steaminjection design

7/27/2019 Steaminjection Design

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Harper Steam Injection Scheme

Performance Presentation to ERCB

March 22, 2011


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Sunshine Oilsands Ltd. Harper Pilot Resource Update March 2011 2

BackgroundSub-Surface

Geology / Geoscience Overview

Drilling and Completions

Instrumentation

Scheme Performance and Monitoring

Surface

Facilities

Environmental

Key Learnings and Future Plans

Agenda


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ApplicationApplication #1587764 submitted to ERCB on September, 2008

ApprovalApproval # 11379 received from ERCB on November, 2009

Delay of one year due to cancellation of Harper winter drillingprogram in 2009

Procurement of ServicesSeptember 2010

11-21-95-25W4M Drilling & CompletionsDrilling - December 30th to January 08th

Completions January 8th to January 25th

Steam Cycle

January 28

th

StartFebruary 15th End

Production CycleFebruary 19th Start

March 17th End

Demobilization

Introduction Key Dates


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Scheme PurposeConfirm oil mobility through thermal stimulation

Establish a preliminary data set to aid determination of the

applicability and technical feasibility of in-situ thermal recovery

methods as they apply to the Grosmont formation

ChallengesRemoteness

Winter only access

Weather

Terrain

Team Introduction

Introduction Scheme Purpose, Challenges & Team Introductions


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Jason HancherukVP, Land & Regulatory Affairs

Trevor DufresneSenior Geologist, Harper Pilot Project Manager

Tony SabelliVP, Drilling and Construction

Tomasz WnorowskiManager, Reservoir Engineering

Presenters


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Sub-Surface Information


7/88Sunshine Oilsands Ltd. Harper Pilot Resource Update March 2011 7

Geology


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Harper Property

Edmonton

Calgary

Ft McMurray

Injection well 11-21-95-24W4

Structural Cross Section A A

2 key wells in area (7-8 & 14-21)

Limited 2D seismic

Harper Property

A

AKey Well

7-8

Key Well

14-21

Injection

Well

11-21



Scheme Project Area

Edmonton

Calgary

Ft McMurray

Harper Property

Key Well

7-8

Pilot Area

Pilot Project

Area

Key Well

14-21

Injection

Well

11-21

Small section

pilot area

Injection well drilled

50m to SW of key

well 14-21


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Regional Stratigraphy

Pilot Project

Area



Regional Grosmont Structural Cross-Section

A

A



Reservoir Properties:

Depth: 540m to 571m

Net Pay Thickness: 29m

Avg. Porosity: 18%

Avg. So: 85%

Dol Scale

12% 100 Ohmm

11-21-95-24W4 Open Hole Logs (Steam Injection Well)


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11-21 Petrophysical Analysis (Steam Injection Well)

540m

Grosmont C

571m

Base Pay


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Depth: 541m to 566m

Net Pay Thickness: 22.6m

Avg. Porosity: 18%

Avg. So: 85%

Lst Scale

12

%

100 Ohmm

14-21-95-24W4 Open Hole Logs (Offset 50m to NE)

H Hi h R l i Mi I & P h i l


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Grosmont C

31m

Reservoir

Thickness

Fractures

Harper: High Resolution Micro-Imager & Petrophysical

Correlation 14-21-95-24W4 Grosmont C


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2mm

Thinsection work on 14-21-95-24W4


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Depth: 570m to 596m

Net Pay Thickness: 23.4m

Avg. Porosity: 22%

Avg. So: 85%

Lst Scale

12% 100 Ohmm

7-8-96-24W4 Open Hole Logs (6.1km North)

H Hi h R l ti Mi I & P t h i l


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Grosmont C

27m

Reservoir

Thickness

LargeVuggy

Porosity

Harper: High Resolution Micro-Imager & Petrophysical

Correlation 07-08-95-24W4 Grosmont C


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Grosmont C Net Pay Map

Legend23.4 m Net Pay Value

20m Net Pay Contours

Grosmont D..Subcrop Edge

Sunshine

Oilsands Land

Pilot Project

Area


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Grosmont C Pay Top Structure

Legend

23.4 m Pay Top

...Structure Value

20m Pay Top

.Structure Contours

Grosmont D

..Subcrop Edge

Sunshine

Oilsands Land

Pilot Project

Area


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Grosmont C Pay Bottom Structure

