Mature Fields Argentina Production Optimization 2014 Congress

ARGENTINA’S ONLY OPERATOR LED CONGRESS FOCUSED PURELY ON MATURE FIELD PRODUCTION OPTIMIZATION

Optimizing Artificial Lift AndSecondary Recovery Injection To Maximize Production And Reduce OPEX In Argentina’s Depleted,Multi-Layered Oil And Gas Reservoirs

Key Issues To Be Discussed Include:

July 23-24 | Buenos Aires | Argentina

Damian Ramallo Leader Of Production Gran Tierra Energy

Expert Insight From Argentinean E&P Operators Working In Mature Fields, Including:

M Follow Us: @UnconventOilGas

www.mature-fields-argentina-2014.com

• ARTIFICIAL LIFT TECHNIQUES - LIGHT OIL: Selecting the optimal artificial lift

techniques based on run life, cost, durability, energy consumption and effectiveness

to optimize production within low-pressure reservoirs

• VISCOUS OIL PRODUCTION: Defining the optimal well design to ensure the effective

production of fields with viscous oil properties

• GAS PRODUCTION: Examining the latest technologies to deliquify gas wells and

improve the run life of gas lift production

• SURVEILLANCE & MONITORING: Identifying production monitoring, automation and

chemical tracer technologies to optimize injection and minimize failures

• FAILURE MITIGATION: Preventing well failures through sand, paraffin and corrosion

control methodologies, treatments and technologies

• WATER & POLYMER INJECTION: Delivering water and polymer injection and

waterflooding chemical treatment best practices to maximize oil and gas recovery

Victor Perusini Head Of Production San Jorge Petroleum

Francisco Queralt Head Of Facilities & Construction Americas Petrogas

Alejandro Ameglio Production Superintendent Apache Argentina

Carlos Laluf Head Of International Engineering Operations Azabache Energy

Oscar Orellana Production Supervisor Total

Martín Ignacio Kennedy Production Engineering Technical Consultant Petrobras Argentina

Diego Garzon Duarte CEO Oilstone Energy

EARLY LOCAL RATERegister By Friday May 30

SAVE $2700 ARS

Sheraton Buenos Aires Hotel & Convention Center

San Martin 1225-1227

Buenos Aires 1104

Argentina

Phone: (54) 11 - 4318 9000

Website: http://goo.gl/YKCKKA

Venue Information:

If Argentine production declines were improved by mere percentage points, the

country’s production could increase substantially, adding enough crude recovery to

fuel the entire country for years to come. With the global average recovery factor in

a mature field sitting at only 20-40% for oil and 70% for gas, much of the country’s

assets remain untapped.

Considering production optimization can increase incremental production by up to

25% and EOR applications up to 70%, operators are acutely focused on adopting

the right production technologies and strategies for application in these fields.

The answer lies in optimizing production techniques and EOR; the initial

investment into which can be far lower than exploration and workover efforts, while

delivering some of the highest returns. A modest 1% improvement in recovery could

potentially deliver millions of dollars in added value to a company’s assets; YPF is

just one company that agrees, stating that waterflooding can improve recovery by

6-8%, with polymer injection recovery forecasted to be even higher at 12-16%.

Mature Fields Argentina Production Optimization 2014 is the first congress

of its kind addressing how to select the optimal lift method to maximize reservoir

production in light oil, heavy oil and gas fields. The congress will deliver best

practices on artificial lift, production monitoring, deliquification, sand control,

corrosion control, paraffin control and EOR.

Over two days, attendees will benefit from 20 operator case studies specifically

focused on how to reduce OPEX and maximize production in fields with

a high water cut. The mission of the congress is for Argentinean operators to

take away usable solutions focused on how to maximize the run life of the

well and prevent well failures through field automation, surveillance, monitoring

technologies, lift selection and optimization and secondary recovery applications.

