Mukul M. SharmaMukul M. Sharma

Professor and ChairmanProfessor and ChairmanDepartment of Petroleum &Department of Petroleum & GeosystemsGeosystems EngineeringEngineering

University of Texas at AustinUniversity of Texas at Austin

Injection Water ManagementOpportunities and Challenges

Many Reasons to Inject WaterMany Reasons to Inject WaterWaterflooding Waterflooding (recover oil)(recover oil)–– Produced waterProduced water–– Sea waterSea water–– Fresh water sourceFresh water sourcePressure maintenancePressure maintenanceWater disposalWater disposal–– Produced waterProduced water

Regardless of the source, water handling and injection often is the single biggest operating cost for producers.

Subsurface Water InjectionSubsurface Water InjectionWe estimate ~ 300 million bbl of water/day We estimate ~ 300 million bbl of water/day is injected into the subsurface.is injected into the subsurface.

We estimate that over We estimate that over $50 billion$50 billion is spent is spent annually on water injection. annually on water injection.

Stricter offshore water quality requirements Stricter offshore water quality requirements favor water reinjection for disposal.favor water reinjection for disposal.

Produced water/oil ratio increasing in Produced water/oil ratio increasing in mature fields.mature fields.

Opportunities and ChallengesOpportunities and ChallengesChallengesChallenges

Design water handling and injection systems to Design water handling and injection systems to reduce the cost of water injection. reduce the cost of water injection. –– Specify injection water quality, rates & pressuresSpecify injection water quality, rates & pressures–– Subsurface separation?Subsurface separation?–– Subsea vs Subsea vs topsidestopsides

Reduce water cut (the holy grail).Reduce water cut (the holy grail).

OpportunitiesOpportunitiesMajor cost reductions to improve production Major cost reductions to improve production economics.economics.Significant improvements in oil recovery.Significant improvements in oil recovery.

The Cost of Water InjectionThe Cost of Water InjectionFluids Handling CostsFluids Handling CostsPiping and TransportationPiping and TransportationPumpingPumping

Costs Depend on Costs Depend on Location andLocation andObjectivesObjectives

P maintenanceP maintenanceWater disposalWater disposalWaterfloodingWaterflooding

Decisions, Decisions!!!Decisions, Decisions!!!Your water management decisions will have a Your water management decisions will have a

very significant impact on project economics.very significant impact on project economics.How clean should the water be?How clean should the water be?–– Controls design of the treatment facility.Controls design of the treatment facility.

Injection rates and pressure?Injection rates and pressure?–– Injector performance ?Injector performance ?–– Impact on oil recovery?Impact on oil recovery?

Well completion design for injectorsWell completion design for injectorsTopsides Topsides vs vs subsub--sea separation.sea separation.DownholeDownhole vsvs surface separation.surface separation.

DownDown--hole Separationhole SeparationOpportunitiesOpportunities

Minimizes surface facilitiesMinimizes surface facilitiesMinimizes fluids handlingMinimizes fluids handlingReduced lifting costs Reduced lifting costs

DownDown--hole Separationhole SeparationChallengesChallenges

Not widely used because:Not widely used because:–– Needs right Needs right wellborewellbore configurationconfiguration–– Reservoir requirementsReservoir requirements–– Needs expensive hardwareNeeds expensive hardware–– DownholeDownhole water qualitywater quality–– Marginal economic benefitsMarginal economic benefits–– System maintenance System maintenance

Ultimately applicable in only Ultimately applicable in only a small number of casesa small number of cases

SubSub--Sea SeparationSea Separation

XT XT

Separator

Oil ProductionProduced Water

Injection

Pump

SubSub--Sea SeparationSea SeparationOpportunitiesOpportunities

Minimizes topsides space and equipment Minimizes topsides space and equipment requirementsrequirementsReduced risk of hydrate formation in lines.Reduced risk of hydrate formation in lines.Allows higher oil flow rates since less water is Allows higher oil flow rates since less water is being pumpedbeing pumpedReduces the hydrostatic head (back pressure) Reduces the hydrostatic head (back pressure) on the risers and flow lines.on the risers and flow lines.ReRe--injection of the separated water and gas can injection of the separated water and gas can reduce disposal costs and maintain reservoir reduce disposal costs and maintain reservoir pressure.pressure.