Legend

23.4 m Pay Bottom

Structure Value

20m Pay Bottom

.Structure Contours

Grosmont D

..Subcrop Edge

Sunshine

Oilsands Land

Pilot Project

Area


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Harper Property

Key Well

7-8

Key Well

14-21

Injection

Well

11-21

Pilot Project

Area

Trade Seismic Proprietary Seismic

(Winter 2011)

Harper Property 2D Seismic


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Pilot Area

Pilot Project Area

Injection Well

11-21

Reservoir Properties

from 11-21 Injection Well:

Depth: 540m to 571m

Net Pay Thickness: 29m

Avg. Porosity: 18%

Avg. So: 85%

OBIP:~ 17.8 Million Bbls/qtr sec

OBIP=(Phi*h*A*(1-Sw))/FVF

Phi = 18%

h = 29m

A = 64ha

Sw = 15%FVF = 1.005

OBIP for Scheme Area in Harper (1/4 Section)


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The Grosmont formation was ultimately sealed by theoverlaying Lower Cretaceous Wabiskaw shales

Caprock injectivity testing shows the Wabiskaw shale fracture

gradient to be 22kpa/m

Maximum surface steam injection pressures were limited to

5,100 kPa to prevent fracturing of the Wabiskaw shales

Actual injection pressures did not exceed 4,000 kPa throughout

the steam injection cycle

Caprock


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Drilling and Completions


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Scheme Area Location

Edmonton

Calgary

Ft McMurray

Harper Property

Pilot Area

Pilot Area


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Well Summary Drilling 11-21-95-24W4

Spud date: December 30, 2010

Surface: Drilled 444mm hole to 145mKBRan 339.7mm X 81.1Kg/m K55 casing, set at 145mKB

Cemented with 20t RFC thermal cement, 2.5m3 returns

Intermediate: Drilled 311mm hole to 536mKB

Ran 244.5mm X 59.3 Kg/m L80 Hydril 603, set @ 536m

Cemented with 24t of RFC thermal cement, 8m3 of cement returns

Main Hole: drilled 200mm hole to 587mKB

Ran 139.7mm X 23.07kg/m J55 slotted liner, set at 587mKB (top @

523mKB)

Not cemented

Drilling losses: 380m3 into the Grosmont formation

Completed drilling operations on January 8th , 2011


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Well Summary Completions 11-21-95-24W4

Conducted well completion operation from January 8th to 25th

Ran CBL log from 523mKB to Surface casing

Reviewed CBL log with ERCB

Perforated Intermediate casing from 517-518mKB for remedial

cement Squeeze.

Performed remedial cement operations (squeezed 200 liters of

cement at maximum surface pressure of 3,000kPa)

Drilled out cement and cleaned out to top of liner.

Ran 88.9mm Hydril 503 tubing and PSN, set bottom of tubing @

517.17mKB

Ran 31.75mm Coil tubing c/w fiber optic and thermocouples, set coilbottom at 572mKB

Ran 300X250 RWBFS pump with 10X34mm sinker bars and

56X25.4mm grade D rods


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Well Summary Operations 11-21-95-24W4

Completed installation of steam generator and

production tanks from January 8th to 27th

Commenced steam injection - January 28th

Steam soak February 15th to 17th

Production operations initiated on February 18th

Steamer demobilization February 15th to 22nd

Production operations demobilization - March 17th to

22nd


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Well Completion

WELL NAME DATE Jan-23-2011

ELEVATIONS (meters)

KB ELEV GL ELEV KB TO THF KB TO SCF KB TO GL PBTD

770.09m 765.79m 3m 4.0m 4.30m 582m

OD (mm) LANDED DEPTH WEIGHT (kg/m Grade

339.7 145 81.1 K-55

244.5 536 59.3 Hydril 603

139.7 523-587 23.07 J-55

139.7 top @ 523

Perf Date Zones Top Shot Bottom Shot SPM Gun Data

Jan-14-11 Grosmount 523.00 587.00 SLOTTED 1/4"slots

1/17/2011 Abandoned perfs 517.00 518.00 13 Cemented off

Intermidiate

Slotted Liner

Liner Hanger Import tools

CASING DESCRIPTION

Downhole Well ProfileSunshine Harper 11-21-095-25w4

Surface Casing

DOWNHOLE DESCRIPTION FROM BOTTOM UP (Tubing String)ITEM # DESCRIPTION LENGTH TOP OF (mKB)

