Development of a Static Oil Sands Mine and … Tech...Extraction Reference Facility JANUARY 12, 2017...

Development of a Static Oil Sands Mine andExtraction Reference Facility

PRESENTED TO

Tetra Tech Canada Inc.Riverbend Atrium One, 115, 200 Rivercrest Drive SE

Calgary, AB T2C 2X5 CANADA

Tel 403.203.3355 Fax 403.203.3301

Canada’s Oil Sands Innovation Alliance

JANUARY 12, 2017

ISSUED FOR USE_REVISION 1

FILE: 704-ENV.CENV03071

Development of a Static Oil Sands Mine and Extraction Reference Facility_Rev1.docx

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DEVELOPMENT OF A STATIC OIL SANDS MINE AND EXTRACTION REFERENCE FACILITY

FILE: 704-ENV.CENV03071 | JANUARY 12, 2017 | ISSUED FOR USE_REVISION 1

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TABLE OF CONTENTS

1.0 INTRODUCTION.......................................................................................................................... 1

2.0 SCOPE......................................................................................................................................... 1

3.0 APPROACH................................................................................................................................. 2

3.1 Cogeneration .........................................................................................................................................3

3.2 Steps......................................................................................................................................................3

4.0 PARAFFINIC FROTH TREATMENT............................................................................................ 4

4.1 Paraffinic Material Flow .........................................................................................................................4

4.2 Paraffinic Energy Flow...........................................................................................................................5

5.0 NAPHTHENIC FROTH TREATMENT.......................................................................................... 5

5.1 Naphthenic Material Flow ......................................................................................................................5

5.2 Naphthenic Energy Flow........................................................................................................................6

6.0 GHG EMISSIONS CALCULATIONS............................................................................................ 6

7.0 FLOW DIAGRAMS ...................................................................................................................... 7

8.0 CLOSURE.................................................................................................................................... 8

LIST OF TABLES IN TEXT

Table 1: Project Team........................................................................................................................... 2

Table 2: Key Assumptions .................................................................................................................... 2

Table 3: Natural Gas Requirement (GJ/h Lower Heating Value – LHV) per Train ................................. 3

Table 4: Major Equipment Size ............................................................................................................. 3

Table 5: Key Parameters for PFT Material Flow.................................................................................... 4

Table 6: Key Parameters for NFT Material Flow ................................................................................... 5

Table 7: Supply Conditions for NFT Material Flow ................................................................................ 6

Table 8: Fugitive Emissions from Mine Face......................................................................................... 6

Table 9: Fugitive Emissions from Tailings Ponds by Paraffinic Froth Treatment Process...................... 6

Table 10: Fugitive Emissions from Tailings Ponds by Naphthenic Froth Treatment Process................. 7



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APPENDIX SECTIONS

APPENDICES

Appendix A

Appendix B

Material and Energy Flow Diagrams

Tetra Tech’s General Conditions



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LIMITATIONS OF REPORT

This report and its contents are intended for the sole use of Canada’s Oil Sands Innovation Alliance and their agents. Tetra Tech

Canada Inc. (Tetra Tech) does not accept any responsibility for the accuracy of any of the data, the analysis, or the

recommendations contained or referenced in the report when the report is used or relied upon by any Party other than Canada’s

Oil Sands Innovation Alliance, or for any Project other than the proposed development at the subject site. Any such unauthorized

use of this report is at the sole risk of the user. Use of this report is subject to the terms and conditions stated in Tetra Tech

Canada Inc.’s Services Agreement. Tetra Tech’s General Conditions are provided in Appendix B of this report.



1


1.0 INTRODUCTION

Tetra Tech Canada Inc. (Tetra Tech) was contracted by Canada’s Oil Sands Innovation Alliance (COSIA) to develop

a static block mass and energy flow for a typical oil sands mine (Tetra Tech File No.

704-ENVONG03396-01). The objective of this project was to create Excel spreadsheet block flow diagrams for

material and heat / energy for four scenarios. These diagrams will facilitate the evaluation of greenhouse gas (GHG)

reduction opportunities by providing a common basis of understanding for prospective technology developers. This

allows them to better frame and quantify the GHG reduction benefits of their technologies. The block material and

heat / energy diagrams are in a similar format as that used for the production of the COSIA Steam Assisted Gravity

Drainage (SAGD) templates.

This report was prepared for COSIA following the development of the flow diagrams to explain the process used to

develop them and their intended use. The report provides a summary of the scope of the project, the objectives and

the deliverables. A discussion of the methods used and the rationale for their selection is provided. Details regarding

the differences associated with Paraffinic Froth Treatment (PFT) and Naphthenic Froth Treatment (NFT) are

outlined and the GHG emissions calculation process is explained. The report concludes with a description of the

flow diagrams and the assumptions used to prepare them.

2.0 SCOPE

The objective of this project was to create four pairs of Excel spreadsheet block flow diagrams for material and

heat / energy for four scenarios considering PFT and NFT. The specific flow diagrams included:

PFT:

− High grade material and heat/energy flow diagrams in summer condition

− Low grade material and heat/energy flow diagrams in winter condition

NFT:

− High grade material and heat/energy flow diagrams

− Low grade material and heat/energy flow diagrams

The reference oil sands mine and extraction reference facility (hereafter called reference facility) is a fictitious

stand-alone mine excluding integration with either an upgrader or adjacent in situ operations. The reference facility

is based on a fixed size of 200,000 bbl/d neat bitumen.

All assumptions for the development of the reference oil sands mine were discussed with and agreed by Tetra Tech

and COSIA.

The project team to complete the four pairs of Excel spreadsheet block flow diagrams is presented in Table 1.



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Table 1: Project Team

Team Member Role

Nelson Lee, M.A.S., P.Eng. Project Manager

Ross Huddleston, M.E.Des. Senior Reviewer

Doug Cox, P.Eng. Senior Technical Advisor

Bruno Dion, P.Eng. Process Engineer

Min Si, M.N.R.M., GHG-V GHG Analyst

Judy Tai, M.A.S., P.Eng. GHG Analyst

3.0 APPROACH

Tetra Tech developed the material and energy flow diagrams for both high grade and low grade ore by PFT and

NFT processes based on publicly available information, mainly environmental impact assessment (EIA) studies.

Key assumptions for the reference facility are presented in Table 2.

Table 2: Key Assumptions

Parameter Reference Facility Source

Bitumen Density 1.007 t/m3 Teck Frontier 2015 Update

Solvent Density (PFT) 0.624 t/m3 Teck Frontier 2015 Update,

isopentane at 20°C

Diluent Density (NFT) 0.665 t/m3 Engineering Toolbox, Naphtha

Natural Gas HHV 40 MJ/m3 Fortis BC

Natural Gas LHV to HHV 1.1 Industrial Practice

Electric Energy Conversion 3.6 GJ/MWh

Solvent/Diluent Losses:

Bitumen producedLess than 0.4 % vol./vol. AER Directives

Solvent : Bitumen ratio – PFT 1.65 wt./wt. Industrial Practice

Diluent : Bitumen ratio – NFT 0.7 wt./wt. Industrial Practice

The major equipment for the PFT and NFT processes included two units of Gas Turbine Generation (GTG), two

units of Heat Recovery Steam Generators (HRSG) with duct burners, and auxiliary boilers. The natural gas

requirement for GTG and HRSG were sourced from the Imperial Oil Kearl Lake EIA and presented in Table 3.



