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2000 Baker Hughes IncorporatedAll rights reserved.Openhole PackerOpenhole Packer 2005 Baker Hughes IncorporatedAll rights reserved.MPas New Era Open Hole PackersMPas New Era Open Hole Packer 2005 Baker Hughes IncorporatedAll rights reserved.MPas New Era Open Hole PackerMPas New Era Open Hole Packer 2005 Baker Hughes IncorporatedAll rights reserved.BodyElastomer Packing Element CoreKevlar Reinforcement Braided Steel Structural LayerDeformable Back Up RingsOuter Elastomer CoverMPas Packer DesignBodyElastomer Packing Element 2005 Baker Hughes IncorporatedAll rights reserved.MPas Open Hole Packer SequenceRun-In PositionSet PositionShifting Balance Sleeve(Initiating Setting)MPas Open Hole Packer Sequenc 2005 Baker Hughes IncorporatedAll rights reserved.Shifting Balance Sleeve(Initiating Setting)MPas Open Hole Packer SequenceRun-In PositionSet PositionShifting Balance SleeveMPas O 2005 Baker Hughes IncorporatedAll rights reserved.Run-In Run-In PositionPositionShifting Balance Shifting Balance SleeveSleeve(Initiating Setting)(Initiating Setting)Set PositionSet PositionMPas Open Hole Packer SequenceRun-In PositionShifting Balanc 2005 Baker Hughes IncorporatedAll rights reserved.Size:5-1/2”Size:5-1/2”Maximum Packer O.D.:8.03”/8.075”Maximum Packer O.D.:8.03”/8.075”Minimum ID:4.592”4.802”Minimum ID:4.592”4.802”Setting Mechanism:HydrostaticSetting Mechanism:HydrostaticCylinder Collapse Rating:10,700 psi Cylinder Collapse Rating:10,700 psi(80ksi MYS)(80ksi MYS)Mandrel Burst Rating:8,400 psi Mandrel Burst Rating:8,400 psi(80ksi MYS)(80ksi MYS)Mandrel Tensile Strength:261,000#Mandrel Tensile Strength:261,000#(80ksi MYS)(80ksi MYS)Setting Tool Required:Workstring Shifting ToolSetting Tool Required:Workstring Shifting ToolMaximum Ovality Tested(to date):8-1/2”x 12”Maximum Ovality Tested(to date):8-1/2”x 12”MPas Packer SpecificationsSize:5-1/2”MPas Packer Spec 2005 Baker Hughes IncorporatedAll rights reserved.MPas Packer SpecificationsSize:6-5/8”Size:6-5/8”Maximum Packer O.D.:9.125”Maximum Packer O.D.:9.125”Minimum ID:5.696”Minimum ID:5.696”Setting Mechanism:HydrostaticSetting Mechanism:HydrostaticCylinder Collapse Rating:5,000 psi Cylinder Collapse Rating:5,000 psi(80ksi MYS)(80ksi MYS)Mandrel Burst Rating:5,700 psi Mandrel Burst Rating:5,700 psi(80ksi MYS)(80ksi MYS)Mandrel Tensile Strength:575,000#Mandrel Tensile Strength:575,000#(80ksi MYS)(80ksi MYS)Setting Tool Required:Workstring Shifting ToolSetting Tool Required:Workstring Shifting ToolMaximum Ovality Tested(to date):9-1/2”x 11”Maximum Ovality Tested(to date):9-1/2”x 11”MPas Packer SpecificationsSiz 2005 Baker Hughes IncorporatedAll rights reserved.Size:4-1/2”Size:4-1/2”Maximum Packer O.D.:5.625”Maximum Packer O.D.:5.625”Minimum ID:3.8”Minimum ID:3.8”Setting Mechanism:Hydrostatic/HydraulicSetting Mechanism:Hydrostatic/HydraulicTested w/4,100 psi Hydrostatic+3,000 psi Hydraulic Tested w/4,100 psi Hydrostatic+3,000 psi Hydraulic Setting PressureSetting PressureCylinder Collapse Rating:7,500 psi Cylinder Collapse Rating:7,500 psi(80ksi MYS)(80ksi MYS)Mandrel Burst Rating:8,440 psi Mandrel Burst Rating:8,440 psi(80ksi MYS)(80ksi MYS)Mandrel Tensile Strength:289,000#Mandrel Tensile Strength:289,000#(80ksi MYS)(80ksi MYS)Setting Tool Required:Workstring