Artificial Lift Production Optimization Canada 2015

� Artificial Lift Cost Reductions

� Production Facility Design

� Matching Lift To Reservoir

� H2S Management

� Sand Control

� Water Flooding

Reducing Lift And Production Costs During The Low Crude Price Period: Designed Specifically For Production Professionals In The WCSB

Sharing Success Stories On How WCSB Operators Are

Optimizing Artificial Lift Selection, Driving Down Costs, Maximizing Run Times And Applying Water Floods To Maximize Recovery In Shale Gas And Tight Oil Plays While Maintaining Margins In Light Of Changing Oil Prices

Key Topics Include:

April 29 - 30 | Calgary | Canada

Glenn Wilde President Revive Energy Corp

Western Canadian Sedimentary Basin: Artificial Lift, Secondary Recovery & Production Optimization

M Follow us @UnconventOilGas

www.artificial-lift-production-canada-2015.com

Register By FridayMarch 27, 2015

SAVE $200

• ARTIFICIAL LIFT SELECTION: Comparing PCPs, ESPs, jet pumps and gas lift systems to establish which have the greatest potential to decrease capital costs whilst guaranteeing desired production rates

• PRODUCTION FACILITY DESIGN: Evaluating best design practices for multi-well pad oil production facilities in the WCSB that have shown to reduce both capital and long term operating cost

• DUVERNAY CASE STUDY: Presenting a case study on how an operator has managed to maximize recovery rates in the Duvernay while minimizing failure rates and downtime

• WATER FLOODING: Showcasing a successful water flood pilot to establish if and under which circumstances the return on capital justifies the investment

• REDUCING FAILURE RATES & DOWN TIME: Examining optimal best practices for mitigating key risks to production including gas, H2S, sand, scaling and paraffin wax to minimize downtime and reduce well costs

Shonn Arndt EOR Project Engineer CNRL

Shawna Bonini Production & Operations Engineer SM Energy

Jeff Dusterhoft Production Engineer Trilogy Energy Corp

Krzysztof Palka Resident Sustainability Agent Imaginea Energy

Jesse Williams-Kovacs New Ventures Engineer TAQA North

Cody Smith COO & VP Operations Strategic Energy

Organized By: HEADLINE SPONSOR: PARTNER SPONSOR: CO-SPONSOR:

SAVE $200

www.artificial-lift-production-canada-2015.com (1) 800 721 3915 [email protected]

Containing 1.7 billion barrels of tight oil and 4,995 trillion cubic feet of shale gas yet to be recovered, the Western Canadian Sedimentary Basin holds huge revenue opportunity for oil companies, even in the low price crude climate; so long as production and artificial lift costs are managed properly.

It is now down to Production VPs, Managers and Engineers to ensure these reserves are recovered at the lowest possible cost and with limited well downtime to keep strong production flowing throughout the lifetime of the well.

Current commodity prices are of course the main driving force behind cost-centric strategies, however optimizing production will increase margins even more

dramatically when prices rebound.

REDUCING LIFT COSTS WHILE MAXIMIZING RECOVERY:

CONGRESS DEDICATED PURELY TO PRODUCTION PROFESSIONALS

The 2015 edition of this operator led congress focuses on artificial lift and secondary recovery techniques across the Western Canadian Sedimentary Basin. This year’s congress hones in on overcoming the WCSB-specific challenges of high gas rates, H2S, paraffin wax and sand production. Ultimately driving this year’s agenda is cost and new technologies all delivered by key E&P operators in the Western Canadian Sedimentary Basin.

Key cost-reduction strategies being discussed by E&P speakers include:

• Identifying in which areas and under what circumstances switching lift types will help maximize per-barrel margins during the period of low oil prices

• Identifying cost saving opportunities at different stages of production, from lift to chemical treatment

• Identifying which production and lift technologies are helping ensure maximum

drainage at lowest cost and consequently, high profit wells

COST REDUCTION FOCUS: As the barrel oil has fallen below $60, it is not just the drilling and completions part of the operations that needs cut back – find out what strategies have operators employed to trim costs on the production side

100% OPERATOR LED: By presenting an agenda that is 100% designed by E&P professionals working in shale gas and tight oil production, this congress is completely up-to-date on need to the know artificial lift and EOR solutions

