WATER INJ / TREATMENT FOR TIGHT OIL EOR
SHONN ARNDT, CNRL EXPLOITATION ENGINEER
DEECEMBER 10, 2014
CALGARY, AB, CANADA
2014-03-16, 4:20 PMbigmap.png 1,059×581 pixels
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I look forward to receiving your Dinner responses and presentations soon. Please let me know if you have any queries and I will be more than
happy to assist.
Mike Skwara
Ordos Basin

Permeability
EOR Choices for LTO
Enhanced(Water(Flood(
• Cyclic(
• Advanced(
Gas(Injec8on(
• N2(or(CO2(misc(
• HC((WAG)(
• Air(Injec8on(
Biochemical(
• MEOR(
• Enzyme(Flooding(
Thermal(
• Steam(Injec8on(
Low(
(
Tight( Low( Moderate( High(
0.1( 1( 10( 100(
Water(Flood(
Chemical(
Gas(Injec8on(
Biochemical(
Perm(Modifiers(
(
(
(
(
(
(
((
Primary(/w(fracs(
Other?(
(
(
(
(
(
(
(
(
(
(
Req’s Water
Req’s Water
Req’s Water

ORDOS BASIN
CHINA
Reference 1
Reservoir
Pressure 2.94 - 6.38 MPa (Low), Temp 40 - 80 C
Oil Properties
Visc 1.48 - 4.3 cP, 0.693-0.8 g/ml, GOR low
Formation Water (mg/L)
Ca 6712-19 002, K/Na 6985 - 39 439, Ba 120 - 1693
Mg 18 - 1266
Salinities 70 000 - 132 000
CL 39 228 - 80 907
HCO, CO3, SO4 low

Case Study: Advanced WF
Jing’an Oilfield, Ordos Basin
Permeability 0.5 - 2 mD
Porosity 8 - 13%
Depth 1690
Reservoir Pressure 10.51 MPa
Primary Recovery 8-10%, AWF incr RF~
3-5%
Wuliwan
Reference 1
Losing
Energy
Early Water
Breakthrough
Optimal
40 - 50 m3/d
Nanliang
Drill injectors 6 months before producers

Case Study: Frac Injectors?
Ansai Oil Field, Ordos Basin
In 1990, 44 Wells not fractured with W/H injection pressures of 6.1
MPa.
23 Neighbouring wells were frac’d and injection pressures were 5.9
MPa.
Additionally, why convert frac’d producers to injectors?
Conclusion: Water injection will open up natural fractures…do not
exceed frac pressure that will lead to early break through!
Reference 1

Case Study: Low Sal WF
Reference 2
Xi Feng Oilfield
Permeability 1.12 mD
Porosity 10.7%
Clay Content 11.4-34.3% (34% Smectite)
Pore Throat Radius 0.05-.29 um
Reservoir Temp 65 C
Oil Density 0.81 g/cm3
Oil Visc 9 cP
Salinity 58 430 mg/L (Ca 2460, Mg 317)
Low Sal Water
A. 5569 mg.L (Ca 200, Mg 30)
B. 2784 mg/L (Ca 100, Mg 15)
No movable fines Results: Improved %OOIP by 13.3%
Need NF treatment or brackish source!
Restricted)Pore)Throat)
Grain)
Boundary)Layer)Forms)
(Adsorp:on)of)Fluids))
Grain)
- - - -
+ + + +

POTENTIAL DAMAGE TO RESERVOIR & WELLBORE
Injector
Producer
Well Bore
• Large particles >33% ave Pore Throat i.e. 2 mD, Particles>0.5 um will plug.
Near Well Bore
• Clay Swelling
• Adsorption (chemicals / ions)
• Injected small particles
• Bacteria
Well bore / Near Well Bore
• Damage from non compatible
drilling / completions / WO fluids
• Artificial fracs potential channels
for injection fluid
• Water Blocks (if Swi < Swirr)
Reservoir (natural filter)
• Plastic Deformation of Matrix
• Gas Break out from Oil
Water Front

Well Bore DamageParticle size > 33% Pore Throat
Reference 3,4,6,7,8,9,10,11,12,13

Near Well Bore DamageParticle size >7% & < 33% Pore Throat
Can also improve Injectivity with pressure pulsing or seismic stimulation
Reference 3,4,6,7,8,9,10,11,12,13

