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Appendix B

Air Quality

Appendix B1

Air Quality Modelling Approach

Application for Approval of the BlackGold Expansion Project Volume 3 – EIA Appendices

December 2009

Appendix B1 – Table of Contents

APPENDIX B1: AIR QUALITY MODELLING APPROACH TABLE OF CONTENTS

PAGE

1.0 MODELLING METHODOLOGY ................................................................................. B1-1 1.1 The CALPUFF Model ...................................................................................... B1-1 1.2 The CALMET Preprocessor ............................................................................ B1-3

1.2.1 Upper Air Data ................................................................................ B1-8 1.2.2 Surface Data ................................................................................... B1-8 1.2.3 The Fifth Generation NCAR/Penn State Mesoscale

Model (MM5)................................................................................... B1-9 1.2.4 Land Use Categories (LUC)............................................................ B1-9 1.2.5 Terrain............................................................................................. B1-9

2.0 DISPERSION MODELLING APPROACH ................................................................ B1-11 2.1 Dispersion Modelling Assessment Assumptions........................................... B1-11 2.2 Building Downwash ....................................................................................... B1-11 2.3 Chemistry ...................................................................................................... B1-11 2.4 Recompiling CALPUFF ................................................................................. B1-12 2.5 Receptors ...................................................................................................... B1-12 2.6 CALPUFF Model Options .............................................................................. B1-12 2.7 NOX to NO2 Conversion................................................................................. B1-19 2.8 Background Levels of Acid-Forming Compounds ......................................... B1-19

3.0 MODELLING NON-POINT SOURCES..................................................................... B1-20 3.1 Area Sources................................................................................................. B1-20 3.2 Highways....................................................................................................... B1-21

4.0 LITERATURE CITED................................................................................................ B1-21


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TABLE OF CONTENTS (cont) PAGE

LIST OF TABLES

Table B1-1: Major Features of the CALPUFF Model .......................................................... B1-2 Table B1-2: Wind Field Options and Parameters (Input Group 5) ...................................... B1-6 Table B1-3: Meteorological Data Options (Input Group 4).................................................. B1-7 Table B1-4: Mixing Height Parameters (Input Group 6)...................................................... B1-7 Table B1-5: Temperature Parameters ................................................................................ B1-8 Table B1-6: Surface Meteorological Station Parameters .................................................... B1-8 Table B1-7: Surface Variables Associated with Land Use Characteristics....................... B1-10 Table B1-8: Assumed Gas Properties .............................................................................. B1-11 Table B1-9: Assumed Particulate Matter Properties ......................................................... B1-11 Table B1-10: Assumed Wet Deposition Parameters........................................................... B1-11 Table B1-11: Input Groups in the CALPUFF Control File ................................................... B1-14 Table B1-12: General Run Control Parameters (Input Group 1)......................................... B1-14 Table B1-13: Technical Options (Input Group 2) ................................................................ B1-15 Table B1-14: Species List-Chemistry Options (Subgroup 3a) ............................................ B1-15 Table B1-15: Map Projection Grid Control Parameters (Input Group 4) ............................. B1-16 Table B1-16: Dry Deposition Parameters for Gases (Input Group 7) ................................. B1-16 Table B1-17: Size Parameters for Dry Deposition of Particles (Input Group 8) .................. B1-17 Table B1-18: Miscellaneous Dry Deposition Parameters (Input Group 9) .......................... B1-17 Table B1-19: Wet Deposition Parameters .......................................................................... B1-17 Table B1-20: Chemistry Parameters (Input Group 11) ....................................................... B1-17 Table B1-21: Miscellaneous Dispersion and Computational Parameters (Input

Group 12) ...................................................................................................... B1-18

LIST OF FIGURES

Figure B1-1: CALMET-Generated Mean Wind Flow in January 2002 ................................. B1-4 Figure B1-2: CALMET-Generated Mean Wind Flow in July 2002........................................ B1-5 Figure B1-3: Discrete Receptor Locations Used in CALPUFF........................................... B1-13 S:\Project Ce\Ce03745\EIA\Vol 3\app b3-Volume 3-final EIA-ce03745-dec09-dr.doc


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APPENDIX B1: AIR QUALITY MODELLING APPROACH

1.0 MODELLING METHODOLOGY

The CALPUFF modelling system, which includes the CALMET meteorological pre-processor and other utilities, was used in this air quality assessment. CALPUFF (Scire et al. 2003 and Scire and Escoffier-Czaja. 2004) is recommended by AENV for refined air quality assessments (AENV 2009).

