosite,electricity,wellspacing° Softwaretoolsforartificialliftselection° Failuredatabasesandeconomicsdata

•Initiallypreparingthewellboretofitprimaryliftmechanismwhilefacilitatingtheinstalmentofsubsequentpumpsorplungerlifttoequipthewellforfutureproduction

•Evaluatingwhichliftmechanismhastheoptimalcapacitytomitigategasinterferencedownholetominimizegaslocking

•Calculatingtheoptimalsizingofartificialliftequipmenttoensuremaximumrecoveryandeconomicviability

•Whatistherequiredfrequencyofperiodicintegratedfieldreviewstoensuretheartificialliftselectionisoptimalforlifecycleassetmanagement

•ExaminingnewtechnologiesforproducingshaleandtightoilinCanadatoovercomeextremeweatherconditionsatsurface,anddeep,lowporosityandpermeabilityandhighGORatsubsurface

Chandran Peringod, Senior Staff Production Engineer, Shell CanadaRansis Kais, Senior Staff Production Engineer, Apache10.30 Question & Answer Session10.40 Morning Refreshments In Exhibition Showcase Area

ARTIFICIAL LIFT APPLICATIONSExamining Case Studies From The Application Of Rod Pump,

Pcp, Gas Lift, Jet Pump, And Esps To Determine Optimal Lift Methods For Tight Oil Wells

GAS LIFT: CASE STUDY

11.10 Outlining The Minimum Rates You Can Run Gas Lift On And The Infrastructure Costs Involved To Determine Its Feasibility As A Production Technique

•Determiningthepointatwhichtostopthegasliftandrunapumptounderstandtherunlifeofthepump

•Consideringtheavailabilityofsurfaceinfrastructureandspaceneededtorunapipetoassessthelogisticalfeasibilityofrunningagaslift

•Examiningthecostandavailabilityofgassource,compressionequipment&pipelinetoassesstheeconomicsofusingthismethod

•Determiningtheusefulnessofgaslifttominimizeoperationalhazardssuchasgaslocking

•Definingthelowestbottomholepressureyoucanachievefordepletingareservoirtounderstandhowitcompareswithrodpumps

Richard Tracey, Production Engineer, Journey Energy11.40 Question & Answer Session11.50 Lunch In Exhibition Showcase Area

JET PUMP: CASE STUDY

12.50 Examining Criteria Of Jet Pumps In Terms Of Size, Cost, Failures, And High Draw Down Rate To Determine The Optimal Application Of Jet Pump•Examiningthemaximumlimitationsonjetpumpsforsand

andsolidsintaketoevaluateusefulnessinmid-highsolidcontentreservoirs

•Examininghowoperatorsarekeepingjetpumpscleanofsandtoavoidplugging

•Determiningwhetherincreasedinitialproductionrateisworththeriskofreducedlongtermrecoveryfromresultanthighdrawdownrate

•Evaluatingthebenefitsofthesizeofjetpumpstoaccessremoteareasandreducesurfaceimpact

•Analyzingthecostvs.increasedrecoveryinuseofjetpumpduringinitialproduction

Christopher Clark, Production Manager, Liberty Resources1.20 Question & Answer Session

ROD PUMP: ROD DESIGN

1.30 How Operators Are Designing More Durable Rods To Handle Dog Legs, Reduce Breakages During Pumping And Decrease Downtime•Optimizingrodstringwithwheelguidestoreducefriction

whilepumpingandmitigateroddamage•Evaluatingdoglegsandprojectedsideloadingto

developruggedroddesigntomeetthereservoirandwellboredemands

•Comparingmetalvs.rubberscrapersappliedtotherodstringtoevaluatewhichismoredurableandmoreeffectiveinscrapingthewax

•Assessingtheapplicationofpolyethylenelinerandpolycortubingtoeffectivelyreducedamagetotheroddownhole

Shawna Bonini, Senior Production and Operations Engineer, SM Energy2.00 Question & Answer Session

ESP: CASE STUDY

2.10 Measuring Expected Production Against Initial Costs Of ESPs To Determine If The Increased Life Of The Well Justifies Expenditure•HearingthelatestproductionresultsusinganESPtoassess

theextenttowhichthefasterpumpratecanincreasethedeclinecurve

•AssessingthelowestproductionatwhichESPscanrunwithoutfailingtodeterminethepointatwhichtheycannolongerbeused

•AsessingthefailurerateofESPscurrentlybeingusedtodefinethetotalrunlifethatcanbeexpected

•Understandingtherotarysystem’ssandcapacityandexaminingtheeffectivenessofscreenstoalleviatesandblockinginESP’s