1 145.00 0.00

2 536.00 0.00

3 63.00 523.00

4 1.00 517 mKB

5 517.17 0.00

6 572.00 0.00

7 8.00 509.00

8 509.00 0.00

31.75mm coil tubing c/w fiber optic string & thermocouples

300X250 RWBFC max stroke 3.67m

10 X .34m sinker bars plus 56 X 25.4mm graded rods

339.7mm X 81.1kg/m. K55 sur face casing

244.5mm X 59.3 kg/m. L-80 hydril 603

139.7mm X 23.07 kg/m. J-55

remedial perf orations 517.518 mKB

88.9mm X 13.84 kg/m. hydril 503 L-80 tubing

REMARKS

All items on wellhead are high tempature . Pressure tested wellhead before steam injections 6 mpa.

Liner top is @523MKB Its a import oil tools liner hanger 177mm X 139.7mm

Perfs f rom 517 to 518mKB Where cemented off and pressure tested to 2 mpa w ith 0% leak off after 15 min

1

2

3

4

56

7

8


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Artificial Lift PerformanceMaximum SPM: 6

Maximum Fluid Production:

98m3

/dayActual Production Rates: 70-85m3/day

87% efficiencies achieved

Downhole Rod Insert Pump


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Wellhead Configuration and Schematic

WELL HEAD DESCRIPTION

ITEM # DESCRIPTION SERIAL # MWP SIZE

1 FMC Casing bow l 21.00 279.4mm

2 FMC Side angle entr y spool 21.00 279.4 x 179mm

complete w ith tbg hanger spool

slips installed in sideangle hanger

w ith 1.25 inch coil installed

3 FMC Flow tee w ith 1.25" radigans 21.00 179.4 x 94.5mm

rams and 50mm flow tee

ll i ll i . ll i i .

i i I i il l li i . .

i l i


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Instrumentation


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Fiber Optic string installed in the 11-21-95-24W4 pilot wellfrom surface to 572m

Continuous temperature monitoring during injection and

production cycles

Two thermocouples inside coil tubing string to verify fiber optic

performance and for calibration

Depths of 532m and 542m

Fiber Optic Monitoring


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Fiber optics inside coil

tubing string

Coil tubing string installed

independently outside of

tubing

Two thermocouples addedinside coil string to

evaluate fiber optic

accuracy

Allows for temperature

monitoring of steam

injection and produced

fluids

Fiber Optic Deployment


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Production Performance andMonitoring


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The pilot design consists of threeelements:

Steam injection

Maintain Nitrogen blanket in annulus

above Grosmont formation

Three day steam soakProduction

Harper Pilot Test Design

Soaking


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Average Steam Quality: 80%Average Daily Injection Rates: 245m3/d

Steam Generation Pressures: 2,000 - 4,000 kPa

Well Head Pressures: 2,000 3,000 kPa

No risks identified due to the low injection pressures and no

potential for fracturing of the formation or the cap rock

Fiber optic temperature string monitored for any unexpected

uphole temperature changes

Pressure fluctuations during steam injection cycle may be due to

heterogeneous fractured and vuggy nature of the Grosmont Cformation

Injection Operations Summary


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Fiber Optic Monitoring - Start of Injection

Initial Reservoir Temperature Gradient

Grosmont Reservoir Temperature: 19C


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Fiber Optic Monitoring - Injection Cycle

Injection Interval 523m-587m

Steam Temperatures: >200C

Nitrogen Blanket 0-520m

Temperature: ~170C


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Fiber Optic Monitoring - Injection Interval

Heating Across Grosmont

Injection Interval 523m-587m

Steam Temperatures: >200C


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0

1000

2000

3000

4000

5000

6000

1/27/2011 0:00 2/1/2011 0:00 2/6/2011 0:00 2/11/2011 0:00 2/16/2011 0:00 2/21/2011 0:00

P

r

e

s

s

u

r

e

Date/Time

Detailed Pressure Plot

S te am Di sc har ge P re ss W el lh ead Pr es su re N2 / Cs g P re ss F ee d W ate r Inl et P re ss