1.1 The CALPUFF Model

CALPUFF is currently considered the state-of-the-art in regulatory modelling, and represents a major improvement over previous models for the following reasons:

• it is applicable over spatial scales from a few meters to hundreds of kilometres, allowing the modelling of both local and regional air impacts;

• it incorporates the BPIP-PRIME downwash algorithm found in other advanced models used to predict building downwash in the vicinity of emission sources;

• it can model wet and dry removal processes (deposition); • it has algorithms to simulate SO2 and NOx chemistry for secondary particulate formation

and for predicting acidification; • it models dispersion in three dimensions, allowing for more realistic plume movement; • it allows winds to vary in space in response to channelling and blocking by terrain,

removing a constraint in older models; • it can model dispersion in calm winds, another major shortcoming of older models; and • it has been widely used for research and has thus undergone extensive peer review. Additional features of the CALPUFF model are provided in Table B1-1.


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Table B1-1: Major Features of the CALPUFF Model Source Types • Point sources (constant or variable emissions) • Line sources (constant emissions) • Volume sources (constant or variable emissions) • Area sources (constant or variable emissions) Non-steady State Emissions and Meteorological Conditions (if CALMET is used) • Gridded 3D fields of meteorological variables (winds, temperature) • Spatially variable fields of mixing height, friction velocity, convective velocity scale, Monin-Obukhov length,

precipitation rate • Vertically and horizontally varying turbulence and dispersion rates • Time-independent source and emissions data Dispersion Coefficient (σy, σz) Options • Direct measurements of σv and σw • Estimated values of σv and σw based on similarity theory • Micrometeorology dispersion coefficients (rural areas) • Pasquill-Gifford (PG) dispersion coefficients (rural areas) • McElroy-Pooler (MP) dispersion coefficients (urban areas) Vertical Wind Shear • Puff splitting • Differential advection and dispersion Plume Rise • Partial penetration • Buoyant and momentum rise • Stack tip effects • Vertical wind shear Dry Deposition • Gases and particulate matter • Three options: - Full treatment of space and time variations of deposition with a resistance model - User-specified diurnal cycles for each pollutant - No dry deposition Chemical Transformation Options • Pseudo first order chemical mechanism for SO2, SO4, NOx, HNO3, and NO3 (MESOPUFF II method) • User-specified diurnal cycles of transformation rates Wet Removal • Scavenging coefficient approach • Removal rate a function of precipitation intensity and precipitation type Graphical User Interface • Click and point model set-up and data input • Enhanced error checking of model inputs


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1.2 The CALMET Preprocessor

Improvements in modelling introduced by CALPUFF call for significantly more meteorological data than its predecessors, which required no more than data from a single meteorological station. CALPUFF makes use of three-dimensional meteorological data prepared by an equally sophisticated companion program called CALMET. CALMET generates three-dimensional fields of winds and other meteorological data by first interpolating between surface stations and upper air soundings. CALMET then adjusts this interpolated wind field to be physically consistent with the channelling and blocking posed by the terrain. It performs this adjustment such that atmospheric stability can enhance or suppress vertical motion. Although CALMET is not a prediction model, it can generate a continuous and realistic historical record of three-dimensional flow even with sparse observations. In addition, from these raw weather observations CALMET can calculate of other parameters required in predicting pollution dispersion, such as surface friction velocity, convective velocity scale, Monin-Obukhov length, mixing height, and Pasquill-Gifford stability class. The CALMET modelling domain used in this study is 235 km long west to east and 485 km long north to south. The UTM coordinates (NAD 83, Zone 12) for the modelling domain ranges from 375.0 km to 610.0 km easting, and 6,080.0 m to 6,565.0 m northing. This domain was selected to contain not only the project, but also the major sources in region. Horizontal grid cells 2 km X 2 km in size were adopted for the modelling to allow sufficient resolution of major terrain feature influences on wind flow. Along the vertical, eight layers were assigned to represent the atmospheric boundary layer. Over flat terrain, these layers would be found at 0, 20, 40, 80, 160, 320, 600, 1400 and 2 600 m above the surface. The 2002-2006 MM5 regional meteorological dataset provided by Alberta Environment served as the raw data used in CALMET. In addition, data from five surface meteorological stations were processed by CALMET. These stations were chosen to provide detail on the flow along the Athabasca Valley, which is a major topographic feature of the region. Sample output of the mean wind flow in the region are presented for two representative months (January and July 2002) in Figures B1-1 and B1-2. Tables B1-2 to B1-5 outline the options selected for use in CALMET preprocessing for various meteorological conditions.