Cup ToolSetting Tool Required:Workstring Cup ToolMaximum Ovality Tested(to date):6”x 7-1/2”Maximum Ovality Tested(to date):6”x 7-1/2”MPas Packer SpecificationsSize:4-1/2”MPas Packer Spec 2005 Baker Hughes IncorporatedAll rights reserved.Example Installation SequenceTD Hole,Condition Mud,POOHRun Liner Assy to Depth,Correlate,Hang,Circulate Hole Volume w/DIFSet Liner Top PackerPull up Inner String,Set MPas PackersPull Above Liner Top,Spot Spacers,Displace Casing w/BrineExample Installation SequenceT 2005 Baker Hughes IncorporatedAll rights reserved.Example Installation SequenceExample Installation Sequence 2005 Baker Hughes IncorporatedAll rights reserved.Setting ToolsSSCMAICHB-1Cup ToolSetting ToolsSSCMAICHB-1Cup To 2005 Baker Hughes IncorporatedAll rights reserved.Location:Timor Sea,AustraliaOperator:ConocoPhillipsField:Bayu UndanDate:1st well May 2004#Wells:3#MPas Packers:26(10,8,8)Max Deviation:62 DegreesMax Depth:10,352 ft TVDMax Temperature:270 Deg FJob Description:Isolation for water shut off One-Trip System with SelectSet Collet tool run as an integral part of the inner string.Packers set in low-permeability silt stringers to enable future shut-off of water as it ingresses.4.5 hours from TD to set and individually test each of packer.Multi-Zone Perforated Pipe Case HistoryLocation:Timor Sea,Australi 2005 Baker Hughes IncorporatedAll rights reserved.Location:Saudi ArabiaOperator:ARAMCOField:Zuluf Main SandDate:December 2002#Wells:1#MPas Packers:4Max Deviation:90 DegreesMax Depth:6,500 ft TVDMax Temperature:200 Deg FJob Description:One-Trip System with MAIC tool run as an integral part of the inner string.Packers used to increase production capabilities of equaliser screen.PLT run and isolation proven.Equaliser Screen Case HistoryLocation:Saudi ArabiaOperat 2005 Baker Hughes IncorporatedAll rights reserved.Location:Eastern Province,Saudi ArabiaOperator:ARAMCOField:GHZL-9#Wells:1Date:December 2003#MPas:2Max Deviation:81 DegreesMax Depth:13,500 ft TVDMax Temperature:260 Deg FJob Description:All project objectives were met.Deepest ML Junction deployment depth to date of 14,082 ft.First FBIV w/Hook Hanger and LEN systems.First MPas Instillation in ML Well.Multilateral Case HistoryLocation:Eastern Province,2005 Baker Hughes IncorporatedAll rights reserved.nMax Temperature270F nMax Dogleg Severity8/100ft nMax Measured Depth20,682 ftnMax Total Vertical Depth13,500 ftnMax Deviation93.1nMax Deviation at Packer89.5nMax Mud Weight10.6ppgMPas Installations DetailsMax Temperature270F MPas 2005 Baker Hughes IncorporatedAll rights reserved.REPackernThe water reactive section consists of water absorbing particles incorporated in a field proven Nitrile-based polymer.These particles swell via absorbing water which in turn expands the rubber without being physically absorbed into the rubber matrix which can adversely effect properties nThe oil reactive section utilizes oleophillic polymers that absorb hydrocarbons into the matrix.This process is a physical uptake of the hydrocarbon which swells,lubricates and decreases the mechanical strength of the polymer chain as it expands.REPackerThe water reactive sec 2005 Baker Hughes IncorporatedAll rights reserved.REPacker Features&BenefitsnSimple deployment,requires no running tools nSimple installation,no