Steam Injection Period Pressure Monitoring

Steam Generator Start Up Following Electrical Failure

2 Days of Down Time Jan 30-31, 2011


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No seismic surveys at this time due to the limited span of this

project and only one CSS injection cycle

Long term pilot will require steam chamber growth and

surface monitoring including consideration of 4D seismic to

aid evaluation of reservoir conformance

Seismic


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Production Cycle


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Operating Temperature Range: 60-180 C

1

10

100

1000

10000

100000

1000000

10000000

100000000

0 20 40 60 80 100 120 140 160 180 200 220 240

Estimated Bitumen Viscosity for Harper

Viscosity

,mPa.s

Temperature, C

Produced Oil Viscosity Range of 20-10,000cp

P d d Fl id Vi it d D it T t


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Produced Fluid Viscosity and Density Test

Produced

Bitumen

Produced

Water


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P d d Bit Vi it A l i


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Produced Bitumen Viscosity Analysis

P d ti O ti


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Daily fluid production 70-85m3/d maximizing pump

performance

No gas production

Constant fluid levels of 110-130m above pump

1-3% oil cuts throughout the production cycle

Total oil volumes to be verified once the production tanks are

cleaned

Production Operations

Fib O ti M it i P d ti


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Fiber Optic Monitoring Production

Operations: Feb 23

Temperature gradient during production operationsTemperature gradient during production operations

Transition Zone

Top of Steam Column Bottom of Steam Column

Transition Zone

Emulsion

D/H pump set @ 520m

~100oC at 101 kPaa

Residual N2 Mixture

Production Cycle


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Production Cycle

0

10

20

30

40

50

60

70

80

90

100

0

10

20

30

40

50

60

70

80

90

100

110

120

130

140

150

2/16 2/21 2/26 3/3 3/8 3/13 3/18 3/23

ater/oilcuts(

)

productionrate(m

3/d)

Date

Fluid Production

Daily PRD Oil

Cut%

Water

Cut%

P d ti C l T t


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Production Cycle - Temperatures

0

10

20

30

40

50

60

70

80

90

100

0

10

20

30

40

50

60

70

80

90

100

110

120

130

140

150

2/16 2/21 2/26 3/3 3/8 3/13 3/18 3/23

ater/oilcuts(

)

productionrate(m

3/d)

Date

Fluid Production

Daily PRD Oil

Cut%

Water

Cut%

Reservoir cooling at ~5oC/d

Cumulative Fluid Production vs Temperature Loss


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Cumulative Fluid Production vs. Temperature Loss

0

20

40

60

80

100

120

140

0

500

1000

1500

2000

2500

3000

3500

0 10 20 30 40 50 60

e

pC

Days

VolumeM3

Volume Vrs BHT

c umul ati ve vol ume the rmo te mp Li ne ar (c umul ati ve vol ume ) Expon. (the rmo te mp)

Mar.08 Mar.18

March 17th Scheduled shut

down of production operations

Expected Produced Volume:

~2,000m3 , 50% recovery of

injected volume

Expected BHT: ~59oC


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Surface Information


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Scheme Facilities

Injection Facilities Plot Plan


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Injection Facilities Plot Plan

Production Facilities Plot Plan


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Production Facilities Plot Plan

Steam Injection Flow Diagram


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Steam Injection Flow Diagram

Production Operations Flow Diagram


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Production Operations Flow Diagram

Discussion of Measurement & Reporting


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Injection volumes measured by reading daily steam injection

volumes (roots meter)

Injected volumes verified through trucked water volumes and

water balance

Production volumes measured daily by monitoring field tanklevels

Production volumes verified through trucked volumes

Total produced oil volume to be verified upon cleaning of tanks

The water cuts measured through wellhead fluid sampling and

separation with centrifuge




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Production accounting department submissions to

Petroleum Registry of Alberta

Injected volumes based on water balance

Delivered oil production volumes as allocated at

approved drop off facilities

Water production volumes based on the production

fluid balance


Fluid Trucking


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Produced fluids trucked off site to approved facilities

Newalta, Red Earth

CCS, Slave Lake

Legacy, Wabasca

When required for drilling operations, water was trucked to 06-14-097-24W4 and 14-03-096-24W4