3


Table 3: Natural Gas Requirement (GJ/h Lower Heating Value – LHV) per Train

Scenario GTG HRSG

High Grade 865 376

Low Grade 1,032 471

Note: Kearl EIA, one train is 123,000 bbl/d for high grade and 100,000 bbl/d for low grade

Approximate size per unit for each equipment configuration was also sourced from the Kearl Lake EIA and

presented in Table 4.

Table 4: Major Equipment Size

Equipment Approx. Size per Unit

GTG 85 MW

HRSG 292 MW

3.1 COGENERATION

The GHG credit for cogeneration was calculated as directed by COSIA (Personal Communication, Matt McCulloch,

August 12, 2016). The following approach was used:

Allocation to thermal output based on steam generation (assuming an 80% efficient boiler under Specified Gas

Emitters Regulation (SGER) to allocate emissions to the thermal output of cogeneration units.

Allocation to electrical output based on the difference between the cogeneration unit emissions (Gt as reported

under the SGER) and the deemed emissions from heat (Dh).

3.2 STEPS

The following steps were used to develop the flow diagrams.

1. Review of the publicly available information, including EIA studies, Alberta Energy Regulator (AER) reports,

SGER reports, etc.

2. Develop material balance sheets and energy consumption.

3. Prepare draft material flow and energy flow diagrams.

4. Review and comment on the draft diagrams by COSIA’s members.

5. Incorporate COSIA member’s comments and revision of the flow diagrams.

6. Final review of the revised diagrams by COSIA members and agreement to issue final flow diagrams.

7. Final review of flow diagrams issued to COSIA.



4


4.0 PARAFFINIC FROTH TREATMENT

The following EIA studies were reviewed by Tetra Tech to guide the development of the flow diagram for PFT.

Teck Frontier

Teck Frontier Project Updates (2015)

Total Joslyn North Mine

Total Joslyn North Mine Updates (2010)

Imperial Kearl Lake

Based on the Scope of Work set out by COSIA, Tetra Tech selected Joslyn North Mine Updates (Joslyn 2010

Update report, 2010) as the basis on which to develop the reference facility. The Joslyn 2010 Update report was

selected because it provided detailed fines content in the material balance sheets.

4.1 PARAFFINIC MATERIAL FLOW

The material flow for the reference facility was developed based on the Joslyn 2010 Update report; Figure 5.3-1 for

high grade summer condition; and Figure 5.3-3 for the low grade winter condition.

Tetra Tech adjusted the two material sheets by:

Removing froth storage;

Removing de-pentanizer and diluent storage;

Prorating the production rate to 200,000 bbl/d; and

Updating the bitumen recovery rate to be consistent with other EIA studies.

Tetra Tech considered the specific parameters for the secondary extraction process based on Tetra Tech’s

knowledge of industrial practices and publicly available information (Table 5).

Table 5: Key Parameters for PFT Material Flow

Parameter Reference Facility

Asphaltene Rejection Approx. 7% *

Asphaltene Content in bitumen product 12%

Solvent Losses: Bitumen Produced 0.3% vol./vol.

Solvent: Bitumen Ratio 1.65% wt./wt.

Water + Solids in Diluted Bitumen Products Less than 0.5%

* expressed as percent of bitumen product



5


4.2 PARAFFINIC ENERGY FLOW

To be consistent with material balance, Tetra Tech used the Joslyn 2010 Update report as the basis for natural gas

and diesel requirements (Table 5.4-3), then prorated these requirements to a static 200,000 bbl/d production

volume.

Cooler and exchanger duties (GJ/h) were modeled by Aspen HYSYS based on flow rates and temperature change.

Tetra Tech used the AER ST 39 reports for Kearl, 2014 electricity consumption data to estimate electricity

consumption for the reference facility. June to August was considered as the summer period for high grade ore,

electricity consumption for summer was estimated to be 3,114 MWh/d. January to March was considered as the

winter period for low grade ore, electricity consumption for winter was estimated to be 4,119 MWh/d.

5.0 NAPHTHENIC FROTH TREATMENT

This section provides a description for the development NFT material flow and energy flow diagrams. The following

EIA studies were reviewed by Tetra Tech to guide the development of the flow diagram for PFT.

Syncrude Mildred Lake – 1973

Alsands Oil Sands Mine – 1978

Suncor Steepbank Mine – 1996

Suncor Millennium – 1998

CNRL Horizon – 2002

5.1 NAPHTHENIC MATERIAL FLOW

The naphthenic material flow was developed based on the paraffinic material flow. Ore preparation and primary

extraction were considered to be equivalent for PFT and NFT. Tetra Tech considered the following parameters for

the secondary extraction process based on Tetra Tech’s knowledge of industrial practices and publicly available

information (Table 6).

Table 6: Key Parameters for NFT Material Flow

Parameter Reference Facility

Asphaltene Rejection 0%

Maltene Losses 2%

Diluent Losses: Bitumen Produced Less than 0.4% vol./vol.

Diluent: Bitumen Ratio 0.7% wt./wt.

Water + Solids in Diluted Bitumen Products 3%

Several adjustments were made to the NFT material flow parameters based on information provided by Mr. Oladipo

(Dipo) Omotoso of Suncor (Personal Communication, August 17, 2015).



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5.2 NAPHTHENIC ENERGY FLOW

The Suncor Steepbank and Millennium EIA reports provided thermal energy demand for extraction during average

conditions. The other EIA reports provided combined energy demand including both extraction and upgrading.

As Tetra Tech was not able to separate energy demand between the extraction plant and the upgrader, energy

demand for the NFT process was based on information from the Suncor Steepbank and Millennium EIA reports.

The supply conditions (temperatures) used for the NFT process are provided in Table 7.

Table 7: Supply Conditions for NFT Material Flow

Parameter Supply Conditions

Oil Sands Feed Temperature 1 °C

Make-up Water 10 °C

Diluent Feed 48 °C

6.0 GREENHOUSE GAS EMISSIONS CALCULATIONS

The GHG emissions from stationary combustion (natural gas) and mobile equipment (diesel) were calculated in

accordance with the Alberta SGER’s Technical Guidance for Completing Specified Gas Compliance Reports

(Version 7.0, January 2014) and Alberta Environment and Parks (AEP)’s Carbon Offset Emission Factor Handbook

(Version 1.0, March 2015). Cogeneration GHG emissions were calculated as per COSIA recommendations

(described in Section 4.1 of this report).

Fugitive emissions from mine face and tailings ponds were provided by COSIA, and are presented in Tables 8

through 10.

