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INTRODUCTION TO WELL PERFORMANCE
& ARTIFICIAL LIFT
November 2001
by Russ Gilbert & Justin Gilmour
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= $$$$$
the well
What is a well?Why is it important ?
WHY BOTHER WITH WELL PERFORMANCE ?
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• Basic Well Configuration
• Reservoir Inflow Performance
• Tubing Outflow Performance
• Improving Well Performance
INTRODUCTION TO WELL PERFORMANCE
CONCEPTS COVERED
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BASIC WELL CONFIGURATIONXMAS TREE
Hydrocarbon Flow
CASING
TUBING OUFLOW
PERFORATIONS
RESERVOIR
RESERVOIR INFLOW
Gas Export
Oil Export= $$$$
Separator
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RESERVOIR INFLOW
oil rate
PRESSURE DROP
Reservoir pressure(Pres)
Inflow Performance Principle:
Pre
ssu
re
As pressure drop increases rate increases!
Can we model this principle?
pres
sure
BHP
Pres
ΔP ΔP
Wellbore Damage (Skin)
BHPBottomhole pressure
(BHP)
Higher Pressure(Driving Force)
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RESERVOIR INFLOWMathematical Model
Flow Rate (Q) varies with: - Inflow Pressure Drop? (ΔP)- Thickness of the Reservoir? (h)- Permeability of the Reservoir Sand? (k)- Phase of the Moon? (x)- Skin Damage around the Well? (S)- Reservoir Pressure? (Pres)- Fluid Viscosity? (µ)- Hours of Sunshine? (y)- Wellbore Radius (rw)
pres
sure
BHP
Pres
ΔP
BHP
ΔP
Q = f ?
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RESERVOIR INFLOWMathematical Model
Various inflow equations are used to model reservoir inflow in software such as Prosper
Flow Rate (Q) varies with: - Inflow Pressure Drop? (ΔP)- Thickness of the Reservoir? (h)- Permeability of the Reservoir Sand? (k)- Phase of the Moon? (x)- Skin Damage around the Well? (S)- Reservoir Pressure? (Pres)- Fluid Viscosity? (µ)- Hours of Sunshine? (y)- Wellbore Radius (rw)
pres
sure
BHP
Pres
ΔP
BHP
ΔP
Q = fK h ΔP rw
µ S
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TUBING OUTFLOW
Tubing Performance Principle:
pres
sure
oil rate
PRESSURE LOSS
Higher Pressure(Driving Force)
Lower Pressure
BHP
WHP
As rate increases pressure loss increases!
Can we model this principle?
Bottomhole pressure(BHP)
Well Head pressure(WHP)
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TUBING OUTFLOW
BHP
WHP
Mathematical Model
Flow Rate (Q) varies with: - Fluid Weight/Type? (ρ)- Friction Losses - Fluid Viscosity? (μ)- Friction Losses - Tubing Length? (L)- Phase of the Moon? (x)- Friction Losses - Tubing diameter ? (d)- Friction Losses - Tubing roughness ? (f)- Hours of Sunshine? (y)- Well Head Pressure? (WHP)
Q = f ?
Note: The acceleration term (velocity increasing due to gas expansion) has been assumed to be negligible for this presentation.
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TUBING OUTFLOW
BHP
WHP
Mathematical Model
Flow Rate (Q) varies with: - Fluid Weight/Type? (ρ)- Friction Losses - Fluid Viscosity? (μ)- Friction Losses - Tubing Length? (L)- Phase of the Moon? (x)- Friction Losses - Tubing diameter ? (d)- Friction Losses - Tubing roughness ? (f)- Hours of Sunshine? (y)- Well Head Pressure? (WHP)
Various correlations are used to model tubing outflow in software such as Prosper
Q = f1
Fluid Weight . Friction Losses . Wellhead Pressure
Note: The acceleration term (velocity increasing due to gas expansion) has been assumed to be negligible for this presentation.