Prevented additional water withdrawals that would have been

required during drilling with losses

Fluid Trucking


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Environmental


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Compliance


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ERCB Approvals

Commercial Scheme Approval # 11379 November 27, 2009Facility License # F42557 December 10, 2010

Class IV Injection Well (D51) Approval # 24 January 25, 2011

Sustainable Resource Development Approvals

Surface Approval MSL 082313/LOC 080480 October 24, 2008

Caribou Protection Plan #NEB2-045-10/11-Harper November

3, 2010

Alberta Environment ApprovalsTDL 00280101-00-00 (20,000 m3) November 1, 2010

TDL 00280141-00-00 (30,000 m3) November 1, 2010

Compliance


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Reclamation Activities


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The Pad site will have topsoil and subsoil re-contoured to mimic

surrounding landscape

Course woody debris will be re-spread evenly over disturbed areas

and the lease will be left to naturally re-vegetate

On-going monitoring for weeds, erosion, and re-vegetation

performance will occur until a Reclamation Certificate has been

obtained

Sunshine Oil Sands Ltd confirms, to the best of its knowledge, that

all operations are in compliance with all conditions and approvals

related to the Harper CSS Pilot Project

Reclamation Activities


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Key Learnings and Future Plans

Key Learnings


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Grosmont C bitumen is thermally mobile

Successful in mobilizing and producing bitumen during this steam pilot

Grosmont C has high injectivity due to excellent permeability

Could not pressure up the formation

Maximum steam injection rates of 250m3/d CWE

High well deliverability, unable to draw down the fluid levels

Fiber optic temperature sensor has good resolution, allowing observations onfluid levels and downhole conditions

Can conclude injection and production to the lower porosity interval dueto uniform heating of fiber optic string

Able to see temperature changes in the wellbore, N2 blanket visible

Potential fluid level monitoring although highly interpretive

N2 blanket successfully insulated wellbore above steam injection interval

Key Learnings

Potential Design Improvements


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Reservoir Heterogeneity

Reservoir non-conformance challenges were indicated when there was no

pressure build-up during injection operations and was likely due to highlypermeable fractures and vugs

Shorter cycles might be required to optimize the thermal stimulation and

production cycles

Artificial Lift

Due to pre-production delays, production operations were only able to recover~50% of injected CWE volume from the formation

Maximum pump volumes of ~85m3/day were insufficient to draw down

wellbore fluid levels

Operating Improvements

Pre-steam production test to understand reservoir fluid dynamics

Cost effective water disposal required

Real time surface and down-hole pressure and temperature monitoring

Flow meters for all fluids including fuel

More time required for CSS cycles

Potential Design Improvements

Future Plans


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Evaluating options to produce remainder of injected water back next winter

Determine if there is a mobile water phase in the Grosmont formation

Evaluating potential for future cycles at the Harper Pilot location

Shorter injection cycles with a more aggressive production strategy

Amendment of current application and extension of pilot operations are required if

another cycle is to be executed at the 11-21-95-24W4 pilot location

Current steam flood experiments of Grosmont C 11-21-95-24W4 core will provide

greater understanding of potential recovery factors and residual oil saturations

Impacts of vugs and fractures on recoveries to be determined through CT scans

before and after steam flood tests

Future pilot projects experimenting with modern enhanced oil recovery techniques will

be evaluated

Future Plans

Contact Information


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Sunshine Oilsands Ltd.

Jason Hancheruk VP, Land & Regulatory Affairs

Suite 1400, 700 - 4th Avenue S.W.

Calgary, Alberta, Canada

T2P 3J4

Tel: +1 (403) 984-5144

Fax: +1 (403) 455-7674

Website: www.sunshineoilsands.com

Contact Information


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Harper Steam Injection SchemePerformance Review

March 22, 2011

Appendix


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Appendix B: Water Source


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pp

Appendix C: Trucked Fluids


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ppLocation Volume m

Trucking Ticket PO. Fluid Hauled In Hauled Out

Date Company Number Number Type Transfered From Transfered To Oil Water Other Oil Water Other