WCSB SPECIFIC SOLUTIONS: Different basins have different challenges. This agenda has been created specifically to address the high gas rates, H2S, paraffin wax and sands that can cause pump downtime and increase costs in the Western Canadian Sedimentary Basin (WCSB)

Register By FridayMarch 27, 2015

Clarion Hotel and Conference Centre2120 16 Ave NECalgaryT2E 1L4

Tel: (403) 291 4666

Web: www.clarionhotel.com/hotel-calgary-canada-CNA28

Venue Information:

Great range of topics covered with good pace/structure. Excellent venue ConocoPhillips Canada

ARTIFICIAL LIFT TECHNIQUES: COST REDUCTION: Cutting Edge Best Practices For Optimizing Artificial Lift Selection Based On Cost, Recovery Effectiveness And Failure Rates

Day 1Wednesday April 29, 2015

Introducing The Latest Advances In Artificial Lift Technology And Application That Can Maximize Recovery At Minimum

Costs And Risk

8:30 Chair’s Opening RemarksChaired By: Nav Dhuney, President & CEO, PumpWELLKEYNOTE: ARTIFICIAL LIFT COST REDUCTIONS8:40 How WCSB Operators Are Significantly Decreasing Artificial Lift Costs While Ensuring Maximum Production And Run Times To Maintain Margins In Light Of Reduced Oil Prices•Sharinghowanoperatorhasrealizeddecreasedoverall

artificialliftcostsforahorizontalapplicationtoapointwhereitjustifiesdrillingthewelleveninthelightofloweroilprices

•Hearinghowcostmanagementwasimplementedinmarginalwellstocutunnecessaryexpensesthroughoutthefulllifecycleoftheassetandmaintainprofitability

•Explainingthemaximumvolumeofreservesthathavebeencapturedatlowestliftingcostsinthelast12monthstobenchmarkperformanceandaidthecomparisonprocess

•ReviewingwhichshaleplaysinCanadahavethelowestoperatingcostsandthegreatestpotentialinmaximizingreturnoninvestment

•Showcasingproductionprofilestoseehowsmartdecisionmakinghasoptimizeddrawdownopportunities,maderuntimesmoreconsistentanddecreaseddeferredproductionandoperatingcosts

Matthew Dodwell, VP Production, Belgrave ResourcesNav Dhuney, President & CEO, PumpWELL9:10 Question & Answer Session

ARTIFICIAL LIFT SELECTION FOR SPECIFIC RESERVOIRSEXAMINING THE LATEST PUMP ADVANCES AND

ESTABLISHING THE KEY CRITERIA TO USE WHEN SELECTING ARTIFICIAL LIFT BASED ON RESERVOIR

SUITABILITY, COST, AND RUN TIME

ARTIFICIAL LIFT SELECTION: DUVERNAY9:20 Presenting A Case Study On How An Operator Has Managed To Maximize Recovery Rates In The Duvernay While Minimizing Failure Rates And Downtime•Showingwhattypeandsizeofpumphaveprovento

achievedesiredproductionratesintight,high-pressurereservoirssuchastheDuvernay

•OutliningbestpracticesforproducinginthehighpressuredDuvernayformationtoincreaseultimaterecoveryanddecreasecapitalcosts

•ExaminingwhichdesignsandpumpshaveworkedforaspecificfieldorzoneintheDuvernayandatwhichspeedstheycouldbeworkedatformaximumruntimesandproductionrates

•HowtoselectthemostreliableequipmentfortheDuvernayformationtoavoidequipmentfailureanddowntime

•Showingwhichpumpshavethegreatesttrackrecordofhandlingsolidstoavoidpumpcloggingandequipmentwear-out

Glenn Wilde, CEO, Revive Energy9:50 Question & Answer Session10:00 Morning Refreshments In Exhibition Showcase AreaHIGH GAS-OIL RATIO WELLS: LIFT SELECTION10:30 Introducing The Key Evaluation Criteria For Selecting Artificial Lift Techniques In High Gas-Oil Ratio Wells To Ensure The Most Reliable Method Is Applied•Outliningthespecificchallengesforhighoil-gasratio

horizontalwellsandhowtoincorporatetheseintoliftevaluationandselection

•Examiningwhatoperatorsareusingasevaluationcriteriawhenchoosingartificialliftmethodsinhighgasratiowells

•Hearingbestpracticesforhandlingadditionalchallengestopumpsposedbysignificantdebris,highliquidproductionandhighgasratestoavoidfailures

