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Enhanced Oil Recovery Technique in Shengli Oilfield
Shengli Oilfield, SINOPEC September, 2012
1. Introduction
2.Chemical flooding technology &
application
3.Thermal recovery technology &
application
4. Outlook of EOR in Shengli Oilfield
Outline
EOR technique in Shengli Oilfield
Shengli Oilfield is located in the Yellow River Delta near Bohai sea shore, which is put into production in 1964.The OOIP is 441×106t and the annual oil-producing capacity is 27.34 ×106t.
1. Introduction
The distribution map of China's main petroliferous basin and oil/gas field
Shengli Oilfield
High Reservoir heterogeneity:fluvial deposition; the
permeability variation is more than 16;
High temperature/high salinity:
T>80℃、TDS>20000mg/L,844×106t,proportion:52.6%;
High total water cut:producing reserves(water
cut:>95%) is 1.41 ×109t and the proportion is 87.9%。
The harsh EOR reservoir conditions
1. Introduction
For chemical flooding
Deep burial depth:92% of Reserves burial
depth is more than 1200m;
High oil viscosity:part of reserves is more
than 100,000mPa•s;
Thin layer:part of reserves is less than 6m.
1. Introduction
For thermal recovery
The harsh EOR reservoir conditions
20.1
79.9
29.3
70.7
0
20
40
60
80
100
化学驱+热力采油 注水开发
Reserves Output
The status of producing reserve and output proportion in different recovery methods
1. Introduction Pr
opor
tion,
%
Chemical flooding +thermal recovery
Water flooding
EOR plays an important role in Shengli Oilfield
EOR plays an important role in Shengli Oilfield
1. Introduction
The output of Shengli Oilfield during 1995-2011
1000
1500
2000
2500
3000
3500
1995 1997 1999 2001 2003 2005 2007 2009 2011
常规开采 热力采油 化学驱
Annu
al o
il ou
tput
, 104
t 29.3% 8.9%
70.7% 91.1%
22.1%
77.9%
14.6%
85.4%
Conventional recovery
Thermal recovery
Chemical recovery
1. Introduction
2. Chemical flooding technology &
application
3. Thermal recovery technology &
application
4. Outlook of EOR in Shengli Oilfield
Outline
EOR technique in Shengli Oilfield
Resource classification of chemical flooding
2.1 The status of chemical flooding
2.Chemical flooding technology & application
Type
Screening criteria
OOIP 109t Permeability
10-3µm2 Temperature
℃ Salinity
mg/L
Divalent contents
mg/L Ⅰ ≥500 ≤70 ≤10000 ≤200 0.306 Ⅱ ≥500 70-80 10000-30000 200-400 0.269 Ⅲ ≥100 80-95 30000-100000 >400 0.510 Ⅳ Thief zone 0.114
Ⅴ Temperature: 90~120℃;Permeability:50~100×10-3µm2 0.235
Offshore Offshore oilfield 0.172 Total 1.605
Development Process
2.Chemical flooding technology & application
Expanding test
Laboratory
study Pilot Application
1996 1998 2002 2005
TypeⅠ
TypeⅡ
TypeⅢ
1966 1992 1994 1997
2000 2005
Type Ⅳ 2000 2004
After polymer flooding
2008 2010
2.Chemical flooding technology & application
Development Process
Expanding
test
Laboratory
study Pilot Application
Alkaline: 1966
Surfactant: 1966
Polymer: 1966 1992 1994 1997
ASP : 1985 1992 1997
SP: 2000 2003 2006 2008
Foam flooding: 2000 2004
Heterogeneous phase combination flooding
(HPCF) :
2006 2010
Main technology
Polymer
ASP
SP
HPCF
2.Chemical flooding technology & application
Reasonable viscosity ratio of polymer solution to oil: 0.15~0.5
Relation between viscosity ratio and EOR
(Temperature:80℃,salinity:19334mg/L,permeability:1500×10-3μm2)
0
4
8
12
16
20
0 0.2 0.4 0.6 0.8 1 1.2μp/μo
提
高
采
收
率
%
2.2 Polymer Flooding
2.Chemical flooding technology & application
EOR
,%
Reservoir typeⅠ: Molecular Weight of HPAM >15×106
Formula:0.05PV×2000mg/L+0.20PV×1500mg/L (HPAM made up by fresh water and injected by producing water)
0
20
40
60
80
100
0 500 1000 1500 2000 2500 3000 3500聚合物浓度 mg/L
1500万
1200万
Visc
osity
,mPa
.s
20
2.Chemical flooding technology & application
The viscosity-concentration relationship of different polymers in reservoir type Ⅰ conditions
( Temperature: 70℃, salinity: 5727mg/L,DVIII viscometer ULRotor,6rpm)
Concentration, mg/L Concentration, mg/L Concentration, mg/L
15×106
12×106
●OOIP:1.65×106t
●Injectors:4
●Producers:10
●Temperature : 70℃
●Salinity :5293 mg/L
Oil well Water well 0 100 200 300 400
2.Chemical flooding technology & application
The structure well location map of layer Ng3 in Zhongyi region in Gudao Oilfield
The polymer flooding pilot was implemented in reservoir type Ⅰ of layer Ng3 of Zhongyi region in Gudao Oilfield in 1992.
