(贝克休斯的关于裸眼封隔器的材料).ppt

2000 Baker Hughes IncorporatedAll rights reserved.Openhole Packer 2005 Baker Hughes IncorporatedAll rights reserved.MPas New Era Open Hole Packers 2005 Baker Hughes IncorporatedAll rights reserved.MPas 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 Design 2005 Baker Hughes IncorporatedAll rights reserved.MPas Open Hole Packer SequenceRun-In PositionSet PositionShifting Balance Sleeve(Initiating Setting)2005 Baker Hughes IncorporatedAll rights reserved.Shifting Balance Sleeve(Initiating Setting)MPas Open Hole Packer SequenceRun-In PositionSet Position 2005 Baker Hughes IncorporatedAll rights reserved.Run-In PositionRun-In PositionShifting Balance SleeveShifting Balance Sleeve(Initiating Setting)(Initiating Setting)Set PositionSet PositionMPas Open Hole Packer Sequence 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 Specifications 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”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 Specifications 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/Brine 2005 Baker Hughes IncorporatedAll rights reserved.Example Installation Sequence 2005 Baker Hughes IncorporatedAll rights reserved.Setting ToolsSSCMAICHB-1Cup Tool 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 History 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 History 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 History 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 Details 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.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 isolation 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.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 Model 2005 Baker Hughes IncorporatedAll rights reserved.REPacker 4-1/2”by 5-5/8”in 6.3”Fixture 2005 Baker Hughes IncorporatedAll rights reserved.REPacker 2-7/8”by 4.2”in 4.9”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 Characteristics 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 Size4-1/25-5/86.85-1/28106-5/88-1/88.96-5/8910.5 2005 Baker Hughes IncorporatedAll rights reserved.New Products Being DevelopedModular Split PackernWaiting on Swell/Pressure TestnEasy to Install Directly to Customers Pipe/ScreensnCan be Molded by Outside Vendor to Reduce Cost and Ease Manufacturing LoadsnWill be Available with Metal End Sleeves and Have Ability to Interlock Multiple SegmentsnUS Patent Application in Place 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 Sleeves 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-onREPacker 2005 Baker Hughes IncorporatedAll rights reserved.REPackerCritical Operating Factors for REPackers 2005 Baker Hughes IncorporatedAll rights reserved.Primary Factors Affecting REPacker Performance n%SwellnSwell RatenElement Length 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%swell 2005 Baker Hughes IncorporatedAll rights reserved.Salinity 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 volume 2005 Baker Hughes IncorporatedAll rights reserved.Swell Rate vs.Temperature 2005 Baker Hughes IncorporatedAll rights reserved.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 rating 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 F 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 selectivity 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 Perforating 2005 Baker Hughes IncorporatedAll rights reserved.Case HistoriesnBakken Shale(US)nDec 2007n8 Stage frac with Hyd.Frac sleevesnLateral Length:7740n24hr start-finishnNext step:Tri-lateral Selective stage fracingFrac-Point sleeves30+REs 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 required