•Analyzinghorsepowerrequirementsforartificialliftsthatcanbeappliedtohighoil-gasratiowellsandhearinghowtoensurecontinuouspowersupplytominimizedowntimeandensureefficiency

Jesse Williams-Kovacs, New Ventures Engineer, TAQA North11:00 Question & Answer Session

PUMP JACK VS GAS LIFT VS PLUNGER LIFT <150 pbd11:10 Comparing Pump Jack, Gas Lift And Plunger Lift Systems To Establish Which Can Be Installed At Minimum Cost And Maximum Pump Efficiency For Operations With Less Than 150 Barrels A Day•Comparingpumpjack,gasliftandplungerliftsystems

onthekeycriteriaof:capitalcost,powerrequirements,efficiency,runlife.equipmentreliabilityanddowntimeandfailurerates

•Contrastingproductionresultsforpumpjack,gasliftandplungerliftintheWCSBtoestablishwhethertheyjustifytheinvestment

•Contrastingwhattypesofartificiallifthaveworkedbestinreservoirsfordifferentdepths,pressuresandtemperaturestoensureappropriateapplication

•Describinghowsandcaneffectivelybecontrolledinascenariowheretheproductionrateistoolowtoflushitoutthroughapumpandforecastingtheimpactitwillhaveonthedifferentlifttechniquesifnotcarriedoutadequately

Ian Wang, Production Engineer, Sunwing Energy11:40 Question & Answer Session

PCP VS ESP VS SUCKER ROD PUMP >150 pbd11:50 Comparing PCPs, ESPs And Sucker Rod Pump Systems For Operations With More Than 150 Barrels Per Day To Establish Which Have The Greatest Potential To Decrease Capital Costs Whilst Guaranteeing Desired Production Rates•ComparingPCP,ESPandsuckerrodpumpsystems

onthekeycriteriaof:capitalcost,powerrequirements,efficiency,runlife,equipmentreliabilityanddowntime&failure

•Contrastingwhattypesofartificiallifthaveworkedbestinreservoirsfordifferentdepths,pressuresandtemperaturestoensureappropriateapplication

•Analyzingwhichtypesoffluidsdifferentpumpscanhandleandhowtheyaffecttheefficienciesofthepumpstoavoiddowntimesandadditionaloperationalcost

•Displayingwhichartificiallifttechniquesaremosteasilyoperatedandprovidethemostamountofflexibilitywhileensuringmaximumproductionratestoavoidfailures

•Evaluatingthein-flowratesofthedifferentpumpsandtheamountoffluidstheycanlifttoestablishwhichpumpsworkcost-effectivelyat$60barrel

•Exploringwhenitispossibletoapplyjustonetypeofpumpfortheentirelifeofthewelltosavecapitalcosts

Krzysztof Palka, Resident Sustainability Agent, Imaginea Energy12:20 Question & Answer Session12:30 Lunch In Exhibition Showcase AreaMATCHING LIFT TECHNIQUE TO RESERVOIR PANEL1:30 Displaying How The Right Artificial Lift Can Be Matched To The Right Well To Optimize The Outflow Performance•Describingwhichapplicationscurrentartificiallift

typeswereoriginallydesignedforandhowtheycanbesuccessfullyappliedtotightoilplaysinWesternCanada

•Sharingthekeyevaluationcriteriathatanoperatorhasusedtodecidebetweentwoequalartificiallifttypesforcertainwellcharacteristics,including:location,depth,estimatedproduction,crookedhole,decreasingsize,reservoirproperties,highviscosity,sandproduction,paraffineticconditions,scaletendenciesandH2S

•Outliningthedifferentlevelsofchallengeforhighpressurereservoirsandwhatartificiallifttechniqueshaveproventodeliverhighproductionratesatminimumcostsanddowntime

•Analyzingthepressureprofilethatneedsmaintainedtooptimizerecoverandperformancefromreservoirstoselecttheadequateartificiallifttechniques

•Assessinghowsensoraccuracyfordownholemeasurementscanbesignificantlyimprovedtoensureselectioncriteriaarebasedonafullsetofaccuratedata

Panelist: Cody Smith, COO & VP Operations, Strategic Oil & GasPanelist: Iryna Koval, Production Technologist, Apache2:00 Question & Answer Session

