Enhanced Oil Recovery Technique in Shengli Oilfield - Yong - Shengli Oil Field...Enhanced Oil...

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


Outline


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


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


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


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


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


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


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


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


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


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


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


●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


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


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.


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


Content of divalent ion, mg/L

Water

Crude oil

Rock

Key question: How to achieve ultralow IFT without alkali?


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


● SP system： 0.3%S1+0.1%S2+0.15%P


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


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


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.


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%


2.4 HPCF


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


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


application


application


Outline


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


Problems:

High oil viscosity: >100,000cp

High injection pressure: >18MPa

Low injection capacity： <1t/MPa·h

Small heating radius: <50m

3.2 HDCS


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


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


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


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


Production curves of the pilot

40

102

Dai

ly o

il pr

oduc

tion,

t/d

Water cut, %

Date


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


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


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


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


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


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


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


1. Introduction


application


application


Outline


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


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


Thank You!

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