0
100
200
300
400
1992 1994 1996 1998 2000 2002 2004 2006
时间
60
70
80
90
100
日油
含水
90.3
71 122
351
2.Chemical flooding technology & application
The cumulative incremental oil production is 200×103t and EOR 12%.
Dai
ly o
il pr
oduc
tion,
t/d
Water cut, %
The pilot production curves in layer Ng3 of Zhongyi region in Gudao Oilfield
Daily oil production Water cut
Year
0
20
40
60
80
100
0 500 1000 1500 2000 2500 3000 3500浓度 mg/L
1500万2000万
.
Visc
osity
,mPa
.s
20.3
2.Chemical flooding technology & application
Reservoir type Ⅱ: Molecular Weight of HPAM >20×106
Formula:0.05PV×1800mg/L+0.20PV×1400mg/L (made up by fresh water and injected by producing water)
The viscosity-concentration relationship of different polymers in reservoir type Ⅱ conditions
(Temperature: 80℃, salinity: 21000mg/L,DVIII viscometer ULRotor,6rpm)
Concentration, mg/L
15×106
20×106
●OOIP:10.89×106t
●Injectors:32; Producers:58
●Temperature:80℃
●Salinity:21000mg/L
●Divalent:311mg/L
1920
0 100 200 300 400
1-3-12 1-3N13 1-3N141 1-4-172 1-4-174
24 21
32+3
1980
2000
2020
2040
2060
2080
2100
12
25
34
37
11
13
31
34
26
2.Chemical flooding technology & application
The pilot was implemented in reservoir type Ⅱ in 1998.
The structure well location map of Sha’er 1-3 in region 1 of Shengtuo Oilfield
The west-east profile map of the pilot of Sha’er 1-3 in Zhongyi region of Shengtuo Oilfield
Graphic symbol
Oil well Water well
0
100
200
300
400
500
600
700
1998 2000 2002 2004 2006 2008 2010 2012时间
70
75
80
85
90
95
100
日油含水
95.9
81.7 227
608
2.Chemical flooding technology & application
The cumulative incremental oil production is 723×103t and EOR 6.6%. D
aily
oil
prod
uctio
n, t/
d W
ater cut, %
The pilot production curves in Sha’er 1-3 of region 1 in Shengtuo Oilfield
Daily oil production Water cut
Year
● Polymer flooding projects:28
OOIP:290×106t annual oil increment:720×103t,
cumulative oil increment:16.8×106t
● Water cut drops 7~19.3%,
oil production increases by 1.8~3.1 times
● EOR: 6-12% , average:7.1%
● Oil increment per ton of polymer:50~143t/t,average:73t/t
2.Chemical flooding technology & application
●Acid number of crude oil>1.2mgKOH/g ●The first pilot of ASP in China was started in 1992.
● OOIP:78×103t
● Injectors:4; Producers:9
● Temperature:69℃
● Salinity:5823mg/L
● Well spacing : 50m 1264
1272
0 50 100 150 200
2.3 ASP
2.Chemical flooding technology & application
The structure well location map of layer Ng52+3 in Qiquxi in Gudong Oilfield
Graphic symbol
Oil well Water well Observation well
●Oil increment of central well is 1740t and EOR 16.8%
●ASP system: 1.5%A+0.4%S+0.1%P
85.2
99.3
60
70
80
90
100
1989 1990 1991 1992 1993 1994 1995 1996时间
30
40
50
60
70
80
含水
采出程度
2.Chemical flooding technology & application
54.4
71.2 76.2
Water flooding ASP Wat
er c
ut,%
Oil recovery,%
The central well production performance
Water cut Oil recovery
Year
OOIP:1.97×106t; Injectors:6; Producers:13; Cumulative output:287×103t; EOR 14.6%.