The First Congress Focused On Increasing The Ultimate Recovery Of Argentinean Mature Fields With Minimal Resources:

•Evaluates how to select the most effective artificial lift for light and heavy oil

reservoirs to maximize production results in depleted reservoirs

• Identifies how lifts and deliquification processes can maximize recovery and

minimize drowning gas fields

•Delivers real-life case studies on how operators have not only prevented

well failures but rectified sand, corrosion and paraffin issues downhole

ARGENTINA’S FIRST MATURE FIELDS CONGRESS FOR PRODUCTION AND RESERVOIR PROFESSIONALS

Jane Thomas

+ (1) 800 721 3915

[email protected]

To Secure Your Booth Or Discuss Tailor-Made Sponsorship Packages, Contact:

Sponsorship 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 Mature Fields Argentina Production

Optimization 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

www.mature-fields-argentina-2014.com (1) 800 721 3915 [email protected]


SAVE $2700 ARS

ARTIFICIAL LIFT OPTIMIZATION, VISCOUS OIL PRODUCTION AND GAS LIFT OPTIMIZATION

Day 1Wednesday, July 23

8.30 Chair’s Opening Remarks

KEYNOTE: ARTIFICIAL LIFT SELECTION

8.40 How To Select The Optimal Artificial Lift System For The Reservoir To Maximize Production Within Argentina’s Mature Fields: Case Study

•Understandinghowthepresenceofgas,liquids,sandsandsolidsimpactwhichartificialliftwouldoptimizeproduction

•Comparingpullingindexresultsfromartificialliftsystemstoselecttherigthatwillminimizeinterventionsingasandoilfields

•DefiningtheoptimalreservoirtouseESP,PCP,plungerliftandmanualbeanpumpunitstoincreasetherunlifeofthewell

•ComparingtheaveragerunlifeofartificialliftsystemstoensuretheOPEXwillnotexceedtheoilrecovery

Diego Garzon Duarte, President, Oilstone Energy

9.10 Question & Answer Session

ARTIFICIAL LIFT - LIGHT OILSELECTING THE OPTIMAL ARTIFICIAL LIFT TECHNIQUES

BASED ON RUN LIFE, COST, DURABILITY, ENERGY CONSUMPTION AND EFFECTIVENESS TO OPTIMIZE PRODUCTION WITHIN LOW PRESSURE RESERVOIRS

BEAM PUMP OPTIMIZATION PANEL

9.20 How Operators Are Reducing Paraffin And Gas Failures And Energy Consumption In Beam Pumps To Reduce OPEX

•Assessingoptimalbeampumpvelocitytopreventdownholebreakageswhilstmaintainingthemaximumlevelofproduction

•Identifyingtheoptimalbeampumpforuseinwellswithhighgascontenttopreventgasinterference,downholefailuresandincreaserunlife

•Selectingtheoptimalbeampumpwhenproducingindeepwellstoensuretheliquidcanbeliftedtosurfaceefficiently

•Comparingceramicandsteelbeampumpstoassesstheoptimalsystemforpreventingcorrosioninhightemperaturewells

Pablo Chebli, VP Argentina, Central Resources


10.00 Morning Refreshments In Exhibition Showcase Area

JET PUMP OPTIMIZATION

10.30 Evaluating Jet Pump Applications In Wells With A Depth Of 4000m With A Temperature Of 173°C To Define The Optimum Operating Regime In Mature Light Oil Wells

•Analyzingtheoptimalsurfacepump,motorandpoweroilconditionswhenusingjetpumpsinlightoilfields

•Evaluatingtheinstallationcosts,failureratesandproductionratesofjetpumpstoidentifyproductioneconomicsoftheproject

•Examiningpumpefficienciesandrunlifetoidentifyifrunningajetpumpwillproduceawellmoreefficientlythanbeampumpunits

•Identifyingtheoptimaltemperatureforrunningajetpumptoensureapolymercanbeselectedthatwillwithstandthedownholeconditions

Moderator: Damian Ramallo, Production Leader, Gran Tierra EnergySergio Flores, Production Engineer, Gran Tierra Energy


ARTIFICIAL LIFT INNOVATIONS: CASING PLUNGERS

11.10 Validating The Application Of A Plunger Casing System In The Neuquina Basin To Evaluate The Potential For Improving Recovery In Low Gross Production Wells

•Evaluatinghowtopowertheproductionsystembyusingtheenergygeneratedinthewelltominimizeoperatingcosts

