6a-flow-control-devices-equalizer-tm-for-promoting-conformance-in-sagd-well-pairs.pdf
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EQUALIZER™ Applications in a Steam
Assisted Gravity Drainage Environment
Petroleum Technology Alliance of Canada (PTAC)
Oilsands Forum: Increasing Production, Reducing Costs, and Improving Market Access
Sudiptya Banerjee
Gonzalo Garcia
Tarik Abdelfattah
Baker Hughes
Reservoir & Fluid Optimization Group
Calgary, AB, Canada
November 20th, 2012
The Cost of Uneven Production Profiles
2
3
• Before ICD, each permeability zone provides
a different pressure drop to reservoir fluid
• Each segment of the well has a different
frictional pressure drop
• Production profile is not even
The Resistor Analogy:
How ICDs Work in the Well
• A new source of pressure drop is added to
each possible pathway
• Now, fluid sees the same resistance
regardless of path (35,000)
14840 15040 710 5722
4
Influx Equalization Technique
• Evenly production
• Downhole Water and Gas Control
• Optimum pressure drop distribution
• Well completion fit to the reservoir need
•Improve well performance
•Improve reservoir performance
•Understand reservoir behavior
5
Passive Inflow Control Device: Market Overview
• Helical Type (BAKER EQUALIZER HELIX ™): big flow area, low velocity, strongly viscosity dependent above 10 cp. Not Adjustable
• Tube Type (HAL): small flow area, high velocity, partially viscosity insensitive. Adjustable
• Orifice Type (WFT, SLB, FLOTECH): small flow area, high velocity, viscosity insensitive up to 20-25 cp. Adjustable
• Hybrid Type (BAKER EQUALIZER™ MAZE™): big flow area, low velocity, highly viscosity insensitive up to 60 cp. Not Adjustable
• New Hybrid Type (BAKER EQUALIZER™ Select ™): big flow area, low velocity, highly viscosity insensitive up to at least 300 cp. Adjustable
Gas, Oil & Water Flow Performance Characteristic
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1
10
100
1000
10000
1 10 100 1000 10000 100000 1000000 10000000
Pre
ssu
re L
oss C
oeff
icie
nt
-K
Reynolds Number
K vs. Reynolds NumberBaker EQ Helix 1.6FRR Tests, Pi = 100 bar, Ti = 62 °C
O&G, 12cpsOil, GVF=0-1, DP=3bar
O&G, 12cpsOil, GVF=0-1, DP=5bar
O&G, 12cpsOil, GVF=0-1, DP=10bar
O&W, 12cpsOil, WC=0-1, DP=3bar
O&W, 12cpsOil, WC=0-1, DP=5bar
O&W, 12cpsOil, WC=0-1, DP=10bar
12cps Oil
Gas, 0.58 SG
Water, 1.01SG
50cps Oil
14421
1
1442
1442
2
2
2
2
2
c
lliq
liq
c
liq
lliq
c
liq
lliq
gAq
pK
Ag
qKp
g
vKp
7
Steam Flashing in Producer PICD
m ° m ° m ° m °
© 2009 Baker Hughes Incorporated. All Rights Reserved.
EQUALIZERTM Case Study
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Reservoir Sector Model:
Porosity and Permeability Distribution
Influx Equalization Applied to SAGD
10
Steam Injection
Bitumen Production
109,000
109,000
5,507
12,000
Slotted Liner
Equalizers
Date
Date Date
Date
Cum
ula
tive
Ste
am
In
jectio
n (
Sm
3)
Cum
ula
tive
Oil
pro
du
ctio
n (
Sm
3)
C
um
ula
tive
Oil
pro
du
ctio
n (
Sm
3)
Cu
mu
lative
Ste
am
In
jectio
n (
Sm
3)
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0
2000
4000
6000
8000
10000
12000
14000
16000
6/18/2011 8/7/2011 9/26/2011 11/15/2011 1/4/2012 2/23/2012 4/13/2012 6/2/2012 7/22/2012
Cu
m O
il P
rod
uce
d (
Sm3
)
Date
SAGD Well Completion Effects on the Reservoir Behavior
Prod (Scr) - Inj (ESel0.8_every80fT)
Prod (Scr) - Inj (Scr_every80fT)
Prod (Sel6.4) - Inj (ESel0.8_every80fT)
Slotted liner completion
Injector with Equalizer
Equalizers in Injector and
Producer
Well Completion Effects on Reservoir Behavior
Case Study – SPE 153706
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Bitumen Production
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Cumulative Steam-Oil-Ratio (CSOR)
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EQUALIZER for SAGD
• Benefits for using EQUALIZER for steam injectors
– Smaller diameter wellbore required
– Promotes uniform steam chamber growth
– By diverting steam, less steam needs to be injected
– No monitoring costs?
• Benefits for using EQUALIZER for oil producers
– Smaller diameter wellbore
– Helps prevent and manage steam breakthrough
– Prevents water production in the presence of an aquifer
– Superior sand control compared to slotted liner
– Increased oil production/ultimate recovery
• Field Benefits for using EQUALIZER in a SAGD pair
– Longer wells mean fewer wells per field! 15
Questions?
16
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