Table 8: Fugitive Emissions from Mine Face

CH4 (kg/m2/d) CO2 (kg/m2/d)

Low High Low High

High Grade 0 0.000294 0.0001333 0.007648

Low Grade 0 0.000904 0.000007085 0.0129

Table 9: Fugitive Emissions from Tailings Ponds by Paraffinic Froth Treatment Process


Low High Low High

Paraffinic

Biogenic1 0 0 0 0

Non-biogenic 0.00000024 0.000424 0.000743 0.009501

1 All existing PFT ponds are not yet biogenic.



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Table 10: Fugitive Emissions from Tailings Ponds by Naphthenic Froth Treatment Process


Low High Low High

NaphthenicBiogenic 0.0002933 0.028757 0.003504 0.029262

Non-biogenic 0.000000105 0.000832 0.001081 0.03645

7.0 FLOW DIAGRAMS

The material and energy flow diagrams are provided in Appendix A. The diagrams are developed using Excel

spreadsheets. The detailed material compositions in the material flows are provided in the spreadsheets, including

maltene, asphaltene, water, sand, fines, and diluent/solvent. The total energy demand with energy consumption

distribution for both NFT and PFT is included in the material and energy diagrams. The key assumptions and

variables are highlighted in yellow in the spreadsheet.



8


8.0 CLOSURE

We thank COSIA for the opportunity to assist in advancing the understanding of this subject and look forward to

further development of this valuable process. We trust this report meets your present requirements. If you have any

questions or comments, please contact the undersigned.

Respectfully submitted,

Tetra Tech Canada Inc.

Prepared by:

Min Si, M.N.R.M., CEM

Energy and GHG Analyst

Direct Line: 403.723.1565

[email protected]

Prepared by:

Bruno Dion, P.Eng.

Process Engineer


[email protected]

Reviewed by:

Ross Huddleston, M.E.Des., EP(CEA).

Senior Consultant


[email protected]




REFERENCES

Quantifying land use of oil sands production: a life cycle perspective (Sarah M Jordaan, David W Keith, and BradStelfox, Environmental Research Letters 2009 (4), 024004

Heavy Crude Oils: From Geology to Upgrading: an Overview. Alain-Yves Huc, 6.2.3.3 Upgrading

Pembina Institute Forecasting the impacts of oilsands expansion June 2013, Jennifer Grant, Eli Angen and SimonDyer




APPENDIX A

MATERIAL AND ENERGY FLOW DIAGRAMS

This is a generic and hypothetical mine and extraction facility developed by COSIA. While representative, it is not based on any one facility.Recovery and solvent loss is based on Alberta Energy Regulator requirements.

COSIA Mining & Extraction: High Grade - Naphthenic Froth Treatment - Energy FlowOre Grade wt%Fine Contents wt%Waste to Ore wt%

Processing Plant80 °C

45 °CMine Face 1 °C Ore Preparation 45 °C Primary ExtractionTruck and Shovel 50 °C 50 °C Stripping Steam Legend

78 GJ/h BitumenDiesel Hydrotransport Pump Water

478 GJ/h SteamFuel gas

Deaerated Froth Pump DiluentTailing

AbbreviationsPSC Tailing Pump BFW Boiler Feed Water

CW Cooling WaterCWR Cooling Water Return

225 °C GTG Gas Turbine GeneratiorHHV High Heating ValueHRSG Heat Recovery Steam GeneratorLPS Low Pressure Steam

Diluent Diluent Storage 48 °C MPS Medium Pressure Steam48 °C NRU Naphtha Recovery Unit

Diluent Feed / MPS PSC Primary Separation CellExchanger Duty PW Process Water

199 GJ/hEnergy Output SummaryCogen GTG Electricity

HRSG BFW PreheatingSteam

84 °C Cogen LossesSubtotal - Cogen

99 °C Boilers Steam200,000 bbl of Bitumen/d Boiler Losses

Subtotal - BoilersTotal

Stripping Steam112 GJ/h Flue Gas

Tailing Pond Natural Gas HHVExcess air @ 13% O2 in CogenExcess O2

NRU Tailing Pump Cogen Flue GasCW (Cold) CWR (Warm) CO2 in Flue Gas from Cogen

30 °C 60 °C H2O in Flue Gas from CogenReclaimed Water 10 °C Boiler Flue Gas

CO2 in Flue Gas from BoilersH2O in Flue Gas from Boilers

Condensate 186 °C Flue Gas Temperature - Acid Dew Point LimitFlue Gas - Max. without Economizer

Make Up Water Raw Water Pond Recycled Water 10 °C 53 °C 59 °C 80 °C Hot Water Tank10 °C 10 °C Pond 10 °C 80 °C Exchanger

PW/CW Exchanger Duty PW/Condensate PW/LPS Process Water / Cooling WaterGJ/h Exchanger Duty 255 GJ/h Exchanger Duty Process Water / Condensate

GJ/h Process Water / LPS62 °C Diluent Feed / MPS

10 °C Warm Water Tank45 °C Energy Consumption Summary

99 °C GTG10 °C HRSG

Cogen Losses Building Heating and Flare68 °C 333 GJ/h Boilers

Diesel51 °C Boiler Losses Energy Intensity (GJ / bbl bitumen produced)

MPS Output 25 GJ/h Electricity Generated85% Efficiency 389 GJ/h Electricity Consumed

Cogen Energy Output Auxilary Boiler 266 GJ/h MPSElectricity GJ/h Electricity GHG Emissions Summary

127 MW GJ/h BFW Preheating Stationary Combustion & FlaringGJ/h Steam Mobile Equipment

GTG Duct burner HRSG GJ/h LPS Output Fugitive Mine 0.0001 - 0.0150921 GJ/h Fugitive Pond 0.0119 - 0.8054

GTG Duct Burner HRSG Flue Gas LPS Total Cogen Emissons (Gt)Natural Gas Required GJ/h GJ/h e3m3/h Boilers Boilers Flue Gas Deemed emissions from Heat by Cogen (DH)

GJ/h HHV m3/h m3/h CO2 vol.% GJ/h 147 e3m3/h Deemed emissions from Electricity by Cogen (DE)m3/h Unit Unit H2O vol.% m3/h 9% CO2 vol.% MPS LPSe3m3/sd 121 - 274 °C Efficiency 17% H2O vol.% 100 % Quality 90 % Quality Project: Static Reference Oil Sands Mine and Extraction Reference Facility

unit 121 - 274 °C °C °C Case: Naphthenic - High Grade Revision: V 1.6Natural Gas kPag kPag Owner: COSIA

10 °C 366 GJ/h T/h Stripping Steam T/h Date:Space Heating T/h Processing Heating Energy / Heat FlowPurge Gas to Flare High Temperature Extraction, High Grade, Average Condition

71,9091,726

80 °C

921

38,678 16,8122

2917,27391.5%

2,8766721,547

1,044

457

1,044386

448

5002,069

10404-Oct-1568

MWH/d

°C

1,879255921199

Duty (GJ/h)

Natural Gas

kg CO2e/m2/dkg CO2e/m2/d

t CO2e/d

3,329827

2,569

274

t CO2e/d

GJ/bbl

1211.74.3

2

4

1,879

225 2102,100 1,050

Cogen Facility

2,6604%7%

MWH/d

t CO2e/d

1,547 928GJ/h e3m3/d

6723662914780.40

3,0443,600

4032201750.3

t CO2e/dt CO2e/d

1,547Input (GJ/h) Output (GJ/h)