•Applyingaproductionsystemtowellswithmedium/highgastoliquidratiostomaintainfluidproductioninlowproductiongrossingwells

•DefiningtheoptimalcasingdiameterusedintheMedanitoreservoirtodefinetheoptimalapparatus

andmaterialsneededforsuccessfulapplication•Definingthecapitalcostsofthetubingandsucker

rodpumptoevaluateifreplacingthepumpingsystemwillbeeconomical

Nicolas Cuestas, Extraction Engineer, Petrobras Argentina

Martín Ignacio Kennedy, Technical Advisor, Petrobras Argentina


LIGHT OIL: ARTIFICIAL LIFT SELECTION

11.50 Evaluating The Optimal Artificial Lift Selection Across The Life Of A Well To Minimize Production Losses

•Evaluatinggeologicalcharacteristicsofthereservoirincludingfluiddistributiontodefinetheoptimalproductionsystem

•Analyzinggeological,economicandworkloadfactorstoselecttheoptimalartificialliftsystem

•Assessingdepressurizationtoevaluatetheimpactonnaturalupwelling

Victor Perusini, Head Of Production, San Jorge Petroleum


12.30 Lunch In Exhibition Showcase Area

HEAVY OIL PRODUCTION OPTIMIZATIONDEFINING THE OPTIMAL WELL DESIGN TO ENSURE THE EFFECTIVE PRODUCTION OF FIELDS WITH VISCOUS OIL

PROPERTIES

MANAGING LOW PRESSURE WELLS

1.30 Selecting Optimal Surface And Downhole Equipment To Ensure Mobility Of Viscous Oil Within Wells With Low Production

•Describinghowsurfacelineshavebeenoptimizedtoimprovethemobilityofviscousoilfromthewellheadtobattery

•Identifyingtheoptimalpumpingunitdesigntomaximizeheavyoilfluidproductionandreducethefailureofthepump

•Evaluatinghowfrictionreductionchemicalsimprovethefluidmovementofviscousoilandreducewellheadtobatterypressure

Juan Miguel Linares, Production Manager, Sinopec Argentina

Aldo Sarelli, Hydrocarbon Processing Engineer, Sinopec Argentina

Federico G. Porta, Industrial Engineer, Sinopec Argentina

Joaquín Vaz, Industrial Engineer, Sinopec Argentina


GAS PRODUCTION OPTIMIZATIONEXAMINING HOW THE LATEST TECHNOLOGIES ARE BEING USED TO COST TO EFFECTIVELY DELIQUIFY WELLS AND IMPROVE THE RUN LIFE OF GAS LIFT

DELIQUIFICATION

2.10 Assessing How Capillary Technology, Chemical Injection, Plunger Lift And Polymer And Soap Agents Are Being Used To Control Water Downhole

•Assessinghowcapillarytechnologyandchemicalinjectioncancontrolwaterinthebottomholetopreventwellheadpressuredecreases

•Assessingtheadvantagesofusingaplungerliftsystemstodeliquifythewellandpreventworkovercosts

•Identifyingwellheadpressureandproductionsymptomstoforecastwellswithahighliquidratioearlyonandpreventdrowning

•Assessinghowutilizingpolymerandsoapagentscanextractwaterfromreservoirchannelswithoutremovingthewaterfromthewell

•Identifyingthemostefficientgasseparatortoensureatechnologyisselectedwhichdoesnotallowaliquidpresence

Gustavo Gonzales, Production Engineer, Capsa-Capex


2.50 Afternoon Refreshments In Exhibition Showcase Area

ESP

3.20 Identifying How ESP Lift Is Being Used To Simultaneously Improve The Run Life Of Low Pressure Wells And Minimize Energy Consumption

•Evaluatingtheoptimalreservoirpressureandgas-liquidrelationshipforESPtoensurethesystemcanoptimizeproductionwithinthereservoir

•DefiningtheoptimalreservoirpressureandtemperaturewhenusinganESPtooptimizethepumplife

•Examiningmethodsforreducingdowntimeduetoelectricalstop

•Assessingtheapplicationofmagnetmotorandspeeddrivetechnologytoreduceenergyconsumptionwhilstpumping