PUMP STRATEGIESEXAMINING THE LATEST PUMP STRATEGIES AND

EXAMINING THE KEY CRITERIA TO USE WHEN SELECTING SPECIFIC ARTIFICIAL LIFT TYPES BASED ON RESERVOIR

SUITABILITY, COST, AND RUN TIME

ELECTRICAL SUBMERSIBLE PUMPS2:10 Learning How To Design, Manage And Operate ESPs To Maximize Run Times At Production Rates Of 900 Barrels Per Day Or Higher•DisplayingwhichmanufacturermodelsofESPsare

currentlyinthemarketandwhichformationsintheWCSBtheycanbeappliedtomaximizeproductionresults

•OutliningthechallengesandtechnicallimitationsofcurrentESPstounderstandhowruntimescanbeoptimizedinthecontextofthewellandhowitisoperated

•DesigninganESPsystemforaspecificapplicationandidentifyingthevariablesthatcanbeadjustedtoincrease

efficienciesandrunlifeinthefield•Comparingtheprosandconsofacceleratedvs.terminal

productiontoenableinformeddecisionmaking•Showcasingthedifferentmetaltypesthatcansuccessfully

dealwithH2SinanESP•PinpointingthebestmomenttotakeoutanESPand

switchtorodpumptoavoidunnecessarydowntime•ChangingESPdesigntoincreasepumpspeedtoincrease

productionlevelatminimumcosts•ShowingwhichESPshavethebestabilitytodealwithfluid

levelsandsandtominimizefailuresandadditionalcostsVern Mantey, Production Engineer, CNRL2:40 Question & Answer Session

ROD PUMP OPTIMIZATION2:50 Examining How The Design And Selection Of Rod Pumping Units Are Being Dramatically Optimized Throughout Tight Plays To Prevent Failures•Learninghowoperatorsareoptimizingthedesignof

standardpumpingunitswitharodpumpstoensureitcanhandledoglegsandpreventdowntime

•Comparinghighstrengthrodstolowerstrengthrodsfor10,000feetdepthsandforecastingwhatthepotentialisforpushingthelimitationsoftherods

•HighlightingtheadvanceofrodpumpsincomparisontoPCPsthathaveissuesstayingsealedinvolatileoiltoestablishhowrodpumpscanbeasustainablesolutionforformationsliketheViking

•Comparingsinglevalve,doublevalve,topholedown,bottomholedown,tubingbarrelpumpsandinsertpumpstoestablishwhichhavenproventobemosteffectiveinthefield

•Analyzingthefailureratesofhighstrengthrodstoidentifythekeyfactorsthatneedtobeaddressedtoensuremaximumruntimes

Cole Starling, Field Optimization Engineer, Sinopec Canada3:20 Question & Answer Session3:30 Afternoon Refreshments In Exhibition Showcase AreaPLUNGER OPTIMIZATION PANEL4:00 Explaining How To Optimize The Cycle On Plunger Lifts For Old Sour Wells To Maximize Gas Recovery Rates•Sharingwhatplungerautomationsystemscanbeputin

placeformoretraditionalwellstoincreaseoverallrecovery•Analyzingwhatkindofalgorithmscanbeutilizedtotrigger

whenthewellcomesonandofftoavoiddowntime•Summarizingthekeysystemfactorsandalgorithmsthatcan

effectivelycontroltheplungerandincreaseproductionratesPanelist: Shawna Bonini, Sr. Production & Operations Engineer, SM Energy4:30 Question & Answer Session

POWERING ARTIFICIAL LIFT4:40 Evaluating How To Effectively And Efficiently Power Artificial Lift Applications While Accounting For Scalability And Reliability To Lower Down Time On Wells•Analyzingthecosteffectivenessofnaturalgaspowerand

dieselpoweralternativefueloptions•Examininghowtoreliablyutilizestrandedgasforpower

generationtolowerdisposalcosts•Assessingtheadvantagesforutilizingscalablemicrogrids

acrossmultiwellpadsitestoprovidetherequiredpowerforoperations

•Understandinghowtoincreasesafetyandreliabilitythroughengineering,remotemonitoringandmaintenanceofartificialliftpoweringtoensurethesafetyofallequipmentandpersonnelonsite

