chemical eor for heavy oil in canada the canadian...

Chemical EOR for Heavy Oil in Canadathe Canadian Experience

Eric Delamaide (IFP Technologies (Canada) Inc.

Brigitte Bazin & David Rousseau (IFP Energies nouvelles)

Guillaume Degre (Solvay)

SPE 169715

Presented at the SPE EOR Conference held in Muscat, Oman 31 March – 2 April 2014

SPE 169715 • Chemical EOR for Heavy Oil: the Canadian Experience • David Rousseau (presenter)

• Chemical EOR in heavy oil

• Chemical EOR in heavy oil in Canada

• Selected projects

– Polymer flooding

– ASP flooding

• Conclusions

Outline


• Thermal is usually the method of choice for heavy

oil EOR

• Chemical EOR can be applied when thermal does

not work

– Too deep

– Too thin

• Capital cost is lower

– Less demanding in terms of water quality

Why chemical EOR in heavy oil?


Heavy oil Chemical EOR pilots in Canada

Company Field Pool

Dead oil

viscosity

(cp)

Process Status

CNRL Pelican Lake Wabiskaw 1,500-2,500 P Full field

Cenovus Pelican Lake Wabiskaw 1,500-2,500 P Full field

Cenovus Suffield Upper Mannville 1,300 ASP Appears succ. but operational issues

Pengrowth East Bodo Lloydminster 1,100 P Severe operational issues

Pengrowth Cactus Lake McLaren P In progress

Murphy Seal Bluesky 5,000-12,000 P Positive response

BlackPearl Mooney Bluesky 255-400 P, ASP Successful polymer pilot, ASP

Nexen Court Bakken 860 C Failure

Enerplus Giltedge Lloydminster 800-1,200 P Early polymer BT (DOB 7/4/2012)

Enerplus Medicine Hat Glauconitic 1,000-1,500? P Starting

Enerplus Wildmere Lloyd and Sparky 750 P In progress

Northern Blizzard Cactus Lake Basal Mannville P In progress

Harvest Suffield Caen 400-600 P Successful

Harvest Viking Kinsella Wainwright 100 P ?

PennWest Coleville ASP ?

Zargon Little Bow Mannville I ASP Not started

Husky Taber/Warner Mannville B 120 ASP Full field, succ. but operational issues

Husky Gull Lake North Upper Shaunavon 24 ASP ?

Husky Crowsnest Glauconitic 85 ASP Successful, uses biosurfactant

Husky Wrentham Lower Mannville 110 AP Successful

Hyak Battrum Roseraie 100-200? ASP Starting

Talisman Instow Upper Shaunavon ASP Successful

EnCana Viking Kinsella Sparky 100 P ?


• Polymer flood

– Brintnell/Pelican Lake: high viscosity, full field extension

– Seal: very high viscosity

– Mooney: variable spacing

• Alkaline-Surfactant-Polymer (ASP) floods

– Taber South: long waterflood, high water-cut, high

secondary recovery

– Suffield: low secondary recovery, low water-cut

Five chemical EOR projects selected


Main projects characteristicsProjects Pelican Lake Mooney Seal Taber Suffield

CompanyCNRL and

CenovusBlackPearl Murphy Husky Cenovus

Type PF PF & ASP PF ASP ASP

Average depth (m) 300-450 900-950 610 985 930

Average net pay (m) 1-9 2.5 8.5 7.1 2.9

Porosity 28%-32% 30% 27%-33% 18% - 28% 30%

Permeability (md) 300-5,000100-

10,000+300-5,800 1,500-3,500

1,000-

3,000?

Reservoir temperature (°C) 12-17 29 20 35 32

Initial reservoir pressure (bar) 18-26 58.0 51.5 99.5 104.9

API gravity 12-14 12-19 10-12 19 15

Dead oil viscosity @ Res. T⁰

(cp)800-80,000 300-500

5,000-

12,000120 600

Live oil viscosity @ Res. T⁰ (cp) 800-80,000? 120-300? 3,000-7,000 40 130

Recovery at start of EOR

(%OOIP)5-10 38.7 14.1


Pelican Lake pool map

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10kmx10km


Pelican Lake polymer flood pilot (CNRL)

• Initiated in 2005

• 1,500 m (4,900 ft) long horizontals

• 175 m (575 ft) spacing

• Live oil viscosity: 1,500 -2,000 cp

• Polymer

– HPAM

– 20MM (later reduced to 12

MM)

– Viscosity 20 cp to 13 cp

(SPE 165234)


Pelican Lake central well production history

0

10

20

30

40

50

60

70

80

90

100

0

50

100

150

200

250

300

350

400

450

500

Wa

ter-

cut

(%)

Oil

ra

te (

bb

l/d

)

Begin injection


Oil rates in high viscosity - 200 m spacing

0

10

20

30

40

50

60

70

80

90

100

0 0,02 0,04 0,06 0,08 0,1

Oil

ra

te (

bb

l/d

)