●ASP system: 1.2%A+0.3%S+0.15%P
The production curves of the central well
0
10
20
30
40
1997 1999 2001 2003 2005 2007 2010
时间
75
80
85
90
95
100
Dai
ly o
il pr
oduc
tion,
t/d 94.8
82.9 12
36.7
Water cut,%
●The expanding test of ASP was carried out in 1997.
2.Chemical flooding technology & application
The structure well location map of the Xiqu for ASP in Gudong Oilfield
Oil well Water well
Time
● Need: alkali-free effective technique—dilute surfactant +polymer (SP)
● Scaling problem is caused during ASP injection due to the high content of divalent ions.
The resource composition of chemical flooding
13.0
58.9
27.3
0
20
40
60
80
<100 100-500 >500L二价离子含量 mg/L
OO
IP,%
2.4 SP
2.Chemical flooding technology & application
Content of divalent ion, mg/L
Water
Crude oil
Rock
Key question: How to achieve ultralow IFT without alkali?
2.Chemical flooding technology & application
Synergism effect:ultralow IFT can be achieved by the
synergism between anionic and nonionic surfactants for their wedgy
alignment at water/oil interface.
Anionic surfactant only
Anionic surfactant Nonionic surfactant
Anionic and nonionic surfactants mixed
2.Chemical flooding technology & application
● SP system: 0.3%S1+0.1%S2+0.15%P
2.Chemical flooding technology & application
IFT curves of SP system and oil from Qiquxi in Gudong Oilfield
Anionic and nonionic surfactants mixed
● The first SP pilot was implemented in Sep, 2003.
OOIP:2.77×106t
Injectors:10
Producers:16
Temperature:68℃
Salinity: 7883mg/L
Divalent:244mg/L
2.Chemical flooding technology & application
The structure well location map of the SP pilot in Qiquxi region of Gudong Oilfield
Graphic symbol
Oil well Water well
EOR 18.0%
0
20
40
60
80
100
120
140
2003 2004 2005 2006 2007 2008 2009 2010 2011
时间 年
50
60
70
80
90
100
98.3
60.4 10.4
127.5
2.Chemical flooding technology & application
Dai
ly o
il pr
oduc
tion,
t/d
Water cut,%
The production curves of the central well for SP pilot Year
The cumulaitve oil increment of Well 32-175 is 40.5×103t.
2.Chemical flooding technology & application
0
10
20
30
40
50
60
70
2003 2004 2005 2006 2007 2008 2009 2010 201150
60
70
80
90
100
98.7
2.1
52.2
57.0
The production curves of the central well(32-175)
Dai
ly o
il pr
oduc
tion,
t/d
Water cut,%
The structure well location map of the SP pilot in Qiquxi of Gudong Oilfield
Graphic symbol
Oil well Water well
Typical well: 32-175
● SP projects :16; OOIP:140×106t
● Water cut decreased by 12~22%,
production increased by 3.0~7.6 times
● Annual oil increment: 780×103t,
cumulative oil increment: 4.74×106t
● EOR: 10-18%
2.Chemical flooding technology & application
2.4 HPCF
2.Chemical flooding technology & application
require
require
Stronger heterogeneity
More dispersed
remaining oil
Improve sweep volume
Improve displacement
efficiency
Reservoir (after
polymer flooding)
HPCF
The HPCF pilot after polymer flooding in layer Ng3 of Zhongyi region of Gudao Oilfield
OOIP:2.21×106t
Injectors:15
Producers:10
Temperature :700C
Salinity :7373mg/L
Divalent ion :92mg/L
Watercut before HPCF :98.3%
Oil recovery before HPCF :52.3%
Well location map of pilot
2.Chemical flooding technology & application
Oil well Water well
0
10
20
30
40
50
60
70
2010.1 2010.4 2010.7 2010.10 2011.1 2011.4 2011.7 2011.10 2012.1 2012.4 2012.780
85
90
95
100
日油 含水
Chemical flooding
New well 83.8
68 96.6
18.3
97.5
4.5
The pilot production curves of HPCF in layer Ng3 of Zhongyi region of Gudao Oilfield
Up to now, the oil increment is 30×103t and EOR 1.83%.