•PredictingthecapacityoftheESPtorunwithindeepwellstopreventcostlyinterventionsandreducefailure

•Evaluatingtheoptimalpumpforusewithvariouscasingdiameterstoensurethepumpisadequatelyprotected

•EvaluatingrealtimeESPproductiondatatoidentifyhowthepumpsystemisimpactingthereservoirrunlife

•Describingtheefficiencyofthegasliftsystemateachstageofthepumptoidentifystageswhereenergyconsumptioncanbereducedandgasproductioncanbeincreased


GAS FIELD: LIFT SELECTION

4.00 Evaluating Artificial Lift Management In Mature Oil Fields To Ensure The Right Lift Is Selected, Installed And Monitored

•Evaluatingtheselection,acquisition,installation,evaluation,monitoringandinspectionofliftmethodstoadoptamultidisciplinaryapproachtoliftselection

•Analyzinghowunderstandingthelocationandcultureofthefieldswillimpactthegasproductionoptimizationandcostofoperations

•AssessinghowproductionoptimizationrequirementschangeovertimetoidentifywhenwaterfloodingandEORprojectsarerequired

Marcelo Hirshfield, OPOGC, Pemex


SURVEILLANCEIDENTIFYING PRODUCTION MONITORING AND

AUTOMATION TECHNOLOGIES TO IMPROVE THE EFFECTIVENESS OF ARTIFICIAL LIFT AND MAXIMIZE

RECOVERY

PUMP OFF CONTROLLERS

4.40 Analyzing How Pump Off Controllers Are Being Installed And Maintained To Extend Run Life And Mitigate Downhole Failure

•Providingacasestudyofhowpumpoffcontrollerautomationhasfixedawellproblemandpreventedworkoverandinterventioncosts

•Explainingtheinstallationandmaintenancecostsforpumpoffcontrollerstocalculatethemonthlycostofsurfaceautomation

•Analysinghowtheautomationofproductionlevels,fluidlevelsandproductionweightcontrolscanpreventpumpbreakagesandsurfaceleaks

•Assessingtheaccuracyofusingpumpoffcontrollerstofixwellissuestoevaluateifthesystemshouldreplacepreviousmonitoringandwellmaintenancemethodologies

•EvaluatinghowcombiningSCADAandthepumpoffcontrollerhasminimizedbeampumpfailurethroughmoreefficientdatamanagement

Juan Miguel Linares, Production Manager, Sinopec Argentina

Aldo Sarelli, Hydrocarbon Processing Engineer, Sinopec Argentina

Federico G. Porta, Industrial Engineer, Sinopec Argentina

Joaquín Vaz, Industrial Engineer, Sinopec Argentina


5.20 - 6.20 Networking Drinks Reception In Exhibition Showcase Area


SAVE $2700 ARS


MITIGATING FAILURES, WATER AND POLYMER INJECTIONDay 2Thursday, July 24

8.30 Chair’s Opening Remarks

PREVENTING FAILURESUNDERSTANDING HOW FAILURE ANALYSIS, SAND,

PARAFFIN AND CORROSION CONTROL IS PREVENTING WELL INTERVENTIONS AND WORKOVERS

FAILURE ANALYSIS

8.40 Outlining How Production Monitoring Techniques Are Being Used To Predict Equipment Failure And Prevent Intervention And Workover Costs

•Determiningthemostcommoncausesoffailureinwellstopreventfailureinthepump,rod,surfaceandfacilities

•Explaininghowadownholefailureanalysisprogramcandeterminetheaccuraterunlifeofawellandcalculatethepulling-interventionindex

•Defininghowfailureanalysisdatasoftwarehasimprovedthewellrunlife

Alejandro Ameglio, Production Superintendent, Apache Argentina9.10 Question & Answer Session

SAND CONTROL

9.20 Assessing How Gravel Packers, Sand Filters And Sand Screens Are Removing Sand Cost-Effectively And Preventing Well Failures

•Defininghowthepercentageofsandwithinthereservoireffectspumpselectiontooptimizeproductionwithinhighsandcontentreservoirs

•Comparingartificialliftsandgasliftpumps’abilitytohandlesandcontenttodeterminetheoptimalpumpforusewhenproducingsolids