Injection (PV)

PL 5,000 - 7,000 cp PL 5,700 cp PL 6,000 - 12,000 cp


Water-cut in high viscosity - 200 m spacing

0

10

20

30

40

50

60

70

80

90

100

0 0,02 0,04 0,06 0,08 0,1

Wa

ter-

cut

(%)

Injection (PV)

PL 5,000 - 7,000 cp PL 5,700 cp PL 6,000 - 12,000 cp


Seal polymer flood pilot (Murphy)

70m 70m 70m 70m70m70m 140m

• Initiated in 2010

• 1,400 m (4,600ft) long

horizontals

• 70 m (230 ft) spacing

• Live oil viscosity 3,000 – 7,000 cp

• Polymer

– HPAM

– 20 MM

– Viscosity 25 cp to 45 cp

– Injection 150-400 bbl/d/well


Seal confined well production history

0

10

20

30

40

50

60

70

80

90

100

0

50

100

150

200

juin-09 juin-10 juin-11 juin-12 juin-13 juin-14

Wa

ter-

cut

(%)

Oil

ra

te (

bb

l/)

Oil rate

Water-cut

Begin polymer injection


Seal confined well production history

0

10

20

30

40

50

60

70

80

90

100

0

50

100

150

200

250

300

juin-09 juin-10 juin-11 juin-12 juin-13 juin-14

Wa

ter-

cut

(%)

Oil

ra

te (

bb

l/)

Oil rate

Water-cut

Begin polymer injection


Influence of viscosity on oil rates50 m (PL) and 70 m (Seal) spacing

0

20

40

60

80

100

120

140

160

180

200

0,00 0,02 0,04 0,06 0,08 0,10 0,12 0,14 0,16 0,18 0,20 0,22

Oil

ra

te (

bb

l/d

)

Injection (PV)

PL 3,000 - 5,000 cp PL 3,000 - 5,000 cp PL 5,000 - 7,000 cp

PL 5,000 - 7,000 cp PL 8,000 - 15,000 cp Pl 8,000 - 15,000 cp

PL 8,000 - 15,000 cp PL 8,000 - 15,000 cp Seal 7,000 - 12,000 cp


Influence of viscosity on water-cuts50 m (PL) and 70 m (Seal) spacing

0

10

20

30

40

50

60

70

80

90

100

0,00 0,02 0,04 0,06 0,08 0,10 0,12 0,14 0,16 0,18 0,20 0,22

Wa

ter-

cut

(%)

Injection (PV)

PL 3,000 - 5,000 cp PL 3,000 - 5,000 cp PL 5,000 - 7,000 cp PL 5,000 - 7,000 cp

PL 8,000 - 15,000 cp Pl 8,000 - 15,000 cp PL 8,000 - 15,000 cp PL 8,000 - 15,000 cp

Seal 7,000 - 12,000 cp Seal 7,000 - 12,000 cp


Taber ASP flood (Husky)

• Injection began May 2006

• Dead/Live oil viscosity

120/40 cp

• Injection fluid composition

– Softened water

– Main slug (0.34 PV)

• Alkaline (NaOH) @ 0.75% wt

• Surfactant @ 0.15% wt

• Polymer @ 1,200 ppm

– Tapered polymer (0.30 PV)

• from 0.12%wt down to 0.06%wt

(SPE 165264)


Taber ASP response

0

10

20

30

40

50

60

70

80

90

100

0

200

400

600

800

1 000

1 200

1 400

1 600

1 800

2 000

mai-96 mai-98 mai-00 mai-02 mai-04 mai-06 mai-08 mai-10 mai-12 mai-14

Wa

ter-

cut

(%)

Oil

ra

te (

bb

l/d

)

Oil rate

Water-cut

Begin injection


Scaling issues in ASP projects

• Severe scaling issues at both Taber and Suffield

– Scales: Calcium carbonate and silica

• In Taber scales caused 30% annual downtime, some

wells had to be redrilled

(SPE 165285)


Mobility Ratio target for viscous oil

• For viscous oil M = 1 is unrealistic due to limitations in

injectivity

@ Reservoir T⁰

Dead oil

viscosity

(cp)

Live oil

viscosity

(cp)

Viscosity of

injected solution

(cp)

Pelican Lake (pilot)

1,200-1,800 1,500? 13-25

Mooney 300-500 120-500? 20-30

Seal 5,000-12,000 3,000-7,000? 25-45

Taber 120 50 22-32

Suffield 480 180-250? 22


• Multiple cEOR projects in heavy oil in Canada

• Chemical EOR is a viable solution for heavy oil

– Thin/deep

– Low capex

• Polymer flooding has been proven for viscosities up

to 10,000 – 15,000 although efficiency appears to

decrease as viscosity increases

• ASP has been proven for lower viscosity (<500 cp)

• Scaling can be a severe issue for ASP

Conclusions

Thank you for your attention

chemical eor for heavy oil in canada the canadian...

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