SubSub--Sea SeparationSea SeparationChallengesChallenges

Expensive equipment and installationExpensive equipment and installationWater separation and water qualityWater separation and water qualitySand productionSand productionApplicable in some fields (deep water, Applicable in some fields (deep water, high waterhigh water--cut) late in the life of the field.cut) late in the life of the field.Water quality for injection.Water quality for injection.Location of appropriate injection zones.Location of appropriate injection zones.

Fluids Handling DecisionsFluids Handling DecisionsHow clean should the water be?How clean should the water be?–– Controls design of the treatment facility.Controls design of the treatment facility.

Injection rates and pressure?Injection rates and pressure?–– Injector performance ?Injector performance ?–– Impact on oil recovery?Impact on oil recovery?

Well completion design for injectorsWell completion design for injectorsTopsides Topsides vs vs subsub--sea separation.sea separation.DownholeDownhole vsvs surface separation.surface separation.

Gulf of Mexico Case StudyGulf of Mexico Case StudyWater Injection Project HistoryWater Injection Project History

Expected injection rates: 10,000 Expected injection rates: 10,000 bbl/day/wellbbl/day/wellAvoidance of fracturing was essential to:Avoidance of fracturing was essential to:(a) avoid early water breakthrough, and (a) avoid early water breakthrough, and (b) maintain water injection in the target (b) maintain water injection in the target sandsand1 Darcy sand, gravel pack completions.1 Darcy sand, gravel pack completions.Low initial Low initial injectivityinjectivity, high skins., high skins.

WaterfloodWaterflood Facilities (GOM)Facilities (GOM)

Seawater taken from 150’Seawater taken from 150’ subseasubsea

DeoxygenationDeoxygenation to 200 ppb by countercurrent gas to 200 ppb by countercurrent gas strippingstripping

Deoxygenated to <10 ppb by chemical scavengersDeoxygenated to <10 ppb by chemical scavengers

SodiumSodium hypochloritehypochlorite used for bacteria controlused for bacteria control

Calcium carbonate scale inhibitor usedCalcium carbonate scale inhibitor used

Primary multimedia filters usedPrimary multimedia filters used

Secondary cartridge filters (5 to 10 Secondary cartridge filters (5 to 10 µµm)m)

Water Quality (GOM)Water Quality (GOM)

Solids content in injection waters, 1 to 7Solids content in injection waters, 1 to 7 ppmppm

Average particle size 2 to 3 Average particle size 2 to 3 µµmm

Elemental analysis performed on digested Elemental analysis performed on digested solidssolids

Excellent water qualityExcellent water quality

Simple rules of thumb predict long half lifeSimple rules of thumb predict long half life

Rather rapid decline inRather rapid decline in injectivityinjectivity actually actually observedobserved

Injection Rate and Pump Injection Rate and Pump Pressure Well A10Pressure Well A10(From Sharma et. al. 1996)(From Sharma et. al. 1996)

0

2000

4000

6000

8000

10000

12000

0 100 200 300 400 500Days

0

500

1000

1500

2000

25003000

3500

Pum

p pr

essu

re

(psi

)

HC

Mud Aci

InjectivityInjectivity Decline Well A10Decline Well A10

0.0

0.5

1.0

1.5

2.0

2.5

3.0

3.5

0 100 200 300 400 500Time (days

10% HCltreatment

Mud acidtreatmen

Filter change from5 µm to 10 µm

Simulated

Prudhoe Prudhoe Bay Bay Water Injection ExperienceWater Injection Experience

1.2 1.2 MMbblMMbbl/day produced water and 0.85 /day produced water and 0.85 MMbblMMbbl/day of seawater injected via 159 /day of seawater injected via 159 injectors.injectors.No decline in No decline in injectivity injectivity when injecting up to when injecting up to 2000 2000 ppm ppm solids and oil.solids and oil.All injectors are fractured.All injectors are fractured.PW (150 PW (150 00F) F) frac frac gradient = 0.57gradient = 0.57-- 0.60.6SW (80 SW (80 00F) F) frac frac gradient = 0.53 gradient = 0.53 -- 0.540.54Well orientation affects Well orientation affects injectivityinjectivity..

