Primary funding is provided by The SPE Foundation through member donations
The SPE Foundation through member donations … Primary funding is provided by The SPE Foundation...
Transcript of The SPE Foundation through member donations … Primary funding is provided by The SPE Foundation...
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Primary funding is provided by
The SPE Foundation through member donations and a contribution from Offshore Europe
The Society is grateful to those companies that allow their professionals to serve as lecturers
Additional support provided by AIME
Society of Petroleum Engineers Distinguished Lecturer Programwww.spe.org/dl 1
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Society of Petroleum Engineers Distinguished Lecturer Programwww.spe.org/dl
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Improved Oil & Gas Recovery byPolymer Technology: EOR, Water
Shutoff and Sand Control
Alain ZaitounPoweltec, France
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Outline
1. EOR Challenges
2. Polymer Flooding
General aspectsField case in heavy oil reservoir
3. Water Shut-Off
Fundamentals of WSO by RPMs
WSO gas well field case
4. Sand Control
Principle of sand control by polymers
Sand control in gas storage wells
5. Conclusions
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EOR Challenges
• Peak oil occurring soon, oil slow decline expected
• EOR enables increase in Recovery Factor
• Teams mobilized in Major Oil companies
to implement EOR
• Chemical EOR attractive, major focus on polymers
• Low capital cost, low risk, waterflood improvement
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Malaysia Scenario
• Increasing domesticconsumption
• Forecasted decline from 2007• Net crude importer by ~2010 ?
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EOR by Polymers
Polymer Flood improves Mobility Control, thus reservoir sweep efficiency
Water flooding Polymer flooding
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Polymer Flood:
Heavy-Oil Application (Canada)
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Pelican Lake heavy oil field
• High-permeability sand reservoir
• Thin continuous pay layer (4 m thick)
• Heavy oil – 14°°°° API – 2000 cP
• Shallow, low temperature, fresh water
• Horizontal well primary production
• Low recovery factor (around 5%)
• RF expected to jump to 25% with polymer flood
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Pelican Lake Polymer Flood Pilot
200 m
1400 m
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Oil rate in Central Producer 00-15-PROMax Injection & Production Rates 150 m3/d
0
5
10
15
20
25
30
35
40
45
1/1/97 1/1/01 1/1/05 1/1/09 1/1/13 1/1/17
Date
Oil r
ate
(m
3/d
)
Water injection
1000 ppm (12 months) then water
1000 ppm (9m) 500 ppm (6m) water
1000 ppm (6m) 500 ppm (12m) water
1000 ppm (3m) 500 ppm (18m) water
1000 ppm (3m) water
Simulation of Polymer Injection Scenarios
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Main outcomes of Polymer Flood pilot
• Polymer Flood has potential in heavy-oil reservoir
• In combination with Horizontal Wells
• Integrated Lab & Simulation studies help designing pilot
• Polymer injectivity is an essential issue
• First pilot results very positive, field extension
implemented by operator (270 injection wells in 2009)
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Water Shutoff
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Water Shutoff by Polymer/Gels
• Two strategies: (1) Sealing gels and (2) RPM
• Sealing gels block a water producing interval
• Sealing gels compete with cements or packers
• Relative Permeability Modifiers are weak polymer/gels
• Usually “bullhead” injected into the whole open interval =
cost effective
• Maintain oil/gas permeability while reducing strongly water
permeability
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Principle of WSO by RPM Polymers
W
Oil Oil
Water
Oil Oil
Water Water Water
WaterOil
Oil
Water
Low k
High K
Two-layer model
Swollen orweakly
X-linked polymer
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Modification of Relative Permeabilityby Polymer Adsorption
((SorSor))
((SwiSwi))
Adsorbed polymer or microgels
before polymer
after polymer
RRF=10
Principle of RPM treatments