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TUBING OUTFLOWFluid Weight/Type
0 5000 10000 15000 200000
1000
2000
3000
4000
5000
6000
VLP (TUBING) CURVES ( 20 Nov 01 16:11)
Liquid Rate (STB/day)
Pre
ssur
e (
psig
)
FluidOilFlow TubingTypeProducer
Lift NoneCompCased HoleCorrlnHagedorn Brown
Bottom Measured Depth 10000.0(feet)Bottom True Vertical Depth 10000.0(feet)
Variables1:Water Cut (percent)2:First Node Pressure (psig)3:Tubing/Pipe Diameter (inches)
1 2 30=0 0=50.0 0=1.99
1=50.000 1=200.0 1=2.752=90.000 2=400.0 2=3.83
3=4.89
002
102
202
Mixture
All Wtr
50/50
All Oil
Tubing Length=10,000ft; Tubing Diameter=4 1/2”OD;WHP=50psig
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TUBING OUTFLOWFriction Losses
Tubing Length=10,000ft; All Oil; WHP=50psig
0 5000 10000 15000 200000
1000
2000
3000
4000
5000
6000
VLP (TUBING) CURVES ( 20 Nov 01 16:11)
Liquid Rate (STB/day)
Pre
ssur
e (
psig
)
FluidOilFlow TubingTypeProducer
Lift NoneCompCased HoleCorrlnHagedorn Brown
Bottom Measured Depth 10000.0(feet)Bottom True Vertical Depth 10000.0(feet)
Variables1:Water Cut (percent)2:First Node Pressure (psig)3:Tubing/Pipe Diameter (inches)
1 2 30=0 0=50.0 0=1.99
1=50.000 1=200.0 1=2.752=90.000 2=400.0 2=3.83
3=4.89
000
001
002
003
Tubing OD
2 3/8”
4 1/2”
5 1/2”
3 1/2”
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TUBING OUTFLOWWell Head Pressure
0 5000 10000 15000 200000
1000
2000
3000
4000
5000
6000
VLP (TUBING) CURVES ( 20 Nov 01 16:11)
Liquid Rate (STB/day)
Pre
ssur
e (
psig
)
FluidOilFlow TubingTypeProducer
Lift NoneCompCased HoleCorrlnHagedorn Brown
Bottom Measured Depth 10000.0(feet)Bottom True Vertical Depth 10000.0(feet)
Variables1:Water Cut (percent)2:First Node Pressure (psig)3:Tubing/Pipe Diameter (inches)
1 2 30=0 0=50.0 0=1.99
1=50.000 1=200.0 1=2.752=90.000 2=400.0 2=3.83
3=4.89
002
012
022
Tubing Length=10,000ft; All Oil; Tubing Diameter=4 1/2”
Well Head Pressure
400 psig
200 psig
50 psig
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THE OIL RATE
Determined for specific fluid, specific tubing & specific reservoir by intersection of the reservoir inflow & tubing outflow curves
oil rate
pres
sure
from tubing outflow
surface pressure - WHP
from reservoir inflow
reservoir pressure - Pres
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THE OIL RATE
0 5000 10000 15000 200000
1000
2000
3000
4000
5000
6000
Inflow v Outflow Curves ( 20 Nov 01 17:04)
Liquid Rate (STB/day)
Pre
ssur
e (
psig
)
FluidOilFlow TubingTypeProducer
Lift NoneCompCased HoleCorrlnHagedorn Brown