28-Jan Black Gold 27034 Water 11-21 14-3-96-24 18.0

29-Jan Black Gold 27264 Water 11-21 14-3-96-24 18.0

2-Feb Clean Harbours Water 11-21 14-3-96-24 45.0

4-Feb Casper 2527 Water 11-21 14-3-96-24 44.0

7-Feb Casper 2530 Water 11-21 14-3-96-24 22.0

9-Feb Casper 2651 Water 11-21 14-3-96-24 1.0

11-Feb Casper 2652 Water 11-21 14-3-96-24 20.015-Feb Casper 2654 Water 11-21 14-3-96-24 2.0

16-Feb Casper Water 11-21 14-3-96-24 61.0

17-Feb Casper 2657 Water 11-21 14-3-96-24 10.0

22-Feb Gibson 597055 Water 11-21 6-14-97-24 30.0

22-Feb Black Gold 27532 Water 11-21 6-14-97-24 10.0

23-Feb Gibson 6027977 Water 11-21 Newalta 25.0

23-Feb Casper 2626 Water 11-21 6-14-97-24 10.0

23-Feb Clean Harbours CH124728 Water 11-21 6-14-97-24 15.0

24-Feb Gibson 6027979 Water 11-21 Newalta 25.0

25-Feb Gibson 6288391 Water 11-21 Legacy 25.0












1-Mar Gibson 6288395 Water 11-21 CCS Slave Lake 25.0



3-Mar Gibson 6178526 Water 11-21 Legacy 25.0








5-Mar Gibson 6117226 Water 11-21 Legacy 25.05-Mar Gibson 6288503 Water 11-21 Legacy 26.0