2,220

291

457

40

e3m3/h

672

291

3861,044333

2,22026625

291

1479%

MJ/m3

vol.%vol.%

°C

%e3m3/h

2,511 2,511

4% vol.%7% vol.%

%179%13%

2,660

17%121

Centrifuge 84 °C

NRU

Diluted Bitumen

Inclined Plate Separator 84 °C


COSIA Mining & Extraction: Low Grade - Naphthenic Froth Treatment - Energy FlowOre Grade wt%Fine Contents wt%Waste to Ore wt%

Processing Plant80 °C

45 °CMine Face 1 °C Ore Preparation 45 °C Primary ExtractionTruck and Shovel 50 °C 50 °C Stripping Steam Legend

90 GJ/h BitumenDiesel Hydrotransport Pump Water

684 GJ/h SteamFuel gas

Deaerated Froth Pump SolventTailing

AbbreviationsPSC Tailing Pump BFW Boiler Feed Water

CW Cooling WaterCWR Cooling Water Return

225 °C GTG Gas Turbine GeneratiorHHV High Heating ValueHRSG Heat Recovery Steam GeneratorLPS Low Pressure Steam

Diluent Diluent 48 °C MPS Medium Pressure Steam48 °C Storage NRU Naphtha Recovery Unit

Diluent Feed / MPS PSC Primary Separation CellExchanger Duty PW Process Water

335 GJ/hEnergy Output Summary Input (GJ/h) Output (GJ/h)Cogen GTG Electricity

HRSG BFW Preheating84 °C Steam

Cogen LossesSubtotal - Cogen

99 °C Boilers Steam200,000 bbl of Bitumen /d Boiler Losses

Subtotal - BoilersTotal

Stripping Steam112 GJ/h Flue Gas

Tailing Pond Natural Gas HHVExcess air @ 13% O2Excess O2

NRU Tailing Pump Cogen Flue GasCW (Cold) CWR (Warm) CO2 in Flue Gas from Cogen

30 °C 60 °C H2O in Flue Gas from CogenReclaimed Water 10 °C Boiler Flue Gas

CO2 in Flue Gas from BoilersH2O in Flue Gas from Boilers

Condensate 186 °C Flue Gas Temperature - Acid Dew Point LimitFlue Gas - Max. without Economizer

Make Up Water Raw Water Pond Recycled Water 10 °C 55 °C 61 °C 80 °C Hot Water Tank10 °C 10 °C Pond 10 °C 80 °C Exchanger

PW/CW Exchanger Duty PW/Condensate PW/LPS Process Water / Cooling WaterGJ/h Exchanger Duty 368 GJ/h Exchanger Duty Process Water / Condensate

GJ/h Process Water / LPS61 °C Diluent Feed / MPS


99 °C GTG10 °C HRSG


Diesel51 °C Boiler Losses Energy Intensity (GJ / bbl bitumen produced)

MPS Output 37 GJ/h Electricity GeneratedCogen Facility 85% Efficiency 537 GJ/h Electricity Consumed

Cogen Energy Output Auxilary Boiler GJ/h MPSElectricity GJ/h Electricity GHG Emissions Summary


GTG Duct burner HRSG GJ/h LPS Output Fugitive Mine 0.0001 - 0.0150GJ/h Fugitive Pond 0.0119 - 0.8054

GTG Duct Burner HRSG Flue Gas LPS Total Cogen Emissons (Gt)Natural Gas Required GJ/h GJ/h e3m3/h Boilers Boilers Flue Gas Deemed emissions from Heat by Cogen (DH)

GJ/h HHV m3/h m3/h CO2 vol.% GJ/h 218 e3m3/h Deemed emissions from electricity by Cogen (DE)m3/h Unit Unit H2O vol.% m3/h 9% CO2 vol.% MPS LPSe3m3/sd 121 - 274 °C Efficiency 17% H2O vol.% 100 % Quality 90 % Quality Project: A Static Oil Sands Mine and Extraction Reference Facility

unit 121 - 274 °C °C °C Case: Naphthenic - Low Grade Revision: V 1.6Natural Gas kPag kPag Owner: COSIA

10 °C 414 GJ/h T/h Stripping Steam T/h Date:Space Heating T/h Processing Heating Energy / Heat FlowPurge Gas to Flare High Temperature Extraction, Low Grade, Average Condition

40 MJ/m3

4%7%2189%

121

%%

e3m3/hvol.%vol.%

e3m3/hvol.%vol.%

°C

1,074

3,164431

4313,595

630597

1,463475

3,16439437

4313,595

2,4062 2

91.5%

682

t CO2e/dt CO2e/d

100,231 10,778

kg CO2e/m2/dkg CO2e/m2/d

t CO2e/dt CO2e/d

26,838 4314,009 t CO2e/d1,0742,090

1,320

7%

4

04-Oct-15

225 2102,100 1,050

72 642175

3,0581,320

920

1.5

80 °C

4,6401,184

GJ/h

6840.56

4,1983,600

Natural Gas

2,0901,074414431

3,796

180%13%

17%

1,463

2,090

630597

1,463

394

52,257

MWH/dMWH/d

3,6612,9793,796

4%

e3m3/d1,254644249259

GJ/bbl

274 °C

0.4

Duty (GJ/h)3,058368

1,320335

NRU

Diluted Bitumen


Centrifuge 84 °C


COSIA Mining & Extraction: High Grade - Naphthenic Froth Treatment - Material FlowOre Grade wt%Fine Contents wt%Waste to Ore wt%

Ore Preparation: Conditioning, Crushing and Conveying

Mine Face T/h Crusher Conveyor Feed Rotary BreakerTruck and Shovel 1 °C System 50°C RejectsBitumen 12 wt% Bitumen 4 wt%Water 3 wt% Water 6 wt%Solids 85.6 wt% Solids 90.8 wt%

T/h Hot Process Water 80 °C T/hGland Cooling Water T/h T/h Breaker RejectsWarm Dilution Water 45 °C T/h T/h

Primary Extraction 50 °C Vent to atmosphereT/h

Caustic Stripping Steam 28 T/h Deaerator 40-50 °CNaOH Flotation Froth

Deaerated Froth 77 °C MiddlingsT/h

Bitumen 58 wt%Water 32 wt% Middlings Displacement

Cooling Water T/h Solids 10 wt%

PSC TailingT/h

Bitumen 0.1 wt%Secondary Extraction- Froth Treatment Water 58 wt%

Solids 42 wt%Diluent 955 T/h T/h

IPS CentrifugeWarm Water 19 T/h T/h T/h

59 wt% Bitumen 58 wt% Bitumen1.5 wt% Water 3 wt% Water

Diluent 0 wt% Solids 1 wt% Solids48 °C 0.7 wt/wt Diluent : Bitumen 0.7 wt/wt Diluent : Bitumen

Diluent:Bitumen 0.7 wt / wtDiluent Loss:Bitumen 0.4 vol. / vol.