Performance Plot for Well HPerformance Plot for Well H--09i09i(From Martins et. al., 1994)(From Martins et. al., 1994)

Effect of Well Azimuth and Deviation Effect of Well Azimuth and Deviation (From Martins et. al., 1994)(From Martins et. al., 1994)

60-9030-60

0-30

0-20

20-40

40-60

0

100

200

300

400

500

600

Incr

ease

d In

terc

ept P

ress

ure

Well Azimuth

Well Deviation

Unfavorable

Unfavorable

Wytch Farm FieldPaige and Murray(1994)

Injection Rate

Pressure

200 400

15 ppm solids

PressurebarFlow

ratebbl/day 18020,000

15,000140

10,000

1005,000

6001

Time(days)

Forties Field ExperienceForties Field Experience(1975(1975--1996)1996)

240,000 bbl of water injected in 1996.240,000 bbl of water injected in 1996.Core flow experiments indicated 90% Core flow experiments indicated 90% reduction in reduction in injectivity injectivity over 6 months.over 6 months.Removal of fine filters had no adverse Removal of fine filters had no adverse effects on effects on injectivity injectivity of sea water.of sea water.Injection of 50Injection of 50--1200 1200 ppm ppm oil and 5 to 50 oil and 5 to 50 ppm ppm solids resulted in I/Isolids resulted in I/Ioo=0.7 long term.=0.7 long term.

UlaUla, Magnus and , Magnus and Gyda Gyda FieldsFields

Removal of fine filters had no impact on Removal of fine filters had no impact on injectivityinjectivity..Hydraulic Hydraulic impedence impedence testing on 50 testing on 50 injectors showed that they were all injectors showed that they were all fractured.fractured.

Injection Well FracturingInjection Well FracturingMost water injection wells are fractured.Most water injection wells are fractured.

Injection of suspended solids and oil droplets Injection of suspended solids and oil droplets can quickly plug the formation.can quickly plug the formation.

When the BHP exceeds the When the BHP exceeds the fracfracgradient, fractures are created.gradient, fractures are created.

Thermal stresses can be important.Thermal stresses can be important.

Managing these fractures is key to Managing these fractures is key to successful water injection. successful water injection.

Effect of Injection Well FracturingEffect of Injection Well FracturingGrowing injection well fractures affect Growing injection well fractures affect reservoir sweep and oil recovery.reservoir sweep and oil recovery.

Lf

t

Existing commercial reservoir Existing commercial reservoir simulators do not handle simulators do not handle growing injection well growing injection well fractures.fractures.

Injector physics must be built Injector physics must be built into well models.into well models.

Injection Water Management Research

Combining single well models with reservoir simulators

Injection Water Management Research

Injection Well Models Core flow tests

Large block tests

Distributed Models Oily Water Injection

Injection Into Soft Sands Horizontal /MultilateralInjectors

Case Studies

We have Tracked FracturesWe have Tracked Fracturesin Simulated Injection Wellsin Simulated Injection Wells

σ1 = 2,000 psi

pp = 700 psi

σh = 1,450 psi

Pressure at Various PortsPressure at Various Ports

500

700

900

1100

1300

1500

1700

1900

2100

2300

2500

0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8

Time (hour)

Pre

ssur

e (p

si)

Pore Pressure

Wellbore Pressure

P1 P2

P4P5

Fracture initiationRed Rust acrylic particles

Injectivity Injectivity Remains ConstantRemains Constant

0

0.005

0.01

0.015

0.02

0.025

0.03

0.035

0.04

0.045

0 5 10 15 20

Injection Time (Hrs)

Inje

ctiv

ity

Lessons LearntLessons LearntInjectivity remains essentially constant (despite Injectivity remains essentially constant (despite plugging by particles).plugging by particles).The rate of fracture growth is closely related to The rate of fracture growth is closely related to particle trapping. particle trapping. Invasion depth from fracture face is shallow.Invasion depth from fracture face is shallow.Injected particles end up mostly at the fracture Injected particles end up mostly at the fracture tip except when fracture is plugged.tip except when fracture is plugged.No fracture growth when clear brine is injected.No fracture growth when clear brine is injected.

