6a-flow-control-devices-equalizer-tm-for-promoting-conformance-in-sagd-well-pairs.pdf
TRANSCRIPT
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
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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
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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
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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
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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
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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?
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