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Source: GeoBase®, KNOC, Spatial DataWarehouse Ltd.

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FigB01-01 Wind Flow Jan0209-12-18

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CALMET-Generated Mean Wind Flow

in January 2002BlackGold Expansion Project

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Mean Wind Flow(length represents 5 m/s)

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FigB01-02 Wind Flow Jul0209-12-18

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CALMET-Generated Mean Wind Flow in July 2002BlackGold Expansion Project


Mean Wind Flow(length represents 5 m/s)


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Table B1-2: Wind Field Options and Parameters (Input Group 5)

Parameter Default This Study Description Wind Field Model Options: IWFCOD 1 1 Model selection variable – Diagnostic wind module IFRADJ 1 1 Compute Froude number adjustment (Yes = 1) IKINE 0 0 Compute kinematic effects (Yes = 1) IOBR 0 0 Use O’Brien procedure for adjustment of the vertical velocity (No) ISLOPE 1 1 Compute slope flow effects (Yes) IEXTRP -4 1 Extrapolate surface wind observations to upper layers (similarity theory used

with layer 1 data at upper air stations ignored) ICALM 0 0 Extrapolate surface winds even if calm (No) RMIN2 4.0 4.0 Minimum distance (km) from nearest upper air station to surface station for

which extrapolation of surface winds at surface station will be allowed IPROG 0 14 Use gridded prognostic wind field model output fields as input to the

diagnostic wind field model (14=use winds from MM5.DAT file as initial guess field)

Radius of Influence Parameters: LVARY F F Use varying radius of influence (F - False) RMAX1 - 20 Maximum radius of influence over land in the surface layer (km) RMAX2 - 50 Maximum radius of influence over land aloft (km) RMAX3 - 50 Maximum radius of influence over water (km) Other Wind Field Input Parameters: RMIN 0.1 0.1 Minimum radius of influence used in the wind field interpolation (km) TERRAD - 5.0 Radius of influence of terrain features (km) R1 - 1.0 Relative weighting of the first guess field and observations in the surface layer

(km) R2 - 5.0 Relative weighting of the first guess field and observations in the layers aloft

(km) RPROG - 0.0 Relative weighting parameter of the prognostic wind field data (km) DIVLIM 5.0E-6 5.0E-6 Maximum acceptable divergence in the divergence minimization procedure NITER 50 50 Maximum number of iterations in the divergence minimization procedure NSMTH (NZ) 2,(mxnz-

1)*4 2,4,4,4,4,4,4,4 Number of passes in the smoothing procedure

NINTR2 99 99 Maximum number of stations used in each layer for the interpolation of data to a grid point(number 12 is bigger than number of stations, then all stations are used)

CRITFN 1.0 1.0 Critical Froude number ALPHA 0.1 0.1 Empirical factor controlling the influence of kinematic effects FEXTR2(NZ) nz*0.0 1,1.7,2.2,3,3.9,5.

1,6.3,7.2 Multiplicative scaling factor for extrapolation of surface observations to upper layers

Diagnostic Module Data Input Options: IDIOPTI 0 0 Surface temperature (0 = compute internally from hourly surface observation) ISURFT -1 -1 Surface meteorological station to use for the surface temperature IDIOPT2 0 0 Domain-averaged temperature lapse (0 = compute internally from hourly

surface observation) IUPT -1 -1 Upper air station to use for the domain-scale lapse rate ZUPT 200 200 Depth through which the domain-scale lapse rate is computed (m) IDIOPT3 0 0 Domain-averaged wind components IUPWND -1 -1 Upper air station to use for the domain-scale winds IDIOPT4 0 0 Observed surface wind components for wind field module IDIOPT5 0 0 Observed upper air wind components for wind field module

Note: Lake breeze and barrier modules not used in this application


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Table B1-3: Meteorological Data Options (Input Group 4)

Parameter Default This Study Description

NOOBS 0 1 Use surface and overwater stations (no upper air observations) Use MM4/MM5/M3D for upper air data

Number of Surface & Precipitation Meteorological Stations: NSSTA - 3 Number of surface stations