•Assessingthepullingindextodetermineifthesandshouldberemovedfromthereservoirorifthepumpcanoperatewithoutintervention

•Outlininghowgravelpackingisbeingusedtocontainthesandinthewellandpreventsandcleaninginterventions


10.00 Morning Refreshments In Exhibition Showcase Area

PARAFFIN CONTROL

10.30 Analyzing Optimal Conditions In Which To Utilize Paraffin And Asphaltene Management Chemicals To Prevent Stuck Pipe

•Outliningtheoptimalchemicalsforreducingparaffinblockagesdownholetomaintainwellperformanceandproduction

•Determininghowdeeptheparaffindispersershouldbeinjectedtoavoidparaffinblockageswithinthetubingstring

•Identifyingcasingandchemicalsuitesthathandleparaffintopreventdownholebottlenecks

•Providingchemicaldepositionanalysisresultstodetermineifthechemicalhasworkedeffectivelytoremovetheparaffindownhole

•Evaluatingtheoptionsforhandlingparaffindownholeandatthewellheaddevicestoavoiddepositionsandminimizeinterventions

Oscar Orellana, Production Supervisor, Total


CORROSION CONTROL

11.10 Evaluating The Type, Cost And Volume Of Chemical Treatments Being Used To Combat Surface And Downhole Corrosion And Prevent Pipeline Failures And Interventions

•Assessingchemicalreactionandequipmentinjectionpointstoidentifytheoptimallocationforthechemicalproducttocombatcorrosion

•Analyzingtheoptimalinjectionratesforcorrosionchemicalstoensuretargetlayerisreached

•Evaluatingthevolumeandcostperbarrelofcorrosionchemicaltreatmentrequiredtodetermineifwellreplacementismoreeconomicalthantreatment

•Explainingthechemistrycompositionofthecorrosioncontroltreatmenttodefinehowthechemicalwilltacklecorrosiondownhole

•Evaluatingthefluidcharacteristics,temperatureandpressureofthewelltoselectatreatmentwhichwillminimizecorrosioneffectively

Juan Manuel Garro, Corrosion Engineer, Pluspetrol


11.50 Lunch In Exhibition Showcase Area

CORROSION CONTROL METHODS

12.50 Identifying The Optimal Corrosion Control Methodologies Across The Most Problematic Areas Facing Corrosion Within Well Design

•Suckerrodcorrosion:evaluatingkeymethodologiesforpreventingpumpcorrosionwithinhighsalinitywellstominimizewellfailures

•Flowlinecorrosion:identifyingachemicaltreatmentthateffectivelycombatsoil,gasandsulphuricacidcorrosiontopreventpipelinebreakages

•Tubingcorrosion:howanoperatorhasevaluatedthetubingpigmentsdownholetoselectachemicaltreatmentwhichwillpreventH2SandCO2equipmentfailures

•Capillaryinjectioncorrosion:examiningifwellscanremainproductivewithparaffindownholetodetermineifchemicalinvestmentisrequired

•Bacteriacorrosion:classifyingcorrosionchemicaltreatmentswithinproductionfacilitiesover10yearsold

•Waterqualitycorrosion:understandinghowtoeffectivelyrunchemicalsfromthesurfacetodownholetoextendtherunlifeoftherodandpump

Oscar Orellana, Production Supervisor, Total


INTERVENTION

1.30 Minimizing Non-Productive Time During Interventions To Reduce The Cost Of The Workover Operation

•Identifyinghowtoreducestandbytimeswithininterventionoperationstoreducethecostoftheworkover

•Definingthetechnicallimitforworkoveroperationdrillingservicestopreventcomplexworkoveroperationsdamagingtheeconomicsofawell

Carlos Laluf, Head Of International Engineering Operations, Azabache Energy


INJECTIONEXAMINING THE EFFECTIVNESS OF WATER AND

POLYMER INJECTION, WATERFLOODING, CHEMICAL TREATMENTS AND CHEMICAL TRACERS IN OPTIMIZING

SECONDARY RECOVERY

WATER INJECTION PANEL

2.10 Evaluating Injection Assembly And Reservoir Dynamics To Ensure Waterflooding Optimizes Sweep Efficiency Within Multi-Layered Reservoirs