First Node Pressure 50.0(psig)Bottom Measured Depth 10000.0(feet)
Bottom True Vertical Depth 10000.0(feet)
IPR PI EntryRes Temp200.0 (degrees F)Res Pres 3000.0 (psig)
Variables1:Reservoir Pressure (psig)
1 2 30=3000.01=4000.02=5000.0
2
2
IPR Curve
VLP Curve
Tubing Length=10,000ft; All Oil; Tubing Diameter=4 1/2”; WHP=50psig, Pres=5000psig, k.h=10000mdft, rw=8.5”, Wellbore Skin=5
Reservoir Pressure
5000 psig
Initial Conditions
6500 bopd
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THE OIL RATEPressure Depletion
0 5000 10000 15000 200000
1000
2000
3000
4000
5000
6000
Inflow v Outflow Curves ( 20 Nov 01 17:04)
Liquid Rate (STB/day)
Pre
ssur
e (
psig
)
FluidOilFlow TubingTypeProducer
Lift NoneCompCased HoleCorrlnHagedorn Brown
First Node Pressure 50.0(psig)Bottom Measured Depth 10000.0(feet)
Bottom True Vertical Depth 10000.0(feet)
IPR PI EntryRes Temp200.0 (degrees F)Res Pres 3000.0 (psig)
Variables1:Reservoir Pressure (psig)
1 2 30=3000.01=4000.02=5000.0
0
0
1
1
2
2
IPR Curve
VLP CurveReservoir Pressure
5000 psig
4000 psig
3000 psig
6500 bopd2500 bopd
Tubing Length=10,000ft; All Oil; Tubing Diameter=4 1/2”; WHP=50psig, Pres=depleting, k.h=10000mdft, rw=8.5”, Wellbore Skin=5
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THE OIL RATEPressure Depletion & %Water Increase
Tubing Length=10,000ft; %wtr increasing; Tubing Diameter=4 1/2”; WHP=50psig, Pres=depleting, k.h=10000mdft, rw=8.5”, Wellbore Skin=5
0 5000 10000 15000 200000
1000
2000
3000
4000
5000
6000
Inflow v Outflow Curves ( 20 Nov 01 17:04)
Liquid Rate (STB/day)
Pre
ssur
e (
psig
)
FluidOilFlow TubingTypeProducer
Lift NoneCompCased HoleCorrlnHagedorn Brown
First Node Pressure 50.0(psig)Bottom Measured Depth 10000.0(feet)
Bottom True Vertical Depth 10000.0(feet)
IPR PI EntryRes Temp200.0 (degrees F)Res Pres 3000.0 (psig)
Variables1:Reservoir Pressure (psig)
1 2 30=3000.01=4000.02=5000.0
0
0
1
1
2
2
IPR Curve
VLP CurveReservoir Pressure
5000 psig
4000 psig
3000 psig
%Water
100%
50% (Now)
0%Now 4500 psig
3000 bfpd
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THE OIL RATEPressure Depletion & %Water Increase
What can we do to stop oil rate falling ?
Was 6,500 bopd, now 1500 bopd
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IMPROVING WELL PERFORMANCE
pres
sure
Oil rate can be increased by:• Shifting reservoir inflow up • Shifting tubing outflow curve down
oil rate
Tubing outflow
surface pressure - WHP
Reservoir inflow)
reservoir pressure - Pres
How Do You Do That Then ?