special personnel requirednNo moving parts nRubber bonded to mandrel allows for run in through deviationsnOptimized for maximum expansion while retaining critical propertiesnSeal self-energizes in annular fluidsnContinues to react with well bore fluids to provide long term annulus isolationREPacker Features&Benefits 2005 Baker Hughes IncorporatedAll rights reserved.ARAMCO 1/5 Scale Reactive Element Packer Test(Oil Reactive Element)n7”(1.4”)by 8.2”(1.64”)in 8.5”(1.7”)5000 PSIn4.5”(0.9”)by 5.8”(1.16”)in 6.125”(1.23”)5000 PSIn3.5”(0.7”)by 5.8”(1.16”)in 6.125”(1.23”)3900 PSI REPackers Post-TestREPackers Post-TestRE Packers Pre-TestRE Packers Pre-TestNote:The packers were not tested to failure.Maximum differential pressure exceeds values shown.ARAMCO 1/5 Scale Reactive Elem 2005 Baker Hughes IncorporatedAll rights reserved.Full Scale Testingn2-7/8”by 4.2”OD 9 ft.Water-Reactive in 4.9”4,700 PSI(63%Swell)n4-1/2”by 5-5/8”9 ft Water Reactive in 6.3”3,500 PSI(70%Swell)n5-1/2”by 7-3/4”6 ft.Oil Reactive in 8.9”1,750 PSI(64%Swell)nThese Test Results Used to Develop Math ModelFull Scale Testing2-7/8”by 4.2005 Baker Hughes IncorporatedAll rights reserved.REPacker 4-1/2”by 5-5/8”in 6.3”FixtureREPacker 4-1/2”by 5-5/8”in 2005 Baker Hughes IncorporatedAll rights reserved.REPacker 2-7/8”by 4.2”in 4.9”REPacker 2-7/8”by 4.2”in 4.2005 Baker Hughes IncorporatedAll rights reserved.New Products Being TestedImproved Water Swell Rubber CompoundnImproved Durometer(75 Compared to 50)nGreater Maximum Swell%(130 Compared to 100 Wrapped on a Mandrel)nBetter/Easier Bonding CharacteristicsNew Products Being TestedImpro 2005 Baker Hughes IncorporatedAll rights reserved.New Product Waiting on Test ResultsRCPacker w/Improved Water Swell Rubber CompoundnUse 200%Swell for Swelling Elastomer When Used in RCPacker ElementnInflation w/Fresh Water or Fresh Water MudnTesting w/New Elastomer and Improved Manufacturing Techniques May Allow Swell Greater Than 200%RCPackerMandrel SizeElement Run In OD200%Swell Hole Size4-1/25-5/86.85-1/28106-5/88-1/88.96-5/8910.5New Product Waiting on Test Re 2005 Baker Hughes IncorporatedAll rights reserved.New Products Being DevelopedModular Split PackerWaiting on Swell/Pressure TestEasy to Install Directly to Customers Pipe/ScreensCan be Molded by Outside Vendor to Reduce Cost and Ease Manufacturing LoadsWill be Available with Metal End Sleeves and Have Ability to Interlock Multiple SegmentsUS Patent Application in PlaceNew Products Being DevelopedMo 2005 Baker Hughes IncorporatedAll rights reserved.New Products Being DevelopedSlip on PackernInstallation Tool,Procedure Under DevelopmentnLength Expected 1-3 EachnCan be Mandrel Wrapped by Outside Vendor to Reduce Cost and Ease Manufacturing LoadsnMay be Available with Metal End SleevesNew Products Being DevelopedSl 2005 Baker Hughes IncorporatedAll rights reserved.Wellbore Isolation PortfolionReactive Element(RE)Optimized for maximum expansion while retaining critical mechanical and chemical propertiesNo running tools requiredNo specialist requiredSelf-energizes in water or oil environment(2 separate polymers)Element retains seal in hydrocarbon or water environmentsHydrocarbon exposure causes no deterioration of critical water-reactive seal element propertiesnReactive Element