•Evaluatinginjectionpressure,volumeandlengthoftimetoinjectthereservoirtoidentifytheoptimaldesignforoptimizingrecovery

•Quantifyinginjectorpressurevarianceacrossfieldstoidentifythepressuresthatledtomaximumrecoveryincreases

•Qualifyingtheoptimalflowinjectionrateandwatershutoffpointtoidentifyiflowerorhigherfloodrateswillimproverecoveryfactor

•Identifyingtheoptimalpointwithinawell’srunlifetostimulatethereservoirtopreventproductiondecline

•Selectinghowmanyreservoirlayersshouldbefloodedsimultaneouslytoassesswhatistheoptimalinjectionverticalsweepefficiency

•Calculatingthecostofawaterfloodingproject;estimatedwellrunlifeandinvestmentcosttodetermineifwellreplacementismorecosteffective

•Identifyingmethodologiesforperforatingthinwaterfieldslayerstopreventwaterfloodingalllayersanddamageoverallwellrecovery

Francisco Queralt, Head Of Facilities & Construction, Americas Petrogas


2.50 Afternoon Refreshments In Exhibition Showcase Area

WATERFLOODING WATER TREATMENT

3.20 Defining The Optimal Water Quality And Volume Needed For Flooding To Calculate Treatment Requirements And Costs

•Definingtheminimumwaterinjectionqualitywhichiscompatiblewiththereservoirtopreventcorrosion,scaleandbacteriainthepump,rodandtubing

•Understandingthelevelofbrinewatersolidandgelremovalforrecyclingtoreducethevolumeoffreshwatersourcingrequiredforwaterflooding

•Evaluatinghowwatertreatmentchemistrycanbematchedtowaterqualitiestoavoidsurfaceanddownholedecomposition

•Definingthewatertreatmentplants,floatationunitsandchemicalsrequiredtoreduceionandsulphurcontentandwatersalinity

•Analyzinghowelectricitychangeswithinthewatercanbeusedtoseparatethewaterandcorrosionmaterialstopreventdeposition

•Comparingthecostperbarreloftreatmenttothechemical’sabilitytocleanthewatertoensuretheoperatingcostreducestheOPEX

Francisco Queralt, Head Of Facilities & Construction, Americas Petrogas


POLYMER INJECTION

4.00 Identifying The Optimal Polymer Injection Technique To Improve Aerial Sweep Efficiency And Prevent Water Diversion

•Evaluatingwellsurveillancedatatodetermineifpolymerscansuccessfullyincreasethesweepefficiencywithinawaterfloodproject

•Matchingthepolymertothereservoirpressure,temperatureandfluidmovementto:

•Ensurethetreatmentwillhavethedesiredtransitandactivationtimewithinthereservoir

•Preventcookingthroughoverheatingthepolymer

•Avoidachangeinpolymerelasticityduetohighgascontent

•DesigningthepolymerinjectionratetoimprovetheEORofthewell

Carlos Berto, Head Of Operations, Tecpetrol


MONITORING & CHEMICAL TRACERS

4.40 Analyzing The Monitoring Benefits Of Chemical Tracers In Evaluating The Success Of The Waterflood Operation And Improve Future Injection

•UtilizingtracerstocomparethepredictedandactualverticalandaerialsweepefficiencyofthewaterfloodtodetermineifproductionincreasescanbeattributabletotheEOR

•AssessinghowmonitoringinjectionthroughtheSCADAsystemcanidentifywellfailurestoimprovetherunlifeofthewell

•Howanoperatorutilizedwatertracerresultstolowerthewatercutbyidentifyingthehighwatercontentlayerandavoidinginjection

•Outlininghowwatertracerdatahasimprovedinjectionthroughdefiningtheoptimalreservoirinjectionpressuretoincreaseproductionrecovery

•Assessingifusingchemicaltracerdatacanensureonlyspecificreservoirlayersarefloodedtomaximizewellproduction


5.20 Chair’s Closing Remarks


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Mature Fields Argentina Production Optimization 2014 Congress