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IMPROVING WELL PERFORMANCEShifting Reservoir Inflow Curve Up - How To
Q = fK h ΔP rw
µ S
Increase
Decrease
Increase: Kh, ΔP rw Decrease: µ S
IncreaseReservoirPressure
Re-Perf.,Acidise,Fracture,Dissolve
Heat-UpFracture,Horizontal
Well
DrillBiggerHole
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IMPROVING WELL PERFORMANCEShifting Tubing Outflow Curve Down - How To
Q = f1
Fluid Weight . Friction Losses . Wellhead Pressure
Reduce: Fluid Weight, Friction Losses, Wellhead Pressure
Isolate WtrProdn orAdd gas
via gas lift(aka artificial lift)
BiggerTubing
LowerSeparatorPressure
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No Action:Rate = 3000bfpd
Well Will Die Soon
0 5000 10000 15000 200000
1000
2000
3000
4000
5000
6000
Inflow v Outflow Curves ( 20 Nov 01 17:04)
Liquid Rate (STB/day)
Pre
ssur
e (
psig
)
FluidOilFlow TubingTypeProducer
Lift NoneCompCased HoleCorrlnHagedorn Brown
First Node Pressure 50.0(psig)Bottom Measured Depth 10000.0(feet)
Bottom True Vertical Depth 10000.0(feet)
IPR PI EntryRes Temp200.0 (degrees F)Res Pres 3000.0 (psig)
Variables1:Reservoir Pressure (psig)
1 2 30=3000.01=4000.02=5000.0
0
0
1
1
2
2
IPR Curve
VLP CurveP res
5000 psig
4000 psig
3000 psig
%Water
100%
50%
0%
Shifting Reservoir Inflow Curve UpIMPROVING WELL PERFORMANCE
Increase: Kh, ΔP rw Decrease: µ S
IncreaseReservoirPressure
Re-Perf.,Acidise,Fracture,Dissolve
Heat-UpFracture,Horizontal
Well
DrillBiggerHole
Actions: (1) N/A N/A Later Re-perf N/A
4000 bfpd
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0 5000 10000 15000 200000
1000
2000
3000
4000
5000
6000
Inflow v Outflow Curves ( 20 Nov 01 17:04)
Liquid Rate (STB/day)
Pre
ssur
e (
psig
)
FluidOilFlow TubingTypeProducer
Lift NoneCompCased HoleCorrlnHagedorn Brown
First Node Pressure 50.0(psig)Bottom Measured Depth 10000.0(feet)
Bottom True Vertical Depth 10000.0(feet)
IPR PI EntryRes Temp200.0 (degrees F)Res Pres 3000.0 (psig)
Variables1:Reservoir Pressure (psig)
1 2 30=3000.01=4000.02=5000.0
0
0
1
1
2
2
IPR Curve
VLP CurveP res
5000 psig
4000 psig
3000 psig
%Water
100%
50%
0%
50% +G/L
Shifting Tubing Outflow Curve Down
No Further Action:Rate = 4000bfpd
Well Will Still Die Soon
IMPROVING WELL PERFORMANCE
Reduce: Fluid Weight, Friction Losses, Wellhead Pressure
Isolate WtrProdn,
Add gasvia gas lift
BiggerTubing
LowerSeparatorPressure
Actions: (2) Add G/L N/A N/A
7500 bfpd
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Shifting Reservoir Inflow Curve Up
No Further Action:Rate = 7500bfpd
Well Will Still Die, But Later
0 5000 10000 15000 200000
1000
2000
3000
4000
5000
6000
Inflow v Outflow Curves ( 20 Nov 01 17:04)
Liquid Rate (STB/day)
Pre
ssur
e (
psig
)
FluidOilFlow TubingTypeProducer
Lift NoneCompCased HoleCorrlnHagedorn Brown
First Node Pressure 50.0(psig)Bottom Measured Depth 10000.0(feet)
Bottom True Vertical Depth 10000.0(feet)
IPR PI EntryRes Temp200.0 (degrees F)Res Pres 3000.0 (psig)
Variables1:Reservoir Pressure (psig)
1 2 30=3000.01=4000.02=5000.0
0
0
1
1
2
2
IPR Curve
VLP CurveP res
5000 psig
4000 psig
3000 psig
%Water
100%
50%
0%
50% +G/L
IMPROVING WELL PERFORMANCE
Increase: Kh, ΔP rw Decrease: µ S
IncreaseReservoirPressure
Re-Perf.,Acidise,Fracture,Dissolve
Heat-UpFracture,Horizontal
Well
DrillBiggerHole
Actions: (3) N/A N/A Wtr Injector N/A N/A
10000 bfpd
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IMPROVING WELL PERFORMANCE
Actions to improve well performancehave almost returned oil rate to initial condition
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SUMMARY• Basic Well Configuration
• Reservoir Inflow Performance
• Tubing Outflow Performance
• Improving Well Performance
Q = f K h ΔP rw
µ S
Q =f1
Fluid Weight . Friction Losses . Wellhead Pressure
Shifting Reservoir Inflow Curve Up
Shifting Tubing Outflow Curve Down