Unique Aspects of Unique Aspects of Injection Well ModelingInjection Well Modeling

Formation and fracture plugging Formation and fracture plugging Fracture propagation controlled by Fracture propagation controlled by formation and fracture pluggingformation and fracture pluggingThermal stressesThermal stressesPore pressure induced stressesPore pressure induced stressesFracture geometry evolves with timeFracture geometry evolves with timeCoupling to reservoir modelsCoupling to reservoir models

Particle PluggingParticle Plugging

Pwf Pr

Filtration EquationsFiltration Equations

0)(=++

tD

xcu

tc

∂∂

∂∂

∂φ∂ uc

tD λ∂∂

=

4.0 2.1 3 8/15 8/1 104.272.0 −−×+= RGsRLos NNANNAλ

(Rajgopalan and Tien(1976))

τφφ 11

)1(5 22

3

Sk

−=

Deposited Particles Reduce φ and k

),(),( 0 txDtx −=φφ

Thermal Stresses and Thermal Stresses and Pore Pressure EffectsPore Pressure Effects

SE1 σσ +>tipPFor Fracture propagation(Perkins & Krech (1968))

)/(1)/()1( 1

oo

ooT

abab

TE +=

∆∆−

βσν

ao

Waterflood front

Cooled front bo

PTH 11min1 )( σσσσ ∆+∆+=

Flow EquationsFlow Equations

pfsRwf PPPPPPPP ∆+∆+∆+∆+∆+∆+= 321

Thermal front

Waterflood front

∆P2 ∆P3PR ∆P1

Single Well Model Single Well Model

Single Well ModelSingle Well Model

Effect of Injected Particle ConcentrationEffect of Injected Particle Concentration(No Thermal Stresses, Swi=1)(No Thermal Stresses, Swi=1)

0.0

0.2

0.4

0.6

0.8

1.0

0 50 100 150 200

Injection Time (days)

Inje

ctiv

ity R

atio

3 ppm

10 ppm

30 ppmrwf

rwfo

PtPPP

ItIt

−

−==

)()()(

0

α

Effect of Injected Particle ConcentrationEffect of Injected Particle Concentration(No Thermal Stresses, Swi=1)(No Thermal Stresses, Swi=1)

0

3

6

9

12

15

18

0 50 100 150 200

Injection Time (days)

Frac

ture

Len

gth

(fee

t)

3 ppm10 ppm30 ppm

Fracture Pressure

BH

PTime

Initial BHP

K

Time

3 ppm10 ppm30 ppm

Injection Time (Days)Frac

ture

Len

gth

(feet

)

Anatomy of a Thermal FractureAnatomy of a Thermal Fracture((∆∆T=30 C, CT=30 C, Cinjinj=100ppm)=100ppm)

22.0

22.5

23.0

23.5

24.0

0 10 20 30 40 50

Injection Time (days)

Pres

sure

(MPa

)

BHP

sigma min.

Fracture Initiationσmin+σSE+∆Pf

Effect of Thermal StressesEffect of Thermal Stresses(q=500m(q=500m33/day, S/day, Swiwi=1)=1)

0

10

20

30

40

0.00 50.00 100.00 150.00 200.00

Injection Time (days)

Frac

ture

Len

gth

(feet

)

Delta T=0 CDelta T=40 CDelta T=50 C

Injection Time (Days)

Frac

ture

Len

gth

(feet

)

T=0 CT=25 CT=50 C

Delta T = 50 CDelta T = 25 CDelta T = 0 C

Thermal and Particle Plugging EffectsThermal and Particle Plugging Effects

0

50

100

150

200

250

0 50 100 150 200

Injection Time (days)