19-Mar Black Gold 27348 Water 11-21 CCS Slave Lake 0.6

19-Mar Black Gold 27348 Solids 11-21 CCS Slave Lake 0.1

19-Mar Black Gold 27348 Oil 11-21 CCS Slave Lake 0.3

19-Mar Black Gold 28002 Water 11-21 CCS Slave Lake 4.4

19-Mar Black Gold 28002 Solids 11-21 CCS Slave Lake 0.4

19-Mar Black Gold 28002 Oil 11-21 CCS Slave Lake 3.2

Appendix D: Production Cycle


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pp y

Date TimeWater

Cut%

Total

BS&W%

Oil

Cut%

Wellhead

Temp C

Thermo

Couple

Temp C

Pump

SPM

Fluid On

Pump M

Joints to Fluid

9.6m/jt

Fluid

Level

m

Tank 1

VOL

Tank 2

VOL

Tank 3

VOL

Tank 4

VOL

2/17/2011 8:00 -5 110 0 0 0 0

2/17/2011 12:00 10 107.3 47.8 46 441.8

2/17/2011 16:00 15 158.7 38.24 47 451.4

2/17/2011 20:00

2/17/2011 0:00

2/17/2011 4:00

2/18/2011 8:00 -38 122.4 105.16 40 384.4 0 0 0 0

2/18/2011 10:00 5 115.8 105.16 40

2/18/2011 15:00 65 156.5 114.72 39

2/18/2011 18:30 60 60 40 70 173.4 143.4 36

2/18/2011 0:00

2/18/2011 4:00

2/19/2011 8:00 60 60 40 70 173.2 2.75 124.28 38 365.3 0 26 0 0

2/19/2011 12:00 60 60 40 70 174.8 2.75

2/19/2011 16:00 60 60 40 70 173.1 2.75

2/19/2011 20:00 60 60 40 80 174 2.75 114.72 39

2/19/2011 0:00

2/19/2011 4:00

2/20/2011 8:00 80 80 20 70 169.2 2.75 114.72 39 374.9 0 57 0 0

2/20/2011 12:00 95 95 5 83 168.8 3.5

2/20/2011 16:00 96 96 4 80 167.7 3.5 133.84 37

2/20/2011 20:00 80 165.8 3.5

2/20/2011 0:00

2/20/2011 4:00

2/21/2011 8:00 95 95 5 83 160.5 3.5 124.28 38 365.3 0 76 32 0

2/21/2011 12:00 96 96 4 93 160.2 3.75

2/21/2011 16:00 96 96 4 90 156.4 3.75

2/21/2011 20:00 96 96 4 84 155.8 3.5

2/21/2011 0:00

2/21/2011 4:00



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pp y

Date TimeWater

Cut%

Total

BS&W%

Oil

Cut%

Wellhead

Temp C

Thermo

Couple

Temp C

Pump

SPM

Fluid On

Pump M

Joints to Fluid

9.6m/jt

Fluid

Level

m

Tank 1

VOL

Tank 2

VOL

Tank 3

VOL

Tank 4

VOL

2/22/2011 8:00 96 96 4 82 152.3 3.5 133.84 37 355.8 0 98 24 0

2/22/2011 12:00 95 95 5 87 150.2 4

2/22/2011 16:00 96 96 4 89.4 149.1 4

2/22/2011 20:00 96 96 4 87 147.4 4

2/22/2011 0:00

2/22/2011 4:00

2/23/2011 8:00 97 97 3 91 143.4 4 133.84 37 355.8 0 100 24 0

2/23/2011 12:00 97 97 3 91.7 141.2 4.5

2/23/2011 16:00 97 97 3 91.4 140.1 5

2/23/2011 20:00 97 97 3 91.6 139.1 5

2/23/2011 0:00

2/23/2011 4:00

2/24/2011 8:00 97 97 3 90.8 134 5 133.84 37 355.8 0 112 90 02/24/2011 12:00 97 97 3 91.2 132.2 5.5