T/h28 wt% Bitumen Legend38 wt% Water Bitumen12 wt% Solids Water

Steam70 T/h NRU Tailing T/h Fuel Gas

T/h 2 wt% Bitumen DiluentStripping Steam 40 T/h 2 wt% Bitumen 69.8 wt% Water Tailing

76 wt% Water 21 wt% Solids22 wt% Solids 7 wt% Diluent Abbreviations

0.4 wt% Diluent BFW Boiler Feed WaterT/h Bitumen GTG Gas Turbine Generatiorbbl Bitumen HHV High Heating Value

T/h Tailing T/h Diluent HRSG Heat Recovery Steam GeneratorRecycled Water Reclaimed Water T/h Tailing Pond wt / wt Diluent :Bitumen LPS Low Pressure Steam

10 °C 85 % Process Water Recycled vol / vol Diluent : Bitumen MPS Medium Pressure Steamwt% Asphaltene in Bitumen NRU Naphtha Recovery Unitwt% Solids + Water PSC Primary Separation Cell

T/h LossesT/h Bitumen Recovery Summary

Utilities Ore PreparationRaw Water Pond 202 T/h 470 T/h Recovered MPS Primary ExtractionWater treatment Condensate GTG 100 % Quality Froth Treatment (without rejected asphaltenes)

GJ/h kPag Total Bitumen Recoverym3/h °C Asphaltenes Rejection

T/h MW T/h Stripping Steam Total Bitumen Recovery (with rejected asphaltenes)BFW Unit T/h Process Heating

T/h Duct Burner MPS LPS Utility Steam Water Summary (T/H)Make-up Water mg/L TDS GJ/h HRSG 2 Unit 90 % Quality Cooling Water

10 °C mg/L Silica m3/h Efficiency 85 % kPag Heated Watermg/L Hardness Unit °C Reclaimed Water

Make-up Water mg/L TOC GTG Duct Burner HRSG T/h Raw Watermg/L TDS BFWmg/L Silica Boiler Blowdownmg/L Hardness Make-Up Watermg/L TOC Recovered Condensate 470 T/h Boilers LPS Condensate Return

Fresh Water : Bitumen GJ/hvol./vol. Natural Gas Required Space Heating m3/h Project: Static Oil Sands Mine and Extraction Reference Facility

GJ/h Purge Gas to Flare 91.5 % Efficiency Case: Naphthenic - High Grade Revision: V 1.3m3/h GJ/h unit Owner: COSIA

Natural Gas e3m3/sd Auxilary Boiler Date:Boiler Blowdown Material Flow

T/h High Temperature Extraction, High Grade, Average Condition

6

3198.9%

1,977

1,019

928

T/h

23,623

24 5,045412

1211.7

4.3

12,187

17,072227

2,357

5,372

3,514

12,051

2,100225

2

2

68

1,050

448

67216,812

27-Sep-15366

7,273291

1,72671,909

95.2%0.0%

95.2%

8,5795,599

127

2,328

Process Water

12,0512,12720220

104

210515

1,354

1,354

470

2,876

98.0%98.2%

928

173

1,339200,000

8810.7

1,54738,678

20

1.8

1049

203.96

4

14,178

6,05934

202

2,328

2,127

6,0597

0

1

Primary Separation Cell

Flotation & Cyclone

Centrifuge 84 °C


Diluted Bitumen

NRU


COSIA Mining & Extraction: Low Grade - Naphthenic Froth Treatment - Material FlowOre Grade wt%Fine Contents wt%Waste to Ore wt%


Mine Face T/h Crusher Conveyor Feed Rotary BreakerTruck and Shovel 1 °C System 50°C RejectsBitumen 9 wt% Bitumen 3 wt%Water 6 wt% Water 4 wt%Solids 85 wt% Solids 92 wt%


Primary Extraction 50 °C Vent to atmosphereT/h

Caustic Stripping Steam 32 T/h Deaerator 40-50 °CNaOH Flotation Froth




PSC TailingT/h


Solids 37 wt%Diluent 955 T/h T/h

IPS CentrifugeWarm Water 19 T/h T/h T/h

59 wt% Bitumen 58 wt% Bitumen1.5 wt% Water 3 wt% Water

Diluent 0 wt% Solids 1 wt% Solids48 °C 0.7 wt/wt Diluent:Bitumen 0.7 wt/wt Diluent:Bitumen

Diluent:Bitumen 0.7 wt/wtDiluent Loss:Bitumen 0.4 vol./vol.

T/h27 wt% Bitumen Legend38 wt% Water Bitumen15 wt% Solids Water20 wt% Diluent Steam

70 T/h NRU Tailing T/h Fuel GasT/h 2 wt% Bitumen Diluent

Stripping Steam 40 T/h 2 wt% Bitumen 66 wt% Water Tailing71 wt% Water 25 wt% Solids26 wt% Solids 6 wt% Diluent Abbreviations0.3 wt% Diluent BFW Boiler Feed Water

T/h Bitumen GTG Gas Turbine Generatiorbbl Bitumen HHV High Heating Value

T/h Tailing T/h Diluent HRSG Heat Recovery Steam GeneratorRecycled Water Reclaimed Water T/h Tailing Pond wt / wt Diluent :Bitumen LPS Low Pressure Steam

10 °C 85 % Process Water Recycled vol / vol Diluent : Bitumen MPS Medium Pressure Steamwt% Asphaltene in Bitumen NRU Naphtha Recovery Unitwt% Solids + Water PSC Primary Separation Cell



GJ/h kPag Total Bitumen Recoverym3/h T/h Stripping Steam Asphaltenes Rejection

T/h MW T/h Process Heating Total Bitumen Recovery (with rejected asphaltenes)BFW Unit

T/h Duct Burner MPS LPS Water Summary (T/H)Make-up Water mg/L TDS GJ/h HRSG 2 Unit 90 % Quality Cooling Water

10 °C mg/L Silica m3/h Efficiency 85 % kPag Heated Watermg/L Hardness Unit T/h Reclaimed Water

Make-up Water mg/L TOC GTG Duct Burner HRSG Raw Watermg/L TDS LPS Utility Steam BFWmg/L Silica Water Heating Boiler Blowdownmg/L Hardness Make-Up Watermg/L TOC Recovered Condensate 694 T/h Boilers LPS Condensate Return

Fresh Water : Bitumen GJ/hvol./vol. Natural Gas Required Space Heating m3/h Project: COSIA: A Static Oil Sands Mine and Extraction Reference Facility

GJ/h Purge Gas to Flare 91.5 % Efficiency Case: Naphthenic - Low Grade Revision: V 1.3m3/h GJ/h unit Author Tetra Tech EBA Inc.