NPSTA - -1 use of MM5/M3D precip data

Cloud Data Options: ICLOUD 0 3 Gridded cloud fields (not used)

File Formats: IFORMS 2 2 Surface meteorological data file format (2 = formatted)

IFORMP 2 2 Precipitation data file format (2 = formatted)

IFORMC 2 2 Cloud data file format (unformatted – not used)

Table B1-4: Mixing Height Parameters (Input Group 6)

Parameter Default This Study Description

Empirical Mixing Height Constants:

CONSTB 1.41 1.41 Neutral, mechanical equation

CONSTE 0.15 0.15 Convective mixing height equation

CONSTN 2400 2400 Stable mixing height equation

CONSTW 0.16 0.16 Over water mixing height equation

FCORIO 1.0E-4 1.2E-04 Absolute value of Coriolis (l/s)

Spatial Averaging of Mixing Heights IAVEZI 1 1 Conduct spatial averaging (1 = yes)

MNMDAV 1 1 Maximum search radius in averaging (1 grid cells)

HAFANG 30 30 Half-angle of upwind looking cone for averaging (degrees)

ILEVZI 1 1 Layer of winds used in upwind averaging (1 layers)

Other Mixing Heights Variables:

DPTMIN 0.001 0.001 Minimum potential temperature lapse rate in the stable layer above the current convective missing height (oK/m)

DZZI 200 200 Depth of layer above current convective mixing height through which lapse rate is computed (m)

ZIMIN 50 50 Minimum overland mixing height (m)

ZIMAX 3000 2500 Maximum overland mixing height (m)

ZIMINW 50 50 Minimum over-water mixing height (m) ZIMAXW 3000 2500 Maximum over-water mixing height (m)


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Table B1-5: Temperature Parameters Parameter Default This Study Description

Temperature Parameters ITPROG 0 2 Use Surface stations (no upper air observations),

Use MM5/M3D for upper air data (only if NOOBS = 0,1) IRAD 1 1 Interpolation type (1 = 1/R)

TRADKM 500 500 Radius of influence for temperature interpolation (km)

NUMTS 5 5 Maximum number of stations to include in temperature interpolation

IAVET 1 1 Conduct spatial averaging of temperatures (1 = yes)

TGDEFB -.0098 -.0098 Default temperature gradient below the mixing height over water (oK/m)

TGDEFA -.0045 -.0045 Default temperature gradient above the mixing height over water (oK/m)

JWAT1 - 99 Beginning land use categories for temperature interpolation over water (disabled)

JWAT2 - 99 Ending land use categories for temperature interpolation over water (disabled)

Precipitation Interpolation Parameters NFLAGP 2 2 Method of interpolation (1 = 1/R2)

SIGMAP 100.0 100.0 Radius of influence (km)

CUTP 0.01 0.01 Minimum precipitation rate cut-off (mm/h)

1.2.1 Upper Air Data

CALMET typically requires upper air soundings as input to generate a three-dimensional wind field. For the present study, no upper stations were necessary as the five–year MM5 data from the Alberta Environment were used as the initial guess wind field in CALMET.

1.2.2 Surface Data

In view of the coarse (12 km) resolution of the MM5 database, data from five surface stations in the domain were also included in the raw input to CALMET for processing. Four of these (Fort Chipewyan, Fort McKay, Patricia McInnes, and Mannix) are operated by the WBEA, while the fifth (Fort McMurray Airport) is a synoptic weather station. The inclusion of these stations improves CALMET’s results by providing additional detail on the flow at various parts of the domain. Table B1-6 presents their locations.

Table B1-6: Surface Meteorological Station Parameters

Name UTM X

Coordinate (km)

UTM Y Coordinate

(km)

Height Above Ground

(m) Ft. McMurray 301.000 5932.082 10

Ft. Chipewyan 493.060 6514.448 10

Patricia McInnes 470.884 6289.915 10

Ft. McKay 461.287 6338.622 10

MX75 447.039 6653.648 75


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1.2.3 The Fifth Generation NCAR/Penn State Mesoscale Model (MM5)

MM5 refers to the fifth generation NCAR/Penn State Mesoscale Model (MM5) developed jointly by the National Center for Atmospheric Research (NCAR) and Pennsylvania State University (PSU). It is a first-principles weather forecasting model capable of simulating meteorological processes, including the conservation of momentum, energy and mass (of air and moisture) and phase changes of water. The MM5 model is a widely used tool in such applications as tropical cyclone forecasting to climate downscaling. CALMET is designed to take MM5 model output through the CALMM5 utility. In many CALPUFF applications in western Canada (BC Environment 2000; SE2 2000 and 2001), MM5 model output was used exclusively as input.