2/24/2011 16:00 97 97 3 90.5 129.7 5.5

2/24/2011 20:00 97 97 3 89.5 129.7 5.5

2/24/2011 0:00

2/24/2011 4:00

2/25/2011 8:00 97 97 3 89.5 129.7 5.5 133.84 37 355.8 0 112 90 0

2/25/2011 12:00 97 97 3 91.7 124.9 6

2/25/2011 16:00 97 97 3 92.6 123.3 6

2/25/2011 20:00 97 97 3 93.1 122.3 6

2/25/2011 0:00

2/25/2011 4:00

2/26/2011 8:00 97 97 3 79.9 120.9 4 133.84 37 355.8 0 112 90 0

2/26/2011 12:00 97 97 3 87.8 118.4 5

2/26/2011 16:00 97 97 3 88 117 5.5

2/26/2011 20:00 97 97 3 86.3 116.4 5.5

2/26/2011 0:00

2/26/2011 4:00


85/88



86/88


pp y

3/4/2011 8:00 97 97 3 78 93 5.5 114.72 39 374.9 0 113 116 0

3/4/2011 12:00 98 98 2 77 92 5.5

3/4/2011 16:00 98 98 2 77 92 5.5

3/4/2011 20:00 98 98 2 77 91 5.5

3/4/2011 0:00

3/4/2011 4:00

3/5/2011 8:00 98 98 2 75 89 5.5 114.72 39 374.9 0 105 116 0

3/5/2011 12:00 98 98 2 73 89 5.5

3/5/2011 16:00 98 98 2 72 88 5.5

3/5/2011 20:00 98 98 2 72 88 5.5

3/5/2011 0:00

3/5/2011 4:00

3/6/2011 8:00 85 0 114.72 39 374.9 0 80 80 03/6/2011 12:00 86 0

3/6/2011 16:00 86 0

3/6/2011 20:00 99 99 1 68 87 5.5

3/6/2011 0:00

3/6/2011 4:00

3/7/2011 8:00 99 99 1 70 83 5.5 114.72 39 374.9 0 121 79 0

3/7/2011 12:00 99 99 1 69 5.5

3/7/2011 16:00 99 99 1 69 5.5

3/7/2011 20:00 99 99 1 67 5.5

3/7/2011 0:00

3/7/2011 4:00

3/8/2011 8:00 99 99 1 66 81 5.5 114.72 39 374.9 0 126 79 0

3/8/2011 12:00 99 99 1 66 81 5.5

3/8/2011 16:00 99 99 1 66 80 5.5

3/8/2011 20:00 99 99 1 66 80 5.5

3/8/2011 0:00

3/8/2011 4:00

Date TimeWater

Cut%

Total

BS&W%

Oil

Cut%

Wellhead

Temp C

Thermo

Couple

Temp C

Pump

SPM

Fluid On

Pump M

Joints to Fluid

9.6m/jt

Fluid

Level

m

Tank 1

VOL

Tank 2

VOL

Tank 3

VOL

Tank 4

VOL



87/88


pp y

Date TimeWater

Cut%

Total

BS&W%

Oil

Cut%

Wellhead

Temp C

Thermo

Couple

Temp C

Pump

SPM

Fluid On

Pump M

Joints to Fluid

9.6m/jt

Fluid

Level

m

Tank 1

VOL

Tank 2

VOL

Tank 3

VOL

Tank 4

VOL

3/9/2011 8:00 99 99 1 67 78 5.5 114.72 39 374.9 0 109 79 0

3/9/2011 12:00 99 99 1 66 78 5.5

3/9/2011 16:00 99 99 1 63 77 5.5

3/9/2011 20:00 99 99 1 61 77 5.5

3/9/2011 0:00

3/9/2011 4:00

3/10/2011 8:00 99 99 1 63 76 5.5 114.72 39 0 107 65 0

3/10/2011 12:00 99 99 1 62 75 5.5

3/10/2011 16:00 99 99 1 59 75 5.5

3/10/2011 20:00 99 99 1 58 74 5.5

3/10/2011 0:00

3/10/2011 4:00

3/11/2011 8:00 99 99 1 58 73 5.5 114.72 39 374.9 0 114 65 0

3/11/2011 12:00 99 99 1 58 73 5.5

3/11/2011 16:00 99 99 1 58 72 5.5

3/11/2011 20:00 99 99 1 58 72 5.5

3/11/2011 0:00

3/11/2011 4:00

3/12/2011 8:00 99 99 1 62 71 5.5 114.72 39 374.9 0 84 20 0

3/12/2011 12:00 99 99 1 62 73 1.5

3/12/2011 16:00 99 99 1 62 73 1.5

3/12/2011 20:00 99 99 1 61 71 5.5

3/12/2011 0:00

3/12/2011 4:00

3/13/2011 8:00 99 99 1 58 69 5.5 124.28 38 365.3 0 112 0 0

3/13/2011 12:00 99 99 1 58 69 5.5

3/13/2011 16:00 99 99 1 57 68 5.5

3/13/2011 20:00 99 99 1 57 68 5.5

3/13/2011 0:00

3/13/2011 4:00

3/14/2011 8:00 99 99 1 53 67 5.5 114.72 39 374.9 0 117 0 0

3/14/2011 12:00 99 99 1 54 67 5.5 114.72

3/14/2011 16:00 99 99 1 53 67 5.5 114.72

3/14/2011 20:00 99 99 1 53 66 5.5 114.72

3/14/2011 0:00

3/14/2011 4:00



88/88

pp y

Date TimeWater

Cut%

Total

BS&W%

Oil

Cut%

Wellhead

Temp C

Thermo

Couple

Temp C

Pump

SPM

Fluid On

Pump M

Joints to Fluid

9.6m/jt

Fluid

Level

m

Tank 1

VOL

Tank 2

VOL

Tank 3

VOL

Tank 4

VOL

3/15/2011 8:00 99 99 1 57 65 5.5 114.72 39 374.9 0 124 0 0

3/15/2011 12:00 99 99 1 56 65 5.5

3/15/2011 16:00 99 99 1 56 65 5.5

3/15/2011 20:00 99 99 1 54 65 5.5

3/15/2011 0:00

3/15/2011 4:00

3/16/2011 8:00 99 99 1 53 64 5.5 114.72 39 374.9 0 129 0 0

3/16/2011 12:00 99 99 1 51 63 5.5

3/16/2011 16:00 99 99 1 50 63 5.5

3/16/2011 20:00 99 99 1 50 63 5.5

3/16/2011 0:00

3/16/2011 4:00

3/17/2011 8:00 99 99 1 51 62 5.5 114.72 39 374.9 0 79 0 0

3/17/2011 12:00

3/17/2011 16:00

3/17/2011 20:00

3/17/2011 0:00

3/17/2011 4:00

3/18/2011 8:00 65 114.72 39 374.9 0 11 0 0

3/18/2011 12:00

3/18/2011 16:00

3/18/2011 20:00

3/18/2011 0:00

3/18/2011 4:00

3/19/2011 8:00 65 105.16 40 384.4 0 0 0 0

3/19/2011 12:00

3/19/2011 16:00

3/19/2011 20:00

steaminjection design

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