T/h High Temperature Extraction, Low Grade, Average Condition

23928

3,626694

98.2%

6,84915,73119,1933,387

92.3%98.2%89.0%

0%89%

1,354

6

2,479

9201.2

17,451

35 9,267323 863

6,445 26,213

6,526

36,730

3

1,354

928 928T/h

2,099

1,1701,141

1,339200,000

8810.7117

72

44

2,090 2,100

3,654 175 175

22,58019,193

3,387

267

52,257

2

6,0597

203.96

431

414 4

10,778

28

Process Water

2.74,009

100,2312,406 27-Sep-15

1,0500 2 642

515

6,059 1,07434 26,838


Flotation & Cyclone

FSU 80 °C

Bitumen


Flotation & Cyclone

Centrifuge 84 °C


Diluted Bitumen

NRU


COSIA Mining & Extraction: High Grade - Paraffinic Froth Treatment - Energy FlowOre Grade wt%Fine Contents wt%Waste to Ore wt%

Processing Plant78 °C Legend

50 °C BitumenMine Face 5 °C Ore Preparation 50 °C Primary Extraction WaterTruck and Shovel 50 °C 50 °C Stripping Steam Steam

70 GJ/h Fuel gasDiesel Hydrotransport Pump Solvent

515 GJ/h Tailing

Deaerated Froth Pump AbbreviationsBFW Boiler Feed WaterCW Cooling WaterCWR Cooling Water Return

CWR PSC Tailing Pump FSU Froth Settling UnitGTG Gas Turbine Generator

CW HHV High Heating Value225 °C HRSG Heat Recovery Steam Generator

LPS Low Pressure SteamMPS Medium Pressure SteamPSC Primary Separation Cell

Make Up Solvent Solvent Storage PW Process Water20 °C SRU Solvent Recovery Unit

SRU/MPS Exchanger Duty TSRU Tailing Solvent Recovery UnitStrippingg Steam 199 GJ/h

76 GJ/h Energy Output Summary Input (GJ/h)99 °C Cogen GTG Electricity

HRSG BFW PreheatingSteam

103 °C 38 °C Cogen LossesCooler Duty Subtotal - Cogen357 GJ/h Boilers Steam

CW CWR Boiler LossesSubtotal - BoilersTotal

Strippingg Steam Flue Gas - Based on Stochiometric CombustionCW CWR 89 GJ/h Natural Gas HHV

Tailing Pond Excess air @ 13% O2Excess O2Cogen Flue Gas

TSRU Tailing Pump CO2 in Flue Gas from CogenCW (Cold) CWR (Warm) H2O in Flue Gas from Cogen

30 °C 60 °C Boiler Flue GasReclaimed Water 25 °C CO2 in Flue Gas from Boilers

H2O in Flue Gas from BoilersFlue Gas Temperature - Acid Dew Point Limit

Condensate 186 °C Flue Gas - Max. without Economizer

Make Up Water Raw Water Pond Recycled Water 49 °C 56 °C 78 °C Hot Water Tank Exchanger & Cooler25 °C 25 °C Pond 25 °C 78 °C Process Water / Cooling Water

PW/CW Exchanger Duty PW/Condensate PW/LPS Process Water / CondensateGJ/h Exchanger Duty 301 GJ/h Exchanger Duty Process Water / LPS

GJ/h SRU Feed / MPS57 °C Cooler


99 °C GTGHRSG


Diesel51 °C Boiler Losses Energy Intensity (GJ per bbl of bitumen produced)

MPS Output 64 GJ/h Electricity GeneratedCogen Facility 85% Efficiency 434 GJ/h Electricity Consumed

Cogen Energy Output Auxillary Boiler GJ/h MPSElectricity GJ/h Electricity GHG Emissions Summary

127 MW GJ/h BFW Preheating Stationary Combustion & Flaring t CO2e/dGJ/h Steam Mobile Equipment t CO2e/d

GTG Duct burner HRSG GJ/h LPS Output Fugitive Mine 0.0001 - 0.0150 kg CO2e/m2/dGJ/h Fugitive Pond 0.0007 - 0.0201 kg CO2e/m2/d

GTG Duct Burner HRSG Flue Gas LPS Total Cogen Emissons (Gt) t CO2e/dNatural Gas Required GJ/h GJ/h e3m3/h Boilers Boilers Flue Gas Deemed emissions from Heat by Cogen (DH) t CO2e/d

GJ/h HHV m3/h m3/h CO2 vol.% GJ/h 380 e3m3/h Deemed emissions from Electricity by Cogen (DE) t CO2e/dm3/h Unit Unit H2O vol.% m3/h 9% CO2 vol.% MPS LPSe3m3/sd 121 - 274 °C Efficiency 17% H2O vol.% 100 % Quality 90 % Quality Project: Static Oil Sands Mine and Extraction Reference Facility

unit 121 - 274 °C °C °C Case: Paranffic - High Grade Revision: V 2.3.9Natural Gas kPag kPag Owner: COSIA

25 °C 604 GJ/h T/h Stripping Steam T/h Date:Space Heating T/h Processing Heating Energy / Heat FlowPurge Gas to Flare High Temperature Extraction, High Grade, Summer Condition

2,145

78 °C

1,051

38,678 16,8122

75118,78091.5%

3,57589,376

1211.94.3

2

6

1,108

25 °C

1,547 672

457633797

797

2,6604%7%

e3m3/d

04-Oct-15

2252,10010253

2101,050511

515

9284033634510.3

3,142

2,069500

4,137892

1,051

Natural Gas

687

Output (GJ/h)

333

380 e3m3/h9% vol.%

17% vol.%

2,660 e3m3/h4% vol.%7% vol.%

40 MJ/m3179 %

1,547 457672 633

797

121 °C

2,569

MWH/d

1,547672604751

Duty (GJ/h)1,108301

1,051199

GJ/bbl3,044 MWH/d0.49

357

GJ/h

274 °C

751 7512,971 2,971

2,220 2,220751 687

64

13 %

SRU 215 °C FSU 70 - 90 °C

TSRU 90 °C

Bitumen 200,000 bbl/d


COSIA Mining & Extraction: Low Grade - Paraffinic Froth Treatment - Energy FlowOre Grade wt%Fine Contents wt%Waste to Ore wt%

Processing Plant Legend85 °C Bitumen

45 °C WaterMine Face -3 °C Ore Preparation 45 °C Primary Extraction SteamTruck and Shovel 50 °C 50 °C Stripping Steam Fuel gas

80 GJ/h SolventDiesel Hydrotransport Pump Tailing

735 GJ/hAbbreviations

Deaerated Froth Pump BFW Boiler Feed WaterCW Cooling WaterCWR Cooling Water ReturnFSU Froth Settling Unit

CWR PSC Tailing Pump GTG Gas Turbine GeneratorHHV High Heating Value

CW HRSG Heat Recovery Steam Generator225 °C LPS Low Pressure Steam

MPS Medium Pressure SteamPSC Primary Separation CellPW Process Water

Make Up Solvent Solvent Storage SRU Solvent Recovery Unit2 °C TSRU Tailing Solvent Recovery Unit

SRU/MPS Exchanger DutyStripping Steam 368 GJ/h Flue Gas

73 GJ/h Natural Gas HHV99 °C Excess air @ 13% O2

Excess O2Cogen Flue Gas

100 °C 38 °C CO2 in Flue Gas from CogenCooler Duty H2O in Flue Gas from Cogen341 GJ/h Boiler Flue Gas

CW CWR CO2 in Flue Gas from BoilersH2O in Flue Gas from BoilersFlue Gas Temperature - Acid Dew Point LimitFlue Gas - Max. without Economizer