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Example of successfull WSO treatmentPelican Lake Horizontal Well 11-15A (Canada)
100
500
1000
juil-
85
avr-
88ju
in-8
8
oct-8
8
avr-
89ju
in-8
9
oct-8
9
avr-
90ju
in-9
0
oct-9
0
avr-
91ju
in-9
1
0 %
10 %
50 %
100 %Water
Oil
Water Cut
Year 1 Year 2 Year 3 Year 4
Mo
nth
lyP
rod
uc
tio
n (
m3)
Treatment
0
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Successful WSO treatment in horizontal well (Canada)
0
1000
2000
3000
4000
5000
6000
7000
0 1000 2000 3000 4000 5000 6000
Cumulated Water Production (m3)
Sandcleaning
Incrementaloil
RPM treatment
Cu
mu
late
dO
ilP
rod
ucti
on
(m
3)
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New Microgel Technology
dH ≈≈≈≈ 0.3 µµµµm
Small microgelMicrogel A Microgel B
Linear chain
Linear polymer
SMG are calibrated microgels larger and more stable than
conventional polymers
dH ≈≈≈≈ 2.0 µµµµm
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Several Microgel products proposed today
• “Brightwater” (Popping microgel)
• “Colloidal Dispersion Gels” (CDG)
• “SMG” (Small calibrated microgels)
• “PPG” (Preformed Particle Gels to plug thief zones)
• More used for Conformance Injection well treatments
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Example of integrated study:
Water Shutoff in a
Gas storage well
Cerville (GDF)
(SPE 106042)
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Grès à Voltzia
Restriction de perméabilitéAquifère
VA36
Model construction
Well
Reservoir
Low k
Aquifer
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Simulation forecasts
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252001_2002 2002_2003 2003_2004 2004_2005 2005_2006
Effect of Microgel WSO treatment on gas wellDrop in water production
Wa
ter
Ga
s R
atio
Wa
ter
Ga
s R
atio
Microgel Treatment
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000E+00
05E+06
10E+06
15E+06
20E+06
25E+06
2001-
2002
2002
-200
3
2003-
2004
2004
-200
5
2005
-200
6
well #0
well #1
well #2
well #3
well #4
well #5
Increase in Gas Production rate
2001/02 2002/03 2003/04 2004/05 2005/06
microgel treatment
Wells
Effect of Microgel WSO treatment on gas well
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Sand Control by Polymers
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Principle of action:
Stabilization of rock cement by "coating" with adsorbed
polymer/microgel layer
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Chemical sand consolidation
• Two types of products; (1) Oil-based, (2) Water based
• Oil-based product: resins and organo-silanes
• Resins form hard solid compounds
• Formulations have to re-establish oil/gas permeability
• Water-based polymers are environmentally friendly
• Lower consistency than resins, deeper penetration
• Low costs compared to sand control completions
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Advantages of water-based RPM polymer products
• Treatment has little impact on oil or gas permeability
• Thus, can be injected into existing completion with no
risk of well plugging
• Deeper penetration possible than with resins or cement,
also much thicker intervals
• Environmentally friendly
water based RPM products
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Sand monitoring device
MicrogelMicrogel treatmenttreatment: : effecteffect on on sandsand productionproduction
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Effect of Microgel Treatment on Sand Production
Sand production Sand production beforebefore treatmenttreatment
Sand production Sand production afterafter treatmenttreatment
Qgas
san
d(u
.a.)
Qgas
san
d(u
.a.)
Sand impacts at wellhead
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Conclusions
• Polymer Technology has great potential
• Easier and cheaper than other IOR methods
• Both EOR (reservoir) & WSO/Sand Control
(near-wellbore) applications
• New products available (microgels)
• Environmentally friendly (water based)
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Conclusions (II)
• Broadening field of applications: Sand Control &
EOR in Heavy Oil fields
• New products in WSO and Conformance, more
stable than conventional polymers (microgels)
• Lab/Simulations integrated studies improve
process control & success rate