1.2.4 Land Use Categories (LUC)

Land use data required by CALMET was taken from circa-2000 land cover map (Olthof et al. 2000) as a TIFF image with a 1km resolution. From this image file, grid values for CALMET were drawn from the most common land cover classification found in the grid cell. From the grid-averaged land use category, default values of the surface characteristics using the CALPUFF utility MAKEGEO were then generated. These parameters include the following:

• leaf area index; • roughness length; • anthropogenic heat flux; • bowen ratio; and • albedo. Values of these parameters corresponding to a land cover type are shown in Table B1-7.

1.2.5 Terrain

Topographic elevations for the terrain were obtained from the SRTM (3 Arc Second – 90 m), which is a joint project between the National Geo-spatial Intelligence Agency (NGA) and the National Aeronautics and Space Administration (NASA) (Jarvis et al. 2008). The TERREL program was used to extract and format terrain data for input into CALMET.


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Table B1-7: Surface Variables Associated with Land Use Characteristics

LUC Description Roughness Length Z0 (m) Albedo Bowen

Ratio Heat Flux Anthropogenic Heat Flux

Leaf Area Index

Winter 16 Mixed Urban 1.00 0.35 1.50 0.25 30.0 0.10 31 Herbaceous Rangeland/Grassland 0.10 0.702 0.502 0.151 0 0 32 Shrub & Brush Rangeland 0.15 0.702 0.502 0.151 0 0.20 41 Deciduous Forest 0.50 0.50 1.50 0.151 0 0.50 42 Evergreen Forest (Coniferous) 0.90 0.20 1.50 0.151 0 4.00 43 Mixed Forest 0.90 0.35 1.50 0.151 0 2.30 51 Streams & Canals 0.052 0.702 0.502 0.151 0 0 52 Lakes 0.052 0.702 0.502 0.151 0 0 54 Bays & Estuaries 0.052 0.702 0.502 0.151 0 0 61 Forested Wetlands 0.70 0.25 1.50 0.151 0 1.00 62 Non-Forested Wetlands/Swamps 0.10 0.60 0.502 0.151 0 0.50 75 Strip Mines, Quarries 0.10 0.702 0.502 0.151 5.0 0 Spring 16 Mixed Urban 1.00 0.14 1.00 0.25 30.0 0.20 31 Herbaceous Rangeland/Grassland 0.15 0.18 0.50 0.151 0 0.30 32 Shrub & Brush Rangeland 0.30 0.30 0.70 0.151 0 0.30 41 Deciduous Forest 1.00 0.50 0.70 0.151 0 1.00 42 Evergreen Forest (Coniferous) 0.90 0.35 0.70 0.151 0 4.00 43 Mixed Forest 0.90 0.40 0.70 0.151 0 2.50 51 Streams & Canals 0.01 0.20 0.10 0.151 0 0 52 Lakes 0.01 0.20 0.10 0.151 0 0 54 Bays & Estuaries 0.01 0.20 0.10 0.151 0 0 61 Forested Wetlands 0.80 0.15 0.50 0.151 0 1.20 62 Non - forested Wetlands/Swamps 0.20 0.30 0.10 0.151 0 0.50 75 Strip Mines, Quarries 0.15 0.40 0.50 0.151 5.0 0 Summer 16 Mixed Urban 1.00 0.16 1.50 0.25 10.0 0.30 31 Herbaceous Rangeland/Grassland 0.20 0.18 0.50 0.15 0 1.50 32 Shrub & Brush Rangeland 0.50 0.20 0.50 0.15 0 1.50 41 Deciduous Forest 1.30 0.12 0.80 0.15 0 3.50 42 Evergreen Forest (Coniferous) 1.30 0.12 1.20 0.15 0 4.00 43 Mixed Forest 1.30 0.12 1.00 0.15 0 3.80 51 Streams & Canals 0.001 0.10 0.05 1.00 0 0 52 Lakes 0.0001 0.10 0.05 1.00 0 0 54 Bays & Estuaries 0.001 0.10 0.05 1.00 0 0 61 Forested Wetlands 1.00 0.12 0.40 0.25 0 2.00 62 Non-Forested Wetlands/Swamps 0.20 0.14 0.10 0.25 0 1.00 75 Strip Mines, Quarries 0.20 0.30 0.50 0.15 5.0 0 Fall 16 Mixed Urban 1.00 0.18 1.50 0.25 10.0 0.20 31 Herbaceous Rangeland/Grassland 0.10 0.20 0.50 0.15 0 1.00 32 Shrub & Brush Rangeland 0.30 0.20 0.50 0.15 0 1.00 41 Deciduous Forest 0.80 0.12 0.80 0.15 0 2.00 42 Evergreen Forest (Coniferous) 1.30 0.12 1.00 0.15 0 4.00 43 Mixed Forest 1.05 0.12 0.90 0.15 0 3.00 51 Streams & Canals 0.001 0.14 0.05 1.00 0 0 52 Lakes 0.001 0.14 0.05 1.00 0 0 54 Bays & Estuaries 0.001 0.14 0.05 1.00 0 0 61 Forested Wetlands 0.90 0.12 0.40 0.25 0 1.50 62 Non - forested Wetlands/Swamps 0.20 0.16 0.10 0.25 0 0.70 75 Strip Mines, Quarries 0.15 0.30 0.50 0.15 5.0 0