David Dickert, Head Of Oil & Gas Americas, Aggreko5:10 Question & Answer Session

INNOVATIONS IN ARTIFICIAL LIFT TECHNOLOGY5:15 Introducing Price Competitive Advances And Development In Artificial Lift Technology That Are Likely To Allow For Improved Recovery Rates And Minimum Downtime In The next 3 Years•Evaluatingtheverylatestadvancesinartificiallifttechniques

currentlyonthebrinkofcommercializationbasedon:runtime,capitalcost,spectrumofapplicability,productionrates,downtime&failuresandoperationalchallenges

•Establishingwhethertheartificialliftinnovationhasthepotentialtoworkindeep,lowporosityandpermeabilitysubsurfaceconditionstodetermineinwhichplaysitcouldbeapplied

•Evaluatingcurrentsuccessandfailurestoriesfromoperatorsthathavetrialledlesscommonpumptypes

Ransis Kais, Sr. Staff Production Engineer, Apache Canada5:45 Question & Answer Session


8.10 BREAKFAST BRIEFINGNav Dhuney, President & CEO, PumpWELL8:20 Chair’s Opening RemarksChaired By: Nav Dhuney, President & CEO, PumpWELL

ENHANCED OIL RECOVERYSHOWING HOW WATER FLOODS CAN BE OPTIMIZED TO INCREASE THE RECOVERY RATE AND OVERALL ROI AT

LOWER OIL PRICES

WATER FLOOD: BUSINESS CASE8:30 Showcasing A Successful Water Flood Pilot And Explaining How To Set Up And Monitor The Downhole System: Establishing If And Under Which Circumstances The Return On Capital Justifies The Investment •Examiningthecommercialpotentialofsecondaryrecovery

throughwaterfloodinthelightofcurrentoilpricestoestablishwhetherthecapitalinvestmentscanbejustifiedbyresults

•Examiningbestpracticesinusingreservoircharacterizationtodeterminethevalueofwaterfloodingandensuremaximumoperationaleffectiveness

•Comparingoperatorfielddevelopmentplansfor1-2and2-5yearsandhowtheyareanalyzingtheeconomicpotentialofwaterfloodingtohelpdecidewhethertheinvestmentisworthitbasedonloweroilprices

•ComparingresultsonwhichEORsintheCardium,Montney,VikingorBakkenhavesuccessfullyincreasedoilrecoveryratesfrom15%to20-25%tohaveanoutlookatthepotentialwaterfloodingcanoffer

•Summarizinghowtomaintainpressureandinjectionlevelsforashalefieldthatconsistsmainlyofhorizontalstomaximizerecovery

•Explaininghowtoenhancedownholemonitoringtoensurethatwaterisenteringintotheblockmatrixinsteadofgoingdownthefracturingchannelandenteringanotherwellboretoreactandadaptoperationtimely

•Lookingatthebestsetupofawellboreforwaterfloodsintermsofhorsepowerneededandsettingsformaximumspeedandvolumesofinjections

Panelist: Mohamed Habib, Completions & Well Testing Engineer, GDF- Suez9:00 Question & Answer Session

REDUCING FAILURE RATES & DOWN TIMEOUTLINING HOW TO MITIGATE KEY RISKS TO PRODUCTION INCLUDING GAS, H2S, SAND, SCALING AND PARAFFIN WAX

TO MINIMIZE DOWNTIME AND REDUCE WELL COSTS

GAS LOCKING9:10 Demonstrating Which Pumps Have Been Proven To Most Effectively Prevent Gas Locking To Avoid Downtime And Save Costs In WCSB Production•Showingwhichpumpsfortightoilhavebeensuccessfulin

dealingwithfreegastopreventgaslock•Learninghowoperatorsareselectingtherightpumpto

avoidgaslockbasedonwhathasproventoworkcost-effectivelyinagasinterferencepronewell

•Examininghowoperatorsareoptimizingtubingstringdesignandconfigurationstoavoidgasenteringthesystem

•Displayingwhichpumpshavethegreatestpotentialtoadapttobottomholepressureirregularitiesandworkeffectivelyatminimumcost

•EvaluatingtheeffectivenessofESPsthatprovideintrinsicgashandlingsystemstohelpjustifywhetherthelisttypeisworththeinvestment

Japan Trivedi, Assistant Professor, University Of Alberta9:40 Question & Answer Session9:50 Morning Refreshments In Exhibition Showcase Area

