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Results
Acknowledgement:
Assignment and Calibration of Relative Permeability by Hydrostratigraphic Units: A Novel Approach for Multiphase Flow Analyses
Case Study: CO2-EOR Operations at the Farnsworth Unit, Texas
NumericalModel
RelativePermeabilityRelationships
AbstractAmongthemostcriticalfactorsforgeologicalCO2 storagesitescreening,selectionandoperationiseffectivesimulationofmultiphaseflow
andtransport.Relativepermeabilityisprobablythegreatestsourceofpotentialuncertaintyinmultiphaseflowsimulation,secondonlytointrinsicpermeabilityheterogeneity.ThespecificrelativepermeabilityrelationshipassignedgreatlyimpactsforecastsofCO2 trappingmechanisms,phasebehavior,andlong-termplumemovement.AprimarygoalofthisstudyistoevaluatetheimpactsandimplicationsonCO2-EORmodelforecastsofdifferentmethodsofassigningrelativepermeabilityrelationships.Weappliedanovelapproachtoassigningrelativepermeabilityrelationshipsinnumericalmodels.Inpreviousresearch,most models
assignrelativepermeabilityfunctionsonthebasisofgeologicformationorrocktype.Inthisstudy,weassignandcalibraterelativepermeabilitybyhydrostratigraphicunits,extendingtheseminalworkofMaxey(1964)tomultiphaseflow.OngoingworkbytheSWPhasidentifieddistinctregionsthatarebelievedtoexhibitsimilarflowcharacteristicsusingtheImprovedHydraulicFlowUnits (IHFU)method.Corefromeachoftheseflowregionswasscannedbymicro-computer-tomography(micro-CT)andMercuryIntrusionCapillaryPressure(MICP)measurementswerecompleted.Specific,constrainedrelativepermeabilityrelationshipswereassignedtoeachhydrostratigraphicunit.Resultsofforwardsimulationswiththenewly-calibratedmodelswillbecomparedtothoseofexistingmodelaswellasawiderangeofdifferentrelativepermeabilityrelationship.ThestudysiteistheFarnsworthUnit(FWU)inthenortheastTexasPanhandle,anactiveCO2-EORoperation.Thetargetformationisthe
Morrow‘B’Sandstone,aclasticformationcomposedofmediumtocoursesands.ThestudywasundertakenaspartoftheSouthwestRegionalPartnershiponCarbonSequestration(SWP)underAwardNo.DE-FC26-05NT42591.
TwoApproaches1. SingleRelativePermeabilitycurveassignedtothewholemodeldomain:[1]MorrowSandstonerelativepermeabilityrelationship,[2]
Linearrelativepermeabilityrelationship,[3-5]eachindividualHydraulicFlowUnit(HFU)curvefromallthreeRegionmodels
HydraulicFlowUnit(HFU)relativepermeabilitycurves• [3]Region1curvesvarythecurveparameterlambdaandthe
saturationend-points• [4]Region2curvesvarythecurveparameterlambda,the
saturationend-points,andtherelativepermeabilityend-points• [5]Regions3curvesvarythecurveparameterlambdaandthe
saturationend-pointsweredeterminedfrommercuryintrusioncapillarypressuremeasurementsforeachoftheHydraulicFlowUnits(HFU)
ModelDomain
Nathan Moodie, William Ampomah, Wei Jia, Brian McPherson
FundingforthisprojectisprovidedbytheU.S.DepartmentofEnergy's(DOE)NationalEnergyTechnologyLaboratory(NETL)throughtheSouthwestRegionalPartnershiponCarbonSequestration(SWP)underAwardNo.DE-FC26-05NT42591
FarnsworthUnit,OchiltreeCounty,TexasMatureoilfieldintheAnadarkoBasin• Primaryproductionstartingin1955• Waterflooding startsinlate1964• CO2-EORstartsinlate2010• EstimatedOOIP~120millionbarrels• Averagepaythicknessis22ft
#13-10AInjectionwell
PetrelE&PSoftwarePlatform• 3-DMeshcreation– 103x95x4(x,y,z)with33,756active
cells• Gridpropertiescreation– permeability&porosity
distribution• Initialconditionsassignment– Watersaturation,Oil
saturation,andPressure- INCONdatafromhistorymatchedwaterfloodmodel
• WaterAlternatingGas(WAG)schedulefor22injectionwells– pureCO2 usedasgasstream
• Bottomholepressurelimits(2400psi)for35productionwells
- Wellsshutwhenwatercutisabove98%
• ThetotalamountofstoredCO2 predictedisbetween3.0milliontonsand3.4milliontonsacrossallofthecurvesstudied• TheRegions3modelpredicts14%moreCO2 asamobilephaseand8%lessdissolvedphasewhencomparedtotheBaseCase• ThethreeHFUregionsmodels(Regions1,2,3)showa26%varianceinfreegasinplaceandonlya3%variationinthetotalgasinplace• Thereisa79%differenceinthevolumeoffreeCO2 predictedacrossallrelativepermeabilitycurvestested• Thereisa49%differenceinthedissolvedgasphaseacrossalltherelativepermeabilitycurvestested
FlowRegions
GasInPlace,freegasanddissolvedgas
HydraulicFlowUnits(HFU)mapoftheentirereservoirshowingthesimulationmodeldomainoutlinedinred.HydraulicFlowUnitswereidentifiedbyD.Ross-Cross,W.Ampomah etal.(2016)(SPE-180375-MS)andusedforthefivegroupedsaturationregionsinthesimulationmodels;HFU1-2,HFU3-4,HFU5,HFU6,HFU7-8.