Kevin Kyle, Production Engineer, Halcón ResourcesMatt Wortmann, Production Engineer, Halcón Resources2.40 Question & Answer Session2.50 Afternoon Refreshments In Exhibition Showcase Area

PCP: CASE STUDY

3.20 Analyzing Increased Pumping Rate Vs. Elastomer And Rod Wear In To Determine The Cost-Effectiveness Of PCPs•Examiningthecriteriaforreservoirandwellconditionsto

enableuseofPCPinlight,tightoilproduction° Flowrate° Wellborecurvedesign° Oilquality,viscosity° Downholetemperature

•AnalyzingelastomerselectioninPCPtoprovidelongestrunlifeinhightemperaturelightoilreservoirs

•ExaminingBHC,rodandtubingselectiontoenablethesuccessfulapplicationofPCPwithminimalfailures

•DetermininghowlowintothedeviatedsectionandatwhatanglePCPcanbeplacedtofacilitategreaterflowrateswithoutdamagingequipment

•AnalyzingresultantflowratesandrunlifeofPCPinlightoiltodeterminefeasibilityofuse

3.50 Question & Answer Session

LANDING THE PUMP AND OPTIMAL PUMP RATE

Evaluating Optimal Pump Placement In The Curve And

Pump Rate To Enhance Initial Recovery Without Damaging

Equipment And Wellbore

LANDING THE PUMP

4.00 Examining The Curve Section, Flow Rates And Rod Limitations To Determine Optimal Pump Placement And Minimize Run Time

•Analyzinghowfarpumpscanbepusheddowninthehorizontalsectionwithoutcausingmajorrodandtubingwear

•Examiningoptimallengthandangleoftangentlengthtoreducedoglegsandimproveinitialpumpplacementtoavoidre-landinganddowntime

•Analyzingwhichpumpmethodcanbelandeddeepestintothecurveandatwhatangletofacilitatehigherflowratewithoutdamagingthewellbore

•Examiningtheuseofcoatedtubingaroundthecurvesectiontomitigatefailuresandequipmentwear

Matt Krawiec, Production Engineer, Penn West Exploration4.30 Question & Answer Session

HOW HARD TO PUMP

4.40 Determining When To Pump And Optimal Pump Rate To Recover Operational Costs Without Bypassing Liquids Or Lowering Pressure

•Examiningthetransitionfromflowingtopumpingtodetermineoptimaltimetostartpumping

•Howtooptimallypumpthewellboreduringflumpingstagetopumpwithinequipmentlimitationsandavoidoilflowingintotheannulus

•Determiningtheoptimalspeedandmethodofpumpingtorecoverhighrateswithoutcausingerosionalissuesatsurface

•Examiningwhetherslowerinitialpumpingcaneffectivelymaintainpressurelongerandincreaselongtermproduction


PRESSURE MAINTENANCE

5.20 Examining Optimum Techniques For Monitoring Reservoir Pressure To Measure Fluctuations And Decrease Pressure Loss

•Examiningnewmethodsformeasuringpressuredownholewithoutdisruptingproductiontoincreaseaccuracyofreadings

•Evaluatingeffectivenessofacousticwellssurveystoaccuratelyrecordpressureatsurface

•Examiningtheshortestshut-intimepossibletoaccuratelyrecordpressuretomitigatedowntime

•Examiningoffsetdataandfracanalysistodefinereservoirpressureateachfracandensuregreatestrecoveryfromallfracstages

•Determiningtheoptimalpumpingspeedandvolumetolengthenprimaryproductionandpreventsteeppressuredecline


6.00 Chair’s Closing Remarks

6.10 - 7.10 Networking Drinks Reception In Exhibition Showcase Area


Day 2Wednesday January 26, 2014

MITIGATING OPERATIONAL HAZARDS AND OPTIMIZING EOR: Day two will examine how operators are evaluating EOR potential in tight oil plays and provide strategies for mitigating operational hazards such as sand, fines, wax and gas locking to lengthen production between workovers and reduce downtime

8.30 Chair’s Opening Remarks

Chaired by: Dhunay Nav, CTO, PumpWELLKEYNOTE: PREPARING FOR EOR

8.40 How An Operator Is Planning Field Development, Well Spacing And Equipment Selection To Facilitate Future EOR Production Schemes•Understandingtheoptimalwellspacingdesignforfield

growthandpotentialEORdevelopmenttomaximizespace•Evaluatingreservoircharacteristicsandprojectedwelllife

todeterminemethodofproductionupfrontandavoidlostfluidrecovery

•ExaminingdeclineratesoftightoilreservoirsandlongtermeconomicstrategyforproductiontoevaluateEORfeasibility

•DefiningtheeconomiclimitsofproductionfallofftodeterminewhetherEORschemeswillbeeconomicalinthelongterm