GAS SEPARATION10:20 Showcasing Which Gas Separators Have Worked Most Effectively In Preventing Gas Lock To Determine Cost Effective Ways Of Maximizing Run Times•Summarizingthecurrenttechnologiesforgasanchors

thatcanincreasethevolumeoffreegasremovedfromtheliquidsbeforeenteringthepumptoavoidgaslock

•Comparingdifferentgasseparatorsontheircost,effectivenessandtheirwellplacementandanglerequirementsforvaryingGORstoenableselectionofthemosteffectiveoption

•Analyzingwhichpumprateshaveprovensuccessfulinremainingabovebubblepointtopreventgaslocking

10:50 Question & Answer Session

MAXIMIZING PRODUCTION VALUE11:00 Maximizing The Full Value From Production At The Lowest Economic Cost: A Short-Term and Long-Term View•ExaminingintegratedsolutionsforWesternCanadian

SedimentaryBasinwellstomaximizerecoveryandcreateeconomicsavingsfromintegration

•Discussinghowtocreatealife-of-wellproductionplantoaddressshort-termliftingcostsandlong-termassetmanagementconsiderations

•Understandinghowtocontinuouslymonitorandadaptproductionplanstowellchanges,ensuringallteamsareinvolvedinthedecisionprocesstoreducedowntimeonwells

Baker Hughes11:30 Question & Answer Session11:35 Lunch In Exhibition Showcase AreaH2S HANDLING12:35 Learning How To Handle And Treat H2S In The Bakken To Mitigate Equipment Wear-Out And Avoid Losing Money Spent Hauling Sour Oil•Explaininghowbacteriainwatercanbeeffectivelytreated

toavoidH2Sdevelopment•ShowcasingwhichH2Sconvertersandcorrosion

inhibitorscancost-effectivelypreventseverecorrosion,foulingandinjectionwellpluggingwithironsulphidetoavoidlossofequipmentandhavingtoisolatetheentireproductionstreamoffforsafetypurposes

•Examiningbestpracticesforpreventinghydrogensulphidefromsettingupintheprocessequipmenttoeffectivelysweetenthegasbeforeitleavesthelease

•ComparingthetreatmentcostsandeffectivenessofalternativesforH2Streatmentonwhichsulphidescavengerscanbeapplied,toensureproductvalue,infrastructureintegrityandenvironmentalandsafetycompliance


SAND CONTROL1:15 Comparing Sand Control Mechanisms For Horizontal Wells To Avoid Expensive Equipment Clogging And Wear-Out•Comparingsandscreensvs.sandseparatorsoncapital

cost,runtimeandefficiencytodeterminewhichismostcosteffectiveinhorizontalwells

•Exploringthepotentialofcontrollingsandbyoperationalmeanstoavoiderodinghardware,creatingdownholecavitiesandblockingtubulars

•Pinpointingwhatconstitutesacceptablelevelsofsandproductionbasedonresistancetoerosion,separatorcapacity,easeofsanddisposalandthecapacitiesofartificialliftequipmenttoremovesand-ladenfluidfromthewell

•Explaininghowtousesurfaceequipmenttoknockoutsandeffectivelyandmaximizepumpruntimes

•Exploringthepotentialofusinggravelpackcompletionstokeepsandintheformationwithoutnegativelyaffectingproductiontomitigateanyequipmentwear-outrisksandreduceoperatingcost

•Comparingdualfilters,meshfiltersandotherfilteralternativestoestablishwhichhavethegreatestpotentialforcost-effectivelycontrollingsand

Jeff Dusterhoft, Production Engineer, Trilogy Energy1:45 Question & Answer Session1:55 Afternoon Refreshments In Exhibition Showcase AreaSCALE PREVENTION & PARAFFIN TREATMENT2:25 Determining The Optimum Chemical Program To Cost- Effectively Treat And Prevent Scaling And Paraffin Downhole And Avoid Damage To Mechanics, Equipment And Reservoir•Examiningthelatestimprovementsintestingandmeteringof

watercontentstoproactivelypreventscalingandcorrosion•Outliningthemostcosteffectivechemicalscaleinhibitors

thathaveworkedinthefieldoveranextendedtimetoensurescalemitigationandreducefrequencyofworkovers

•Analyzingresidualchemicalconcentrationstoensureadesiredlevelofconcentrationcanbemaintainedinaspecificwell

•Teachingbestdownholeplacementtechniquesforensuringtheefficiencyofthechemicalprogram