TechnologyREPackerREBarrierHingedStretch-onREPackerWellbore Isolation PortfolioRe 2005 Baker Hughes IncorporatedAll rights reserved.REPackerCritical Operating Factors for REPackersREPackerCritical Operating Fac 2005 Baker Hughes IncorporatedAll rights reserved.Primary Factors Affecting REPacker Performance n%SwellnSwell RatenElement LengthPrimary Factors Affecting REP 2005 Baker Hughes IncorporatedAll rights reserved.Factors Affecting%Swell nFluid CompositionWater swell elastomernHigher salinity=lower%swellnLower salinity=higher%swellnDivalent salts(CaCl2,CaBr2,ZnBr2)=little to no swellOil Swell ElastomernHeavy oil=lower%swellnLight oil=higher%swellFactors Affecting%Swell Flui 2005 Baker Hughes IncorporatedAll rights reserved.Salinity vs.%SwellSalinity vs.%Swell 2005 Baker Hughes IncorporatedAll rights reserved.Factors That Affect Swell RatenTemperatureHigher temperature=higher swell rateLower temperature=lower swell ratenOD of elementElement OD increases at similar rateIndependent of total rubber volumeFactors That Affect Swell Rate 2005 Baker Hughes IncorporatedAll rights reserved.Swell Rate vs.TemperatureSwell Rate vs.Temperature 2005 Baker Hughes IncorporatedAll rights reserved.Swell Rate vs.Element OD Swell Rate vs.Element OD 2005 Baker Hughes IncorporatedAll rights reserved.REPacker Pressure Rating Affects n%SwellLess%swell=higher pressure ratingMore%swell=lower pressure ratingnTemperatureLower temperature=higher pressure ratingHigher temperature=lower pressure ratingnElement lengthLonger element=higher pressure ratingShorter element=lower pressure ratingREPacker Pressure Rating Affec 2005 Baker Hughes IncorporatedAll rights reserved.Recent Developments(contd)nREPacker Fullscale Testing4.5”x 5.625”x 10 ft oil-swell in 6”hole tested nHeld 10,000 psi for 24 hours 230F(no bypass)4.5”x 5.625”x 10ft water-swell in 6”hole nHeld 10,000 psi for 24 hours 230F(no bypass)5.5”x 7.75”x 10ft water-swell in 8.5”hole ntested to 4,500 psi(fixture limit)at 230F4.5”x 5.875”x 25ft oil-swell in 6.250”hole ntested to 10,000 psi at 290 deg FRecent Developments(contd)RE 2005 Baker Hughes IncorporatedAll rights reserved.Case HistoriesnOffshore India(Oct 07)nLevel 3 Hook w/4-1/2”RE 6”OH lateralnSliding Sleeves to shut-off water inflownLEN installed for selectivityCase HistoriesOffshore India(2005 Baker Hughes IncorporatedAll rights reserved.Case HistoriesnOnshore Mexico(Oct 07)n(3)5-1/2”x 6-1/8”10ft oil-swell REs with liner hangern6-1/2”OH(normally cemented)nPacker depths:5715m,5825m,5895m.nReduced rig time by 2 daysnEliminated Cementing and PerforatingCase HistoriesOnshore Mexico(2005 Baker Hughes IncorporatedAll rights reserved.Case HistoriesnBakken Shale(US)nDec 2007n8 Stage frac with Hyd.Frac sleevesnLateral Length:774024hr start-finishNext step:Tri-lateral Selective stage fracingFrac-Point sleeves30+REsCase HistoriesBakken Shale(US 2005 Baker Hughes IncorporatedAll rights reserved.Case HistoriesnBolivia(Dec 07)n(2)4-1/2”x 5.8”oil-swell REsnSet inside 6.25”sidetracked OHnDeepest ever RE Job to date5440m and 5960mnEliminated risk from cement and perforatingnNo running tools/personnel requiredCase HistoriesBolivia(Dec 07)2000 Baker Hughes IncorporatedAll rights reserved.我们的共同目标我们的共同目标!追求人生的美好追求人生的美好!我我们们的共同目的共同目标标!追求人生的美好追求人生的美好!
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