Frac

ture

Len

gth

(feet

) 100 ppm1000 ppm

∆T=60 CDelta t=60 C

Coupling the Injector Model Coupling the Injector Model with a Reservoir Simulatorwith a Reservoir Simulator

The fracture length from the single well The fracture length from the single well model is used to determine the grid blocks model is used to determine the grid blocks penetrated by the fracturepenetrated by the fractureFracture is considered to be infinite Fracture is considered to be infinite conducting (high permeability)conducting (high permeability)The permeability field is The permeability field is reset in the reservoir reset in the reservoir simulatorsimulator

X

Y dy

Our ApproachOur ApproachPhenomenological DecompositionPhenomenological Decomposition

Single Well Model

Flow Rate, Time Step Cumulative Injection

Average Rsvr. Pressure

Fracture LengthSkin

Damaged Permeability

Reservoir Simulator

Single Well ModelSingle Well Model

Captures near well bore physics on a Captures near well bore physics on a fine grid.fine grid.Correctly account for effects important Correctly account for effects important only in the near wellbore region.only in the near wellbore region.Single well model allows forSingle well model allows for–– Particle pluggingParticle plugging–– Growth of injection well fracturesGrowth of injection well fractures

Reservoir SimulatorReservoir SimulatorCaptures largeCaptures large--scale features such as scale features such as reservoir heterogeneityreservoir heterogeneityAccounts for the changes predicted by Accounts for the changes predicted by the single well models on the overall the single well models on the overall reservoir performancereservoir performance–– Effect of changed injectivitiesEffect of changed injectivities–– Effect of growing injection well Effect of growing injection well

fracturesfractures

Speeding up ComputationsSpeeding up ComputationsOPTIMA: A Distributed Computing ToolOPTIMA: A Distributed Computing Tool

Local Machine Server Clients

•Well file generator•Reservoir simulator•Administrative Tools

Server Program

•Client Program•Single well model

Effect of Injection Well Fracturing onEffect of Injection Well Fracturing onReservoir Sweep (A Simple Example)Reservoir Sweep (A Simple Example)

Well positions in a five spot patternWell positions in a five spot pattern

No flow boundariesNo flow boundaries

Compare oil recovery Compare oil recovery fractured casesfractured cases

unfractured cases

Lf

tunfractured cases

ConfigurationConfiguration II

Fracture grows towards the producing wells

Unfractured Case(Without Single Well Model)

Fractured Case (With Single Well Model)

Effect of Fracture LengthEffect of Fracture LengthInjector Producer Spacing=500 ft

-20

-15

-10

-5

0

5

0 100 200 300 400 500

Fracture Length after 1000 days

% C

hang

e in

Oil

Rec

over

y

Configuration Configuration IIII

Fracture is oriented away from the wells

Unfractured Case

Fractured Case

Effect of Fracture LengthEffect of Fracture LengthInjector Producer Spacing=500 ft

0

1

2

3

4

5

0 100 200 300 400 500

Fracture Length after 1000 days

% C

hang

e in

Oil

Rec

over

y

Effect of HeterogeneityEffect of Heterogeneity

In homogeneous formations

the fracture lags behind the

waterflood front

Effect of HeterogeneityEffect of Heterogeneity

In low permeability layers, In low permeability layers, the fracture may overtake the fracture may overtake the flood frontthe flood frontMore oil is bypassed in the More oil is bypassed in the low permeability layerslow permeability layers

500 md

10 md

Effect of HeterogeneityEffect of HeterogeneityInjector Producer Spacing=500 feet

-35

-30

-25

-20

-15

-10

-5

0

5

0 100 200 300 400 500

Fracture Length after 1000 days (feet)

% C

hang

e in

Oil

Rec

over

y

HomogeneousHeterogeneous

Injection into multiple zones can Injection into multiple zones can lead to complex injection and lead to complex injection and

sweep patterns.sweep patterns.