•Analyzingoffsetproductiondatatodetermineoptimalcompletionsandwellboredesignforproductiontocutoverallwellcosts

Ron Davison, VP Engineering, Beaumont Energy9.10 Question & Answer Session

SAND, FINES, GAS, WAX AND SCALING MANAGEMENTStrategies For Overcoming Operational Hazards During

Primary Production To Prevent Blockages, Mitigate Fluid Loss And Lengthen Time Between Workovers

GAS INTERFERENCE

9.20 Examining Operational Strategies For Reducing Gas Interference To Prevent Gas Locking And Damage To Downhole Equipment•Examiningdownholetoolsincludinggasseparators,pump

andtubingstringconfigurationstomanagehighGORwells•Determiningtheoptimalrateatwhichtopumptomaintain

fluidlevelontheinsertpumpandremainabovethebubblepointtopreventgasinflow

•EvaluatingdifferentgasseparatorsandtheirangleandplacementinthewelltodetermineoptimalselectionforvaryingGOR’s

•Comparingartificialliftmethodsandemergingpumpsdesignstoevaluatewhichmethodcanrestraingasfromenteringthesystem

Jeff Dusterhoft, Production Engineer, Trilogy EnergyPaul Storey, Consulting Engineer, Trilogy Energy9.50 Question & Answer Session10.00 Morning Refreshments In Exhibition Showcase Area

CHEMICAL TREATMENT

10.30 Evaluating The Use Of Inhibitors And Dispersants To Effectively Reduce Wax, Asphaltenes And Scale Build Up•Evaluatingchemicalcompoundssuchaspolureneandxylene

tounderstandoptimalchemicaltreatmenttoeffectivelyreducewaxbuildup

•Determiningtheminimumlevelofchemicaltreatmentrequiredtoeffectivelycontrolwaxbuildupandreducecostlychemicaluse

•Howtoeffectivelygaugelocationandvolumeofwaxandscalebuildupfromsurfacetotargettreatmentmoreefficientlyandreducetreatmenttime

•Examiningwhichdownholematerialshavethehighesttoleranceofcorrosionpropertiestoselectdurablematerials

•Evaluatingtraditionalmethodsofhotoilingtoevaluatepotentialuseintightoilplays

•Evaluatingtheuseofscrapersontheroddesigntoeffectivelyremovewaxandmaintainpumpingrate

Patrick Shuler, Director - Oil Field Chemistry, PEERI11.00 Question & Answer Session

SAND AND FINES MIGRATION

11.10 How Operators Are Effectively Managing Sand And Fines Migration To Reduce Erosion Of Surface Equipment And Prevent Costly Workovers•Examiningsandandfinesmigrationvolumestounderstand

maximumlevelsofsolidsthatcanbepresentwithoutdisruptingproduction

•Evaluatingtheoptimalapplicationandsizeofsandseparatorsandde-sandersatsurfacetopreventblockagesinhighgasreservoirs

•Analyzingtheeffectivenessofgravelpackingandresigncoatedfracfluidduringcompletionstomitigatesandissuesupfront

•Strategiesforcleaningsandandsolidsdownholetoensureaccesstothetoeofthewellborethroughoutproduction

•Analyzingtheuseofnitrogenfoamclean-outstomitigatesandandpreventsteepdeclineinproduction

•Analyzingwhichliftmechanismcanhandlelargestquantitiesoffinestodetermineoptimalpumpmethodinhighfinewellboresandmitigateequipmentdamage


11.50 Lunch In Exhibition Showcase Area

FRAC PERFORMANCE

Evaluating Frac Performance To Develop Optimal Wells

For Production

MEASURING FRAC PERFORMANCE

12.50 Understanding Where Production Is Coming From: Strategies For Measuring Recovery From Each Frac Stage And Maximizing Production From High Producing Frac Ports

•Analyzingflowratesandpressureateachfracporttodeterminewhichfracstagesarecontributingmosttoproduction

•Strategiesforrunningproductionloggingtoolsthroughtheentiredirectionalprofileofthewelltoensureaccesstothetoeofthewellandaccuratelymeasureproduction

•Correlatingproductiondatatodeterminetheoptimalfracsizes,numberofstages,horizontallengthandwellspacingformaximumrecovery

Jesse Williams-Kovacs, New Ventures Engineer, TAQA North1.20 Question & Answer Session

AUTOMATION AND SURFACE FACILTIIES

Analyzing Automation Software And Surface Facilities To

Optimize Production Operation Logistics

AUTOMATION

1.30 Evaluating The Accuracy Of Automation In Remotely Monitoring And Diagnosing Operational Issues In Surface And Downhole Equipment