RelativePermeabilityassignmentbyhydrostratigraphicunits.UniquehydrostratigraphicunitsweredelineatedasHydraulicFlowUnit(HFU)wherethepropertiesthatcontrolfluidflowareinternallyconsistentbutdistinctfromotherrockunits.TheWinland R35methodwasusedtoidentifytheHFUsbyprovidingameansofcorrelatingporositytopermeabilitybyassumingthatwhenasampleis35%saturatedduringaMICPtestcontinuousflowpathsareestablished.Theseflowunitsarethenassignedarelativepermeabilitycurveandforwardsimulationswerecarriedouttoelucidatetheinfluenceofthismethod.
FWUfaultsmodelwithalltheinjectionandproductionwellsusedinthisstudy.Faultsarenotbarrierstoflowinthismodel.
InitialConditionsInitialoilsaturationandwatersaturationwasderivedfromahistorymatchedprimaryproductionandwaterflooding simulation.
OilSaturation WaterSaturation
Permeabilitydistributioninthesimulationmodel.ThisdistributionwasusedtocreatetheHFUrelationshipbytheSWP
-
10,000,000
20,000,000
30,000,000
40,000,000
50,000,000
60,000,000
Gas
Vol
ume
[MSC
F]
Date
Gas in place
-5,000,000
10,000,000 15,000,000 20,000,000 25,000,000 30,000,000 35,000,000 40,000,000 45,000,000 50,000,000
Gas
Vol
ume
[MSC
F]
Date
Solution gas in place
-
5,000,000
10,000,000
15,000,000
20,000,000
25,000,000
30,000,000
Gas
Vol
ume
[MSC
F]
Date
Free gas in place
3,000 3,200 3,400 3,600 3,800 4,000 4,200 4,400 4,600 4,800 5,000
Pres
sure
[psi
]
Date
Pressure
Base Model Regions3 Model
Three-phasesaturationmapsattheendofthesimulation(20yearsofCO2-EOR)TheBaseCaseandRegions3modelshadverysimilarpressureprofilesbutdifferentCO2 phasedistribution,oilproduction,andgasproduction.TheyellowandbrownboxeshighlightareasofsignificantvariationbetweentheBaseModelandtheRegions3Model[1].TheCO2 plumesaroundeachoftheinjectionwellsintheRegions3modelshowalotofvariationfromtheBaseCasemodel,withsomewellspredictingfarlessgasphase,especiallyintheSouth-centralportionofthereservoir.Whentheendcasesareevaluated,Region2modelHFU1-2andHFU7-8relativepermeabilitycurves,thedifferenceinphasepredictionsisdrastic[2].
BM
-M2-
Def
3RP
BM
-M2-
StnI
3RP
LM
R1
R1-
HFU
1-2 R
1-H
FU3-
4
R1-
HFU
5
R1-
HFU
6
R1-
HFU
7-8
R2
R2-
HFU
1-2 R2-
HFU
3-4
R2-
HFU
5
R2-
HFU
6
R2-
HFU
7-8
R3
R3-
HFU
1-2
R3-
HFU
3-4
R3-
HFU
5
R3-
HFU
6
R3-
HFU
7-8
-14,000,000
-12,000,000
-10,000,000
-8,000,000
-6,000,000
-4,000,000
-2,000,000
0
2,000,000
4,000,000
6,000,000
8,000,000
10,000,000
12,000,000
Variation in Gas In Place
FGIP
SGIP
TGIP
1 2
3
4 5
BaseModel
1
2
49%
79%
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