Stripping SteamCW CWR 101 GJ/h Energy Output Summary

Tailing Pond Cogen GTG ElectricityHRSG BFW Preheating

SteamTSRU Tailing Pump Cogen Losses

CW (Cold) CWR (Warm) Subtotal - Cogen30 °C 60 °C Boilers Steam

Reclaimed Water 2 °C Boiler LossesSubtotal - BoilersTotal

Condensate 186 °CExchanger & Cooler

Make Up Water Raw Water Pond Recycled Water 42 °C 52 °C 85 °C Hot Water Tank Process Water / Cooling Water2 °C 2 °C Pond 2 °C 85 °C Process Water / Condensate

PW/CW Exchanger Duty PW/Condensate PW/ LPS Process Water / LPSGJ/h Exchanger Duty 544 GJ/h Exchanger Duty Treated Water / LPS

2 °C GJ/h SRU / MPS53 °C Cooler

71 °C 210 °C 2 °C Warm Water Tank45 °C Energy Consumption Summary

Treated Water/ 36 GJ/h 99 °C Natural Gas GTGLPS Exchanger Duty HRSG

25 °C Cogen Losses Building Heating and Flare60 °C 475 GJ/h Boilers

Diesel43 °C Boiler Losses Energy Intensity (GJ per bbl of bitumen produced)

MPS Output 182 GJ/h Electricity Generated85% Efficiency 623 GJ/h Electricity Consumed

Cogen Energy Output Auxilary Boiler GJ/h MPSElectricity GJ/h Electricity GHG Emissions Summary


GTG Duct burner HRSG GJ/h LPS Output Fugitive Mine 0.000007-0.036GJ/h Fugitive Pond 0.0007 - 0.0201

GTG Duct Burner HRSG Flue Gas LPS Total Cogen Emissions (Gt)Natural Gas Required GJ/h GJ/h e3m3/h Boilers Boilers Flue Gas Deemed emissions from Heat by Cogen (DH)

GJ/h HHV m3/h m3/h CO2 vol.% GJ/h e3m3/h Deemed emissions from Electricity by Cogen (DE)m3/h Unit Unit H2O vol.% m3/h CO2 vol.% MPS LPSe3m3/sd 121 - 274 °C Efficiency H2O vol.% 100 % Quality 90 % Quality Project: Static Oil Sands Mine and Extraction Reference Facility

unit 121 - 274 °C °C °C Case: Paraffinic - Low Grade Revision: V 2.3.9Natural Gas kPag kPag Owner: COSIA

2 °C 949 GJ/h T/h Stripping Steam T/h Date:Space Heating T/h Processing Heating Energy / Heat FlowPurge Gas to Flare High Temperature Extraction, Low Grade, Winter Condition

40 MJ/m3

2,090

3,164

2,143

630

vol.%17% vol.%121 °C

2,143

1,074

Output (GJ/h)Input (GJ/h)

5,307

MWh/dMWh/d

2,143 1,286735

36368

1,840

Duty (GJ/h)

Cogen Facility

156,398 53,5743,754

291.5%

2

6

04-Oct-15

1,876

17%

1,522538

538

1961

3,7964%7%

1,0839%

630

6,256 26,838 2,143

2,1941,840

85 °C

1,074

7,2401,274

3,661

682

t CO2e/dt CO2e/d

kg CO2e/m2/d

t CO2e/d

192

225 2102,100 1,050111 895

4,119

920

1.5

kg CO2e/m2/dt CO2e/dt CO2e/d2,090

52,2571,074

180% %13% %

3,796 e3m3/h4% vol.%7% vol.%

1,083 e3m3/h9%

5442,194

2,979

GJ/h e3m3/d

274 °C

3,164

2,143

644949 570

1,2542,090

341

0.50.84 GJ/bbl

1,961182

1,522538475

5,307

4,198

SRU 215 °C FSU 70 - 90 °C

TSRU 90 °C

Bitumen 200,000 bbl/d


COSIA Mining & Extraction High Grade - Paraffinic Froth Treatment - Material FlowOre Grade wt%Fine Contents wt%Waste to Ore wt%


Mine Face T/h Crusher Conveyor Feed Rotary BreakerTruck and Shovel 5 °C System 50°C RejectsBitumen 12 wt% Bitumen 3 wt%Water 3 wt% Water 6 wt%Solids 85.3 wt% Solids 91 wt%


SG 1.5-1.6Primary Extraction 50 °C Vent to atmosphere

T/hCaustic Stripping Steam 30 T/h Deaerator 40-50 °CNaOH Flotation Froth




PSC TailingT/h


Solids 40 wt%Make Up Solvent 4 T/h Solvent - Bitumen to SRU T/h

Bitumen 38 wt%Gland Cooling Water 61 T/h Solvent to Bitumen 1.65 wt/wt

Bitumen 10.4 wt%Solvent Make up Water 62 wt% Stripping Steam 33 T/h Legend

20 °C Solids 23 wt% BitumenWater

Recovered Solvent Tailing to TSRU T/h SteamT/h SRU Recovered Water 34 T/h Fuel gas

Solvent Loss : Bitumen Gland Cooling Water 143 T/h Solvent0.3 % vol./vol. TSRU Tailing Tailing

T/hStripping Steam 39 T/h Bitumen 7 % Abbreviations

Water 70 % BFW Boiler Feed WaterSolids 21 % FSU Froth Settling Unit

GTG Gas Turbine Generator51 T/h HHV Higher Heating Value

T/h HRSG Heat Recovery Steam GeneratorLPS Low Pressure Steam

bbl/sd MPS Medium Pressure SteamBitumen 99.9 % PSC Primary Separation Cell

T/h Tailing Asphaltene 12.0 % SG Specific GravityRecycled Water Reclaimed Water T/h Tailing Pond Solids + Water 0.1 % SRU Solvent Recovery Unit

25 °C 85 % Process Water Recycled Asphaltene Rejection 7.6 % TDS Total Dissolved SolidsTOC Total organic carbon TSRU Tailing Solvent Recovery Unit



GJ/h °C Total Bitumen Recoverym3/h kPag Asphaltenes Rejection

T/h MW T/h Stripping Steam Total Bitumen Recovery (with rejected asphaltenes)Unit T/h Processing Heating

Duct Burner MPS LPS Water Summary (T/H)Make-up Water BFW GJ/h HRSG 2 Unit 90 % Quality Cooling Water

25 °C T/h m3/h Cogen Efficiency 85 % °C Heated Watermg/L TDS Unit kPag Reclaimed Water

Make-up Water mg/L Silica GTG Duct Burner HRSG T/h Raw Watermg/L TDS mg/L Hardness BFWmg/L Silica mg/L TOC LPS Utility Steam Boiler Blowdownmg/L Hardness Make-Up Watermg/L TOC Recovered Condensate 479 T/h Boilers LPS Condensate Return

Fresh Water : Bitumen GJ/hvol./vol. Natural Gas Required Space Heating m3/h Project: A Static Oil Sands Mine and Extraction Reference Facility

GJ/h HHV Purge Gas to Flare 91.5 % Efficiency Case: Paraffinic - High Grade Revision: V 2.7.7m3/h unit Owner: COSIA

Natural Gas e3m3/sd GJ/h Auxilary Boiler Date:25 °C Boiler Blowdown Material Flow