1 Desert Shrubland. 2 Value recommended by EarthTech for perennial snow.


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2.0 DISPERSION MODELLING APPROACH

2.1 Dispersion Modelling Assessment Assumptions

Key assumptions designed to simplify the modelling procedure while increasing the likelihood of overestimating actual concentrations were made where appropriate. These assumptions include:

• all facility sources were simultaneously operating on a continuous basis at maximum capacity;

• all activities, such as road traffic and fugitive emissions, emit at their maximum levels.

2.2 Building Downwash

Building downwash was incorporated using the BPIP-PRIME program. Downwash was however applied only for the project in absence of building data for the other sources.

2.3 Chemistry

The chemistry module was used in the prediction of deposition and secondary particulate formation. Assumed gas and particulate matter properties are shown in Tables B1-8 to B1-10, based on default values used in CALPUFF.

Table B1-8: Assumed Gas Properties SO2 NO NO2 HNO3 Diffusivity (cm2/s) 0.115 0.186 0.141 0.108

Alpha Star (a*) 1000 1.0 1.0 1.0

Reactivity 8 2 8 18

Mesophyll Resistance (s/cm) 0 94 5 0

Henry's Law Coefficient 0.0332 21.5 4.09 8x10-8

Table B1-9: Assumed Particulate Matter Properties

SO4 NO3 PM2.5 PM10

Geometric mass mean diameter (µm) 0.48 0.48 0.48 0.48 Geometric standard deviation (µm) 2.0 2.0 2.0 2.0

Table B1-10: Assumed Wet Deposition Parameters

Scavenging Coefficient

(s-1) SO2 SO4 NO NO2 HNO3 NO3 PM2.5 PM10

Liquid 3.2 x 10-5 1 x 10-4 2.9 x 10-4 5.1 x 10-4 6 x 10-5 1 x 10-4 1 x 10-4 1 x 10-4 Frozen 0 3 x 10-5 0 0 0 3 x 10-5 3 x 10-5 3 x 10-5


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2.4 Recompiling CALPUFF

To ensure the correctness of the concentration-dependent reaction rates used in the CALPUFF chemistry module, all sources were modelled in one run. This called for recompiling CALPUFF to allow the more than 800 point sources to be included in the input files. In addition, the maximum number of puffs was increased to 200,000 (twice the default maximum of 99,000). This higher number was found to be more than sufficient to model all the emissions in the domain without causing error. These changes were made by modifying the PARAMSL.PUF file and recompiling using a Lahey F90 compiler. No changes were made to the CALPUFF model code itself.

2.5 Receptors

Receptors where ambient concentration and deposition rates were predicted were selected based on guidance in AENV (2009). Receptor spacing was based on the following criteria:

• 20 m spacing from the project fence line up to a distance of 200 m; • 50 m spacing between 200 m to 500 m from the fence line; • 250 m spacing between 500 m to 2 km; • 500 m spacing between 2 km to 5 km; and • 1 000 m spacing between 5 to 20 km. Beyond 10 km, a coarser grid spacing was used to allow the model to complete the simulation within a reasonable period but retaining focus on modelling the maximum impacts from the project. The following criteria was used in addition to the AENV guidelines:

• 2 500 m spacing between 20 km to 50 km from the fence line; • 5 000 m spacing between 50 km to 100 km; and • 10 km spacing in the rest of the domain. Receptors that fell inside area and volume sources or were within 20 m of a stack were removed as unrepresentative. In all there were 7795 discrete receptors, including 82 selected to represent human health exposure and ecological impact. A map of receptors is presented in Figure B1-3.