Formation DamageParticle size <7% will pass through
Reference 1

Water Specifications
Water Floods
1. Water driven oil field injected water quality standard
Currently DaQing oil field regular injecting water carries the industrial
standard issued by National Petroleum & Gas General Corporation
<<Particles of Classic Rocks Oil Reserve Injecting Water Standard>> (Table
1) ((SY/T 5329-94) and DaQing Oil Co. Ltd issued enterprise standard <<
DaQing Oil Reserve Injecting Water Standard>> (Q/SY DQ0605-2000)
(Table 2).
7DEOH Particles of Classic Rocks Oil Reserve Injecting Water Standard
67676767
,1-(7 /$(5
$9(5$*( $,5
3(50($%,/,7­m2
˘ ̚ ˚
67$1'$5' *5$',1* $ $ $ % % %
)/2$7,1*
3$57,/(6 PJ/
İ
İ İ
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2
1
7
5
2
/
)/2$7,1*
3$57,/(
',$0(7(5­P
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2,/ 217(17
PJ/
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$9(5$*( 5$7( 2)
25526,21 PPD
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65% *(50 36P/ ˘ ˘ ˘ ˘ ˘ ˘
6$3523+7,
%$7(5,$
360O
Qh Qh Qh
3
$
5
$
0
(
7
(
5
,521 %$7(5,$
36P/
Qh Qh Qh
1RWH LQ WKH WDEOH İQ˘DŽ
7DEOH DaQing Oil Reserve Injecting Water Standard (Q/SY DQ0605-
2000) 46 '446 '446 '446 '4
$9(5$*( $,5 3(50($%,/,7
Oilfield Water Technical Requirements China
Also consider water compatibility scaling tendencies other impurities that affect injectivity.
Frac Fluid Req’s
100 ppm
1 um
30 ppm
10 cells / mL

Water Treatment Technologies
Suggested Configurations for Tight Oil
1. Skim Tank - DAF/DGF or EC - MMF - UF - chem inj
Add NF or WAC to remove divalents for Low Salinity flooding

Final Thoughts
1. Put a reservoir in front of your reservoir (i.e. filtration).
Damage may not be reversible!
2. Mother nature (formation / water quality) drives water
treatment solutions.
3. It’s critical to inject early and keep the water flowing
(i.e. maintain reservoir pressure).

References:
1.
Advanced
Water
Injec0on
for
Low
perm
Reservoirs
Ran
Xinquan
Petroleum
Industry
Press
2013
2.
Coreflood
study
of
low
salinity
effects
in
low
permeability
sandstone
reservoirs,
Wu
Jiazhong
et
al
2012
3.
A
new
methodology
that
surpasses
current
bridging
theories,
VIkers
et
al
2006
4.
Injec0on
Water
Quality
-­‐
A
Key
Factor
to
Successful
Waterflooding,
Bennion
et
al
JCPT
June
1998
5.
Produced
Water
Treatment
in
Hydraulic
Fracturing,
Martex
et
al
2013
Canadian
Business
Conference
6.
Forma0on
Damage,
King
et
al,
March
14,
2009
presenta0on
7.
Enhanced
Oil
Recovery
Injec0on
Waters,
Collins
et
al,
1982
US
DOE
8.
Iden0fying
Op0mum
Techniques
for
Parafin
Control,
Schuler,
March
2014
9.
SPE
122189
Improving
Water
Injec0on
in
a
Mature
Field,
Cavallero
et
al,
2009
10.
Water
and
Fluid
Based
Reten0on
in
Low
Perm
Media,
Bennion
et
al,
2006
11.
Study
and
Applica0on
of
Waterflood
Protec0on
Technology
in
Developing
Low
Perm
Reservoirs,
Zhang
et
al,
2013
12.
Decompression
adn
Augmented
Injec0on
during
Waterflooding
Development
in
Low
Perm
Reservoirs,
Zhang
et
al,
2012
13.
Mechanisms
and
Effec0ve
Preven0on
of
Damage
for
Forma0ons
with
Low-­‐Porosity
and
Low-­‐Permeability,
Yan
et
al,
2012
14.
Product
Descrip0on
–
Shengl
Oilfield
Water
Treatment
for
Low
Perm
Reservoirs
15.
SPE893731
Oil
Recovery
with
HZ
Waterflooding,
Osage
COunty
Oklahoma
2004,
Westermark
et
al
16.
New
Field
Water
Treatment
for
Produced
Water
Reuse
in
Fracing
Tipton_Steven,
July
9,
2013
presenta0on