•Learningfrompastwellfailuresanddowntimeduetoscaleafterwellstimulationtounderstandkeyrisks,costimplicationsandhowmitigationcanbeoptimized

•Displayinghowtotestandmapparaffineticareastoenableproactiveplanningandmitigatedepositionandpluggingrisks

•Comparingthecostperbarrelofcurrentchemicalinhibitorandsolventsonthemarketthatcaneffectivelypreventandtreatparaffindepositioninparaffineticareas

•Providingafieldstudyshowinghowanoperatorhasadjustedthechemicalinhibitorovertimetokeepupwithchangingoilqualitiestopreventparaffindeposition

•Tacklingthekeychallengesposedtothepumpingsystemwhendealingwithmoreparaffinwaxtodeterminemitigationrequirements

•Comparinghotoiltreatmentstochemicalinhibitorprogramsforthetreatmentofparaffinwaxtodecreaseoperatingcostlong-termandensureproductionrates


WELL OPTIMIZATION3:05 A Review of Theory of Constraints (TOC), Lean Manufacturing and Six Sigma To Show How they Can Be Applied to Well Optimization•ProvidinganoverviewofTOC,LeanManufacturingand

SixSigmaconceptstostresstheimportanceofsystemthinkingtoimproveoperationalefficiency

•Demonstratinghowsystemthinkingcansignificantlyimprovethefieldoptimizationprocesstobenefitfromanincreaseingasoroiltosalesinlesstime

•Hearingacasestudyillustratingtheapplicationoftheseconceptstotightoilandgasexamplesincludingtheoptimizing14000+shallowgaswellstoprovetheeffectivenessofTOC

•Identifyingwhatiscriticaltocreateanorganizationofcontinuousimprovement

Shonn Ardnt, Exploitation Engineer, CNRL3:35 Question & Answer Session3:45 Chair’s Closing Remarks

Day 1 (...continued)

Wednesday April 29, 2015


Day 2Thursday April 30, 2015

REDUCING FAILURE RATES AND OPTIMIZING SECONDARY RECOVERY TECHNIQUES: Learning Best Practices For Mitigating Scaling, Gas Locking, Paraffin Build Up And Sand Failures And Examining Best Practices In Secondary Recovery To Ensure Optimum Recovery From WCSB Reserves

PRODUCTION FACILITY DESIGN5:55 Evaluating Best Design Practices For Multi-Well Pad Oil Production Facilities In The WCSB That Have Shown To Reduce Both Capital And Long Term Operating Cost•Explaininghowartificialliftsurfacefacilitiescanbe

designedtodecreasecostandextendfacilityruntimes•Comparingfacilitydesignforasinglewelltomulti-well

paddesigntounderstandhowadditionalchallengeslikeelectricityrequirementscanbetackledatthelowestincrementalcost

•Hearingbestpracticesforoptimizingmetering,monitoringandtestingformulti-wellpadstokeepsurfacecostslowandstillprovidesufficientdatatomanagethereservoir

•Outliningbestpracticesforhandlingfieldcompression:centralizedcompressionversuswellsite

•Incorporatinglong-termfieldplanningtoeffectivelymatchproductionfacilitieswithsurfaceinfrastructureanddecreaseoperationalcosts

•Exploringtheequipmentwithpotentialtolastforthelifeoftheoilwellonceinstalled

6:25 Question & Answer Session6:35 Chair’s Closing Remarks6:45 - 7:45 Networking Drinks Reception In Exhibition Showcase Area

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BEST PRACTICE CASE STUDIES, TECHNICAL REPORTS & DATA ANALYTICS

Dealing With Scaling In The Bakken

Carlos Cardenas told attendees at last year’s Bakken Artificial Lift and Production Optimization Congress how he had successfully dealt with scaling and corrosion problems. Leah Mooney reports.

Using Data To Predict Failures In Rod Pump Artificial Lift Systems

University of Southern California professor Raghu Raghavenda explained to attendees of last year’s Woodford Shale Production Optimization Congress in Oklahoma City how computer modelling can help prevent rod pump failures. Leah Mooney reports.

How Well Spacing Affects Production

Down spacing can allow operators to access more of the reservoir and improve reserves but can also cause interference and affect production. Statoil Subsurface Manager Paul Lundy described recent well spacing and interference tests on the Statoil fields in Karnes and DeWitt Counties, Texas to delegates at last year’s Eagle Ford Production Artificial Lift & Choke Management Congress.

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