2.6 CALPUFF Model Options

The CALPUFF control file defines 17 input groups as identified in Table B1-11.

!(

Fort McMurray

Fort McKay

S A

S K

A T

C H

E W

A N

A L B

E R

T A

Ath

abas

ca

River

RiverClearwater

WinefredLake

!!63

!!63

Fort Chipewyan

LakeClaire

LakeAthabasca

Ath

abas

ca

Riv

er

Conklin

400000

400000

450000

450000

500000

500000

550000

550000

600000

600000

6100

000

6100

000

6150

000

6150

000

6200

000

6200

000

6250

000

6250

000

6300

000

6300

000

6350

000

6350

000

6400

000

6400

000

6450

000

6450

000

6500

000

6500

000



Project Area

Open Water

Watercourse

Receptor Location

±


20 0 20 4010


QA/QC:

KW

December 2009

CE03745/200PROJECT:

ANALYST:

FigureB1-3

CF

Figb01-03 Discrete Receptor09-12-18

DATE:


AMEC

PROJECTION/DATUM:

UTM Zone 12 NAD83

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Discrete Receptor Locations used in CALPUFFBlackGold Expansion Project



December 2009

Page B1-14

Table B1-11: Input Groups in the CALPUFF Control File Input

Group Description Applicable to the Project

0 Input and output file names Yes 1 General run control parameters Yes 2 Technical options Yes 3 Species list Yes 4 Grid control parameters Yes 5 Output options Yes 6 Sub grid scale complex terrain inputs No 7 Dry deposition parameters for gases Yes 8 Dry deposition parameters for particles Yes 9 Miscellaneous dry deposition for parameters Yes

10 Wet deposition parameters Yes 11 Chemistry parameters Yes 12 Diffusion and computational parameters Yes 13 Point source parameters Yes 14 Area source parameters Yes 15 Line source parameters No 16 Volume source parameters Yes 17 Discrete receptor information Yes

As stated earlier, the chemistry option was applied for the prediction of wet and dry acid deposition. This required the inclusion the of nine species in a single run: SO2, SO4, NO, NO2, HNO3, NO3, CO, primary PM2.5 and PM10. Another set of runs was used to model VOCs and NOx concentrations as conservative pollutants (no chemistry). From NOx, NO2 concentrations were calculated using the ozone-limiting method described in the AENV modelling guidelines. Speciated VOC and PAH emissions were determined by the methods discussed in Section 4.5 and Appendix B4. The CALPUFF input parameters were selected according to the default values, however some parameters were altered to better relate specifically to the modelling domain. Tables B1-12 to B1-21 identify the input parameters, default options, and values used for the current project.

Table B1-12: General Run Control Parameters (Input Group 1) Parameter Default Project Description

METRUN 0 0 All model periods in met file(s) will be run IBYR - 2002 Starting year IBMO - 1 Starting month IBDY - 1 Starting day IBHR - 0 Starting hour XBTZ - 7.0 Base time zone (MST = 7.0) IRLG - 8760 Length of run (hours) NSPEC 5 9 Number of chemical species NSE 3 6 Number of chemical species to be emitted ITEST 2 2 Program is executed after SETUP phase MRESTART 0 0 Does not read or write a restart file NRESPD 0 0 Restart file written only at last period METFM 1 1 Meteorological data format 1= CALMET binary file (CALMET.MET) AVET 60 60 Averaging time (minutes) PGTIME 60 60 PG Averaging time (minutes)


December 2009

Page B1-15

Table B1-13: Technical Options (Input Group 2) Parameter Default Project Description