T/h High Temperature Extraction, High Grade, Summer Condition

2,145

2

2,255

2,480

16,531

241

2,721

2.03

203.96

6,0597

6,059

034

38,678

3,57589,376

14,0512,48024121

4792,721

04-Oct-15604

18,780

2,204

2252,100

751

2

102

210

200,000

21

Process Water

6

1211.9

4.3

18,888244

4,396

13,142

99.0%

6,217

26 5,918441

2,443

14,051

1,382

26,634

94.6%

3,546

1,217

5,769

6

33

515

127

98.4%92.2%7.6%

85.1%

10,314

53

5111,050

67216,812

1,547

PSC

Flotation & Cyclone

TSRU 90 °C

FSU 70-90 °C SRU 215 °C

Bitumen


COSIA Mining & Extraction Low Grade - Paraffinic Froth Treatment - Material FlowOre Grade wt%Fine Contents wt%Waste to Ore wt%


Mine Face T/h Crusher Conveyor Feed Rotary BreakerTruck and Shovel -3 °C System 50°C RejectsBitumen 8.6 wt% Bitumen 3 wt%Water 6.4 wt% Water 4 wt%Solids 85 wt% Solids 92.5 wt%


SG 1.5-1.6Primary Extraction 50 °C Vent to atmosphere

T/hCaustic Stripping Steam 35 T/h Deaerator 40-50 °CNaOH Flotation Froth




PSC TailingT/h


Solids 46 wt%Make Up Solvent 3.5 T/h Solvent - Bitumen to SRU T/h

Bitumen 33 wt%Gland Cooling Water 72 T/h Solvent to Bitumen 1.65 wt/wt

Bitumen 8.2 wt%Solvent Make up Water 67 wt% Stripping Steam 32 T/h Legend

2 °C Solids 22% wt% BitumenWater

Recovered Solvent Tailing to TSRU T/h SteamT/h SRU Recovered Water 33 T/h Fuel gas

Solvent Loss : Bitumen Gland Cooling Water 168 T/h Solvent0.3 % vol./vol. TSRU Tailing Tailing

T/hStripping Steam 44 T/h Bitumen 7 % Abbreviations

Water 70.1 % BFW Boiler Feed WaterSolids 20.5 % FSU Froth Settling Unit

GTG Gas Turbine Generator47 T/h HHV Higher Heating Value

T/h HRSG Heat Recovery Steam GeneratorLPS Low Pressure Steam

bbl/sd MPS Medium Pressure SteamBitumen 99.9 % PSC Primary Separation Cell

T/h Tailing Asphaltene 12 % SG Specific GravityRecycled Water Reclaimed Water T/h Tailing Pond Solids + Water 0.04 % SRU Solvent Recovery Unit

2 °C 85 % Process Water Recycled Asphaltene Rejection 7.7 % TDS Total Dissolved SolidsTOC Total organic carbon TSRU Tailing Solvent Recovery Unit



GJ/h °C Total Bitumen Recoverym3/h kPag Asphaltenes Rejection

T/h MW T/h Stripping Steam Total Bitumen Recovery (with rejected asphaltenes)Unit T/h Process Heating

Duct Burner MPS LPS Water Summary (TPH)Make-up Water BFW GJ/h HRSG 2 Unit 90 % Quality Cooling Water

2 °C T/h m3/h Cogen Efficiency 85 % °C Heated Watermg/L TDS Unit kPag Reclaimed Water

Make-up Water mg/L Silica GTG Duct Burner HRSG T/h Raw Watermg/L TDS mg/L Hardness BFWmg/L Silica mg/L TOC LPS Utility Steam Boiler Blowdownmg/L Hardness Make-Up Watermg/L TOC Recovered Condensate 925 T/h Boilers LPS Condensate Return

Fresh Water : Bitumen GJ/hvol./vol. Natural Gas Required Space Heating m3/h Project: A Static Oil Sands Mine and Extraction Reference Facility

GJ/h Purge Gas to Flare 91.5 % Efficiency Case: Paraffinic - Low Grade Revision: V 2.7.7m3/h GJ/h unit Owner: COSIA


50 T/h High Temperature Extraction, Low Grade, Winter Condition

32,406

6,0597

203.9

3,754

62,143

2.25

0

53,574

515

6,05934

17,51614,889

04-Oct-15

6,256156,398 949 6

200,000

1,751

2

2,627

384

52,257 2100

60

2,090 225

3,012 1752

111

105026,838

2,251

2,251

347 9281,716 26,417

7,017

1,074

3,548

1,551

192

210

7

2,773

9201.5

18,765

38 8,195

925

98.2%

7,6059,91114,8892,627

92.3%98.4%89.1%7.7%82.3%

895

Process Water

38450

3,012


Flotation & Cyclone

TSRU 90 °C

FSU 70-90 °C SRU 215 °C

Bitumen




APPENDIX B

TETRA TECH’S GENERAL CONDITIONS

1

GENERAL CONDITIONS

GEOENVIRONMENTAL REPORT

This report incorporates and is subject to these “General Conditions”.

1.1 USE OF REPORT AND OWNERSHIP

This report pertains to a specific site, a specific development, and a specific scope of work. It is not applicable to any other sites, nor should it be relied upon for types of development other than those to which it refers. Any variation from the site or proposed development would necessitate a supplementary investigation and assessment.

This report and the assessments and recommendations contained in it are intended for the sole use of TETRA TECH’s client. TETRA TECH does not accept any responsibility for the accuracy of any of the data, the analysis or the recommendations contained or referenced in the report when the report is used or relied upon by any party other than TETRA TECH’s Client unless otherwise authorized in writing by TETRA TECH. Any unauthorized use of the report is at the sole risk of the user.

This report is subject to copyright and shall not be reproduced either wholly or in part without the prior, written permission of TETRA TECH. Additional copies of the report, if required, may be obtained upon request.

1.2 ALTERNATE REPORT FORMAT

Where TETRA TECH submits both electronic file and hard copy versions of reports, drawings and other project-related documents and deliverables (collectively termed TETRA TECH’s instruments of professional service); only the signed and/or sealed versions shall be considered final and legally binding. The original signed and/or sealed version archived by TETRA TECH shall be deemed to be the original for the Project.

Both electronic file and hard copy versions of TETRA TECH’s instruments of professional service shall not, under any circumstances, no matter who owns or uses them, be altered by any party except TETRA TECH. The Client warrants that TETRA TECH’s instruments of professional service will be used only and exactly as submitted by TETRA TECH.

Electronic files submitted by TETRA TECH have been prepared and submitted using specific software and hardware systems. TETRA TECH makes no representation about the compatibility of these files with the Client’s current or future software and hardware systems.

1.1 NOTIFICATION OF AUTHORITIES

In certain instances, the discovery of hazardous substances or conditions and materials may require that regulatory agencies and other persons be informed and the client agrees that notification to such bodies or persons as required may be done by TETRA TECH in its reasonably exercised discretion.

1.2 INFORMATION PROVIDED TO TETRA TECH BY OTHERS

During the performance of the work and the preparation of the report, TETRA TECH may rely on information provided by persons other than the Client. While TETRA TECH endeavours to verify the accuracy of such information when instructed to do so by the Client, TETRA TECH accepts no responsibility for the accuracy or the reliability of such information which may affect the report.

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