σhmin1 = 4.3 MPa, h1 = 5m σhmin2 = 4.8 MPa , h2 = 10m

Layer 1 Takes All the WaterLayer 1 Takes All the WaterNot What we had in MindNot What we had in Mind

Injection Time (Days)

Frac

tion

of F

low

Fracture Propagates in Layer 1Fracture Propagates in Layer 1

Injection Time (Days)

Frac

ture

Len

gth

(fee

t)

Injection into Multiple ZonesInjection into Multiple ZonesChallenges / OpportunitiesChallenges / Opportunities

Single Single vs vs multiple injection strings.multiple injection strings.Conduct cost benefit analysis for flow Conduct cost benefit analysis for flow control devices.control devices.Run models to understand the Run models to understand the possibility of plugging and fracturing of possibility of plugging and fracturing of different zones.different zones.This strategy can offer flexibility and This strategy can offer flexibility and control over where the water goes.control over where the water goes.

Effect of Fracturing Effect of Fracturing Horizontal Injectors Horizontal Injectors

100 m Water Column

Oil Column

Injector

Producer

500-1000 m Spacing

Oil Water Contact

Effect of Injection Well Effect of Injection Well Fracturing on Oil RecoveryFracturing on Oil Recovery

Producer

Injector

Growing Injection Well Fracture

Bypassed Regions

of the Reservoir

Waterflood Front

500-1000 m

Injecting into Poorly Consolidated Injecting into Poorly Consolidated Formations: Some Unique ChallengesFormations: Some Unique Challenges

Completion decisions are more complicated.Completion decisions are more complicated.Injection water plugs off sand control devices Injection water plugs off sand control devices (gravel packs, screens).(gravel packs, screens).Sudden changes in injection pressures can Sudden changes in injection pressures can cause sand failure.cause sand failure.Injectors fill up with sand if no sand control is Injectors fill up with sand if no sand control is in place.in place.Fracturing is not easily detected and is hard Fracturing is not easily detected and is hard to model.to model.Fracture containment issues.Fracture containment issues.

Injecting into Poorly Consolidated Injecting into Poorly Consolidated Formations: OpportunitiesFormations: Opportunities

Large solids storage capacity in diffuse Large solids storage capacity in diffuse fractures.fractures.Good candidates for waste injection (drill Good candidates for waste injection (drill solids, oilfield and refinery waste).solids, oilfield and refinery waste).An excellent alternative for waste An excellent alternative for waste disposal, if implemented properly.disposal, if implemented properly.

σHminσHmin

ConclusionsConclusionsSubsurface injection of produced water is Subsurface injection of produced water is becoming the disposal method of choice.becoming the disposal method of choice.Better management of injection water can have Better management of injection water can have a large impact on oil & gas production a large impact on oil & gas production economics. economics. Water quality / treatment facility design Water quality / treatment facility design decisions are critical and must be carefully decisions are critical and must be carefully made on a case by case basis.made on a case by case basis.Subsurface separation is thus far turning out to Subsurface separation is thus far turning out to be of limited applicability.be of limited applicability.SubSub--sea separation and injection presents sea separation and injection presents both tremendous opportunities and challenges.both tremendous opportunities and challenges.

ConclusionsConclusionsIn fractured injectors the In fractured injectors the injectivity injectivity decline decline depends very little on water quality. Not so in depends very little on water quality. Not so in unfractured injectors.unfractured injectors.The combination of fracture plugging, thermal The combination of fracture plugging, thermal stresses, phase stresses, phase mobilities mobilities and heterogeneities can and heterogeneities can give rise to complicatedgive rise to complicated injectivityinjectivity behavior.behavior.

Growing injection well fractures can have an Growing injection well fractures can have an important effect on reservoir sweep.important effect on reservoir sweep.

Simulation tools should be used to aid in facilities Simulation tools should be used to aid in facilities and completion design and in selecting injection and completion design and in selecting injection patterns to maximize oil recovery.patterns to maximize oil recovery.

