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� 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
www.artificial-lift-production-canada-2015.com (1) 800 721 3915 [email protected]
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
1:05 Question & Answer Session
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
2:55 Question & Answer Session
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
www.artificial-lift-production-canada-2015.com (1) 800 721 3915 [email protected]
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
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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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Terms & Conditions
The conference is being organized by Canadian Business Conferences, a division of London Business Conferences Ltd, a limited liability company formed under English company law and registered in the UK no. 5090859.Cancellations received 30 days prior to the event taking place will be eligible for a refund less $150 administration fee, after which point no refund will be given. Cancellations must be made in writing, if you are unable to attend you may nominate a colleague to take your place at no additional cost.Receipt of this booking form, inclusive or exclusive of payment constitutes formal agreement to attend and acceptance of the terms and conditions stated.All outstanding fees must be paid within our standard payment period of 7 days. Any outstanding invoices will remain valid should cancellation of attendance be received outside of the aforementioned cancellation period.* If you are claiming the early booking discount this may not be used in conjunction with other discounts advertised
elsewhere. All discount codes and offers must be claimed at the time of registration.Canadian Business Conferences reserves the right to alter or cancel the speakers or program.We would like to keep you informed of other Canadian Business Conferences products and services. This will be carried out in accordance with the Data Protection Act. Please write to the Head of Marketing, Canadian Business Conferences at the address below if you specifically do not want to receive this information.Canadian Business Conferences. Bankers Hall. West Tower, 888. 3rd Street SW. 10th Floor. Calgary. AB. T2P 5C5Canadian Business Conferences will not accept liability for any individual transport delays and in such circumstances the normal cancellation restrictions apply.Canadian Business Conferences is a Division of London Business Conferences Limited.Registered in England No. 5090859 EIN. no: 98-0514924