2.Chemical flooding technology & application D
aily
oil
prod
uctio
n, t/
d
Water cut,%
-Daily oil production; -Water cut
油井
水井
11-315
11X3312
10X3311
10X3310
9-313
9X3009
10X3010
11J11
11X3012
11X3013
12N313
12X3312
11X3311
11X3310
11-311
11X3009
11X3010
11XN411
12X3012
12X301313X313
13X3312
13X3311
12X3310
11X309
油井
水井
11-315
11X3312
10X3311
10X3310
9-313
9X3009
10X3010
11J11
11X3012
11X3013
12N313
12X3312
11X3311
11X3310
11-311
11X3009
11X3010
11XN411
12X3012
12X301313X313
13X3312
13X3311
12X3310
11X309
0
10
20
30
40
2011.4 2011.6 2011.8 2011.10 2011.12 2012.2 2012.4 2012.6
20
40
60
80
100
日油 含水
31.3 4.7
92.2
32.0
2.化学驱油技术与应用
Typical well:12X3012 Water cut drops from 92.2% to 31.3% and the daily oil
production increases from 4.7t/d to 32.0t/d. D
aily
oil
prod
uctio
n, t/
d
-Daily oil production; -Water cut
Water cut,%
The production curves of Well 12X3012
2.化学驱油技术与应用
160
0
50
100
150
200
1994 1996 1998 2000 2002 2004 2006 2008 2010
1 4
23
37 53
102
132 134 134
149
171 174 172 171 171 160 150
Polymer flooding
Combination flooding
Curves of Oil increment of chemical flooding in Shengli Oilfield
Oil
incr
emen
t,104
t
By the end of July,2012, there are 48 chemical EOR projects, the
OOIP is 430×106t,the cumulative oil increment is 21.85×106t and
the cumulative oil production is 46.50×106t.
1. Introduction
2.Chemical flooding technology &
application
3. Thermal recovery technology &
application
4. Outlook of EOR in Shengli Oilfield
Outline
EOR technique in Shengli Oilfield
3.1 The status of thermal recovery
Year Technology 1983 Cyclic steam stimulation for super heavy oil
1991 Steam flooding
1999 Cyclic steam stimulation for extra heavy oil
2003 Cyclic steam stimulation for heavy oil after water flooding
2006 HDCS for extra-super heavy oil
2009 HDNS for super heavy oil in shallow buried thin formation
2009 Chemical assisted steam drive
2010 Steam flooding for heavy oil after water flooding
Development process
3. Thermal recovery technology & application
HDCS for extra-super heavy oil
Steam flooding for heavy oil after water flooding
Chemical assisted steam drive
3. Thermal recovery technology & application
Problems:
High oil viscosity: >100,000cp
High injection pressure: >18MPa
Low injection capacity: <1t/MPa·h
Small heating radius: <50m
3.2 HDCS
3. Thermal recovery technology & application
H(Horizontal well): reducing injection
pressure
D(Dissolver): reducing viscosity near
the wellbore
C(CO2): reducing viscosity and helping
drainage and heat protection
S (Steam): distillation and heating to
reduce viscosity
HDCS mechanism
Realizing synergistic effect.
Production process
Horizontal well
Dissolver + condensation zone
Steam zone
CO2 gas cap
3. Thermal recovery technology & application
Well location map of HDCS development of Zheng 411 reservoir, Wangzhuang
The burial depth of Zheng 411
reservoir is 1320m, the oil viscostity
is 300,000cP.Using HDCS, the
periodic output of the single well
increases from 127t(by conventional
technique) to 1812t,which improves
by 13.3 times。
Field application
127
1812
0
500
1000
1500
2000
HS
HDCS pe
riodi
c ou
tput
, t
Cyclic steam injection in horizontal wells
HDCS
3. Thermal recovery technology & application
The contrast curves of displacement efficiency in different steam quality and pressure
Steam quality,40%
The oil recovery can be improved by increasing steam quality at the high pressure.
3.3 Steam flooding for heavy oil after water flooding
Steam quality,60%
Dis
plac
emen
t effi
cien
cy,%
Steam injection pressure, MPa
3. Thermal recovery technology & application
The well pattern of steam flooding after water flooding in layer Ng5 of Zhong’er zhong region
OOIP :1.15×106t
Well pattern: invert nine-spot
Well spacing: 141×200m
Injectors: 4
Producers: 21
Steam flooding was started when
the reservoir pressure was about
7MPa.