•Evaluatingusefulnessofsoftwaretocontrolpumpcyclingrateanddurationtomanagewellsremotelyandmaximizerecovery

•Examiningtheuseofautomationtorelayequipmentloadsandstressdatatomaximizeequipmentrunlifeandreducefrequencyofworkovers

•Examiningcapacityofsoftwaretodiagnoseoperationalhazardssuchaswaxorscaleandautomaticallyinjectchemicalstominimizeneedformanualinterventionandreducedowntime

•Anaylzingtheeffectivenessofautomationsystemstoreducetheneedofmanualinterventionandcutoperationalcosts

Shaun House, Production Engineer, Nexen2.00 Question & Answer Session

SURFACE FACILITIES

2.10 Examining How A Producer Designing Surface Facilities To Ensure There Is Adequate Space For Future Workovers And Transport Infrastructure

•Analyzingpipelineinstallationandtruckingcostsagainstanticipatedfieldlongevitytodeterminemostcost-effectivetransportationoption

•Evaluatingwellplacementandspacingtoensureeaseofaccesstowelltestingequipmentandpowersourceonsite

•Designingsurfaceequipmenttofacilitatelongtermproductionandworkoversincludingsandseparatorpackage,wellheaddesign,andpowersupply

•Evaluatingavailablepowersupplyandequipmentrequirementstodeterminemostcosteffectiveinstallationofpower

Glenn Wilde, President, Revive Energy Corp2.40 Question & Answer Session

EOR IN TIGHT OIL PLAYS

Examining Crtieria For Eor And Determining Which Eor

Method Gives The Best Recovery In Light Oil Fields

EOR CRITERA

2.50 Considering What Criteria To Use When Evaluating EOR Potential And Determining Which EOR Method Will Deliver The Highest Recovery

•EvaluatingproductionratesandreservepotentialtodeterminewhetherEORisfeasibleandcosteffectiveindepletingreservoirs

•EvaluatingoptimumEORmethodagainstreservoircharacteristicssuchasfluidviscosity,gaslevels,movableoilandpermeability

•Analyzingaccesstoavailableresourcessuchaswater,C02,powerandpipelinestodeterminefeasibilityofimplementinganEORscheme

•EvaluatingpressurelevelsandproductionratetodetermineoptimalpointtoimplementEORscheme

Shonn Arndt, EOR Project Eng, CNRL3.20 Question & Answer Session

3.30 Afternoon Refreshments In Exhibition Showcase Area

WATER FLOODING: PANEL

4.00 How Operators Are Maximizing Water Injection Levels In Water Flooding Fields To Prevent Breakthrough And Formation Damage

•Examiningthehighestinjectionlevelsthathavebeenpossibleinthelowestpermeabilityrocktodeterminereservoirlimitationsforwaterflooding

•Analyzingtheoptimalwellspacingfrominjectortoproducertoenablewatertoflowintoporouszones

•Evaluatingstrategiesforimprovingsweepefficiencyofinjectiontoensurewaterisdistributedevenlybetweenreservoir

•Calculatingthehighestpumpratethatwillallowwatertopermeatetheformationwithouttodeterminebreakthroughpoint

•Calculatingtheminimaltreatmentnecessarytoreduceoxygenlevelsinwaterandpreventbacteriagrowthandpluggingdownhole

•Strategiesformanagingpressureandflowratesofmultiplecorrespondingwellsatsurfacetomaintainoil/watercutandmaximizehigherproducers

Mohamad Mojarab, Senior Reservoir Engineer, Crew EnergyImad Brohi, Reservoir Engineer, Pengrowth EnergySoheil Asgarpour, President, PTACMike Dupont, Senior Staff Reservoir Engineer, Penn West4.30 Question & Answer Session

GAS FLOODING: NITROGEN VS. CO2 VS. METHANE

4.40 How An Operator Has Cost Effectively Employed Gas Flooding To Increase Oil Recovery In A Tight Oil Reservoir

•EvaluatingexpenditureonGas,treatmentfacility,andgaspipetowellsitevs.expectedproductiontodetermineeconomicfeasibilityofC02flooding

•AnalyzingavailablesourceofC02,methane,ornitrogentoselectmostcosteffectivegasforflooding

•Examiningthepotentialofre-usingproducedgasforgasfloodingtoeliminatecostandrepurposeextractedgas

•Evaluatingtherockintegrityoftheformationanddeterminingmaximuminjectionpressurestoensuresafeemploymentofgasandavoidgasleaks

Shauheen Etminan, EOR Leader- Reservoir Engineer, Alberta InnovatesFred Wassmuth, Team Lead, Alberta Innovates5.10 Question & Answer Session

5.20 Chair’s Closing Remarks

5.30 Chair’s Closing Remarks And End Of Conference


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