CoCo--Workers, CollaboratorsWorkers, Collaborators

Lee Lee MorganthalerMorganthalerBill LandrumBill LandrumKris Kris BansalBansalNick Paris

Phani Phani B. B. GaddeGaddeMingjiao Mingjiao YuYuErik Erik WennbergWennbergShutang Shutang Pang Nick ParisPang

For further details, my contact: msharma@mail.utexas.edu

AcknowledgementAcknowledgement

SPE Foundation for funding this trip.SPE Foundation for funding this trip.This work was made possible by This work was made possible by companies supporting the Injection companies supporting the Injection Water Management JIP: BHP, Water Management JIP: BHP, ChevronTexacoChevronTexaco, , ConocoConoco, Shell, TF, Shell, TF--Elf, Elf, PetrobrasPetrobras..The State of Texas ATP program.The State of Texas ATP program.

OPTIMA Administrative ToolsOPTIMA Administrative Tools

• Allow the user to submit jobs and communicate with the server

• Provide application life-cycle control

• Provide the user with status of the various processes

Test SpecificationsTest SpecificationsClientsClients

–– 15 Identical IBM PCs15 Identical IBM PCs–– 667 MHz, Intel P667 MHz, Intel P--III ProcessorsIII Processors–– 256 MB RAM256 MB RAM

ServerServer–– 800 MHz, Intel P800 MHz, Intel P--III ProcessorIII Processor–– 256 MB RAM256 MB RAM–– 10 Mbps Network Card10 Mbps Network Card

Data Transfer per run:Data Transfer per run: 7 MB7 MB

OPTIMA Status FrameOPTIMA Status FrameJob Path on

Local MachineUnique ID assigned

by server Result File Name on

Local machine

Client Port

Client IP addresses

Job Status

Processing Times for 5Processing Times for 5--minute Jobsminute Jobs

0

50

100

150

200

0 100 200 300 400Number of Jobs

Tim

e (m

in)

15 CPUs10 CPUs1 CPU

Run Times Per Job (5Run Times Per Job (5--minute Jobs)minute Jobs)

0.1

1

10

0 5 10 15Number of CPUs

Tim

e (m

in)

Opportunities and ChallengesOpportunities and ChallengesChallengesChallenges

Design water handling and injection systems to Design water handling and injection systems to reduce the cost of water injection. reduce the cost of water injection. –– Specify injection water quality, rates & pressuresSpecify injection water quality, rates & pressures–– Subsurface separation?Subsurface separation?–– Subsea vs Subsea vs topsidestopsides

The single well model can be used to address The single well model can be used to address these challenges.these challenges.

OpportunitiesOpportunitiesSignificant improvements in oil recovery.Significant improvements in oil recovery.Cost reductions to improve production Cost reductions to improve production economics.economics.

A Real OpportunityA Real Opportunity

Using Injection Well Fractures Using Injection Well Fractures to Maximize Oil Recovery to Maximize Oil Recovery

Coupling Single Well Models with Coupling Single Well Models with a Reservoir Simulatora Reservoir Simulator

University of Texas at Austin

Traditional Domain DecompositionTraditional Domain Decomposition

Domain decomposition involvesDomain decomposition involves–– Breaking the reservoir into domainsBreaking the reservoir into domains–– Large volumes of data is exchanged between Large volumes of data is exchanged between

domains (unsuitable for distributed computing)domains (unsuitable for distributed computing)

Phenomenological DecompositionPhenomenological Decomposition

Decomposition based on problem physicsDecomposition based on problem physics–– Single Well ModelsSingle Well Models

–– Reservoir Simulation ModelsReservoir Simulation ModelsSingle Well

Models

Reservoir Simulation

Models

Injectivity Remains ConstantInjectivity Remains Constant

0

0.01

0.02

0.03

0.04

26 28 30 32 34 36

Injection Time (Hrs)

Inje

ctiv

ity

Which is more expensive to purchase: Which is more expensive to purchase: drinking water or crude oil?drinking water or crude oil?

Crude Oil

$28

Gasoline

$54

Bottled Water

$189

Ice Cream

$1100

Coca Cola

$79Milk

$150

TabascoSauce

$2660

Flonase

$615,240