Field application
3. Thermal recovery technology & application
Production curves of the pilot
40
102
Dai
ly o
il pr
oduc
tion,
t/d
Water cut, %
Date
3. Thermal recovery technology & application
3.4 Chemical assisted steam drive
Problems:
Deep burial depth and high reservoir pressure:
burial depth:1000~1400m; reservoir pressure: 7~10MPa.
Strong heterogeneity: fluvial deposition; Vk>0.9
3. Thermal recovery technology & application
Remaining oil distribution in vertical after steam flooding
0.00
0.04
0.09
0.13
0.17
0.22
0.26
0.30
0.35
0.39
0.43
0.48
0.52
0.56
0.61
0.65
Injector Producer Injector Producer Producer Producer
Foam system with high temperature tolerance can effectively improve sweep volume.
Remaining oil distribution in vertical after foam steam flooding
3. Thermal recovery technology & application
The effect of IFT on residual oil saturation
As the IFT of displacement agent decreases, the residual oil saturations in different zones all decreases.
0
0. 1
0. 2
0. 3
0. 4
0. 5
0. 6
0. 0001 0. 001 0. 01 0. 1 1 10 100
65℃120℃200℃
Cool oil zone
Hot-water zone
High temperature zone
The oil displacement agent with high temperature tolerance can enhance displacement efficiency.
Res
idua
l oil
satu
ratio
n
IFT, mN/m
3. Thermal recovery technology & application
EOR can be achieved by the synergism of chemicals and heat. The comparison of displacement efficiency of different thermal recovery methods (dual tubes)
Based on steam flooding and assisted by steam flooding and foam agent, synergism between heat and agent can be achieved.
Dis
plac
emen
t effi
cien
cy,%
Steam flooding Steam flooding +displacement
agent Steam flooding
+foam agent
Steam flooding +displacement agent
+foam agent
3. Thermal recovery technology & application
The well pattern of chemical assisted steam drive in layer Ng5 of Zhong’er bei, Gudao
OOIP:1.84×106t
Well spacing:141×200m
100×141m
Well pattern:inverted
nine-spot
Injectors:8
Producers:37
Field application
3. Thermal recovery technology & application
80
90
100
0
50
100
150
200
250
8/10/2010 2/26/2011 9/14/2011 4/1/2012 10/18/2012
日油 含水
The pilot production curve
chemical auxiliary steam drive
82.9
In the stage, the output is 98×103t and the oil-steam ratio is 0.17t/t.
74
89.0
Oil
prod
uctio
n pe
r day
, t/d
W
ater cut, %
-Daily oil production; -Water cut 197
3. Thermal recovery technology & application
0
50
100
150
200
250
300
350
400
450
500
1996 1998 2000 2002 2004 2006 2008 2010
144 164 177
185
238
287 308
364
413 421
462 An
nual
oil
prod
uctio
n, 1
04t
Annual oil production of heavy oil in Shengli Oilfield
3. Thermal recovery technology & application
1. Introduction
2.Chemical flooding technology &
application
3. Thermal recovery technology &
application
4. Outlook of EOR in Shengli Oilfield
Outline
EOR technique in Shengli Oilfield
Technology Outlook of chemical flooding
Reservoir Type Ⅲ
Reservoir Type Ⅳ
Reservoir Type Ⅴ
Heat-and-salt-resistant polymer flooding
HPCF
Low IFT foam flooding
In-depth profile modification assisted SP
Emulsion-surfactant flooding
Organic alkali-SP
Wettability alteration
4. Outlook of EOR in Shengli Oilfield
Type Technology
Shallow medium-thick extra-super heavy oil reservoir
SAGD
Integral development of horizontal well
Horizontal well steam stimulation
Deep extra-super heavy oil reservoir
In-situ upgrading heavy oil technique
Super deep heavy oil reservoir
Huff and puff stimulation in fractured horizontal well
Heavy oil reservoir using water flooding
Multiple thermal fluids stimulation
High water-sensitivity heavy oil reservoir
Reservoir stimulation+thermal recovery technique
Outlook of heavy oil thermal recovery
4. Outlook of EOR in Shengli Oilfield
Thank You!