MGAUSS 1 1 Gaussian distribution used in near field MCTADJ 3 3 Terrain adjustment method (3 = Partial plume path adjustment) MCTSG 0 0 Subgrid-scale complex terrain (0 = not modelled) MSLUG 0 0 Near-field puffs not modelled as elongated MTRANS 1 1 Transitional plume rise modelled MTIP 1 1 Stack tip downwash used MBDW 1 2 Method used to simulate building downwash (2 = PRIME method) MSHEAR 0 0 Vertical wind shear not modelled MSPLIT 0 0 Puff splitting is not allowed MCHEM 1 3 Transformation rates computed internally using RIVID/ARM3 scheme MAQCHEM 0 0 Aqueous phase transformation not modelled MWET 1 1 Wet removal modelled MDRY 1 1 Dry deposition modelled MTILT 0 0 Gravitational settling (plume tilt) not modeled MDISP 3 3 Dispersion coefficients from internally calculated sigma v, sigma w using

micrometeorological variables (u*, w*, L, etc.) MTURBVW 3 3 Use both σv and σw from PROFILE.DAT to compute σy and σz (n/a) MDISP2 3 3 Back-up method used to compute dispersion when measured turbulence data

are missing (used only if MDISP = 1 or 5) This parameter is not used because MDISP = 2 for the project.

MTAULY 0 0 Draxler default 617.284 (s) used for Lagrangian timescale for Sigma-y (used only if MDISP=1,2 or MDISP2=1,2)

MTAUADV 0 0 Method used for Advective-Decay timescale for Turbulence (used only if MDISP=2 or MDISP2=2)

MCTURB 1 1 Standard CALPUFF subroutines used to compute turbulence sigma-v & sigma-w using micrometeorological variables(Used only if MDISP = 2 or MDISP2 = 2)

MROUGH 0 0 PG σy and σz not adjusted for roughness MPARTL 1 1 partial plume penetration of elevated inversion MTINV 0 0 Strength of temperature inversion computed from default gradients MPDF 0 0 PDF not used for dispersion under convective conditions MSGTIBL 0 0 Sub-grid TIBL module not used for shore line MBCON 0 0 Boundary conditions (concentration) not modelled MSOURCE 0 0 No Individual source contributions saved MFOG 0 0 Do not configure for FOG model output MREG 1 0 Do not test options specified to see if they conform to regulatory values

Table B1-14: Species List-Chemistry Options (Subgroup 3a)

CSPEC Modelled

(0=no, 1=yes)

Emitted (0=no, 1=yes)

Dry deposition (0=none,

1=computed-gas, 2=computed particle,

3=user-specified)

Output group Number

SO2 1 1 1 0 SO4

-2 1 0 2 0 NO 1 1 1 0 NO2 1 1 1 0 HNO3 1 0 1 0 NO3

- 1 0 2 0 PM2.5 1 1 2 0 CO 1 1 0 0 PM10 1 1 2 0


December 2009

Page B1-16

Table B1-15: Map Projection Grid Control Parameters (Input Group 4) Parameter Default Project Description

PMAP UTM UTM Map projection: Universal Transverse Mercator IUTMZN - 12 UTM Zone (1 to 60) UTMHEM N N Northern hemisphere UTM projection DATUM WGS-84 NAR-B NIMA Datum Region - Canada NX - 95 Number of X grid cells in meteorological grid NY 195 Number of Y grid cells in meteorological grid NZ - 8 Number of vertical layers in meteorological grid DGRIDKM - 2.5 Grid spacing (km) ZFACE - 0,20,40,80,

160,320,600,1400,2600

Cell face heights in meteorological grid (m)

XORIGKM - 375.6 Reference X coordinate for SW corner of grid cell (1,1) of meteorological grid (km)

YORIGKM - 6080.0 Reference Y coordinate for SW corner of grid cell (1,1) of meteorological grid (km)

IBCOMP - 1 lower left corner of the computational grid JBCOMP - 1 lower left corner of the computational grids IECOMP - 95 upper right corner of the computational grid JECOMP - 195 upper right corner of the computational grid LSAMP T F Sampling grid is not used IBSAMP - 0 X index of lower left corner of the sampling grid JBSAMP - 0 Y index of lower left corner of the sampling grid IESAMP - 0 X index of upper right corner of the sampling grid JESAMP - 0 Y index of upper right corner of the sampling grid MESHDN 1 1 Nesting factor of the sampling grid

Table B1-16: Dry Deposition Parameters for Gases (Input Group 7) Species Default Project Description

0.1509 0.1372 Diffusivity (cm2/s) 1000.0 1000. Alpha star

8.0 8.0 Reactivity 0.0 0.0 Mesophyll resistance (s/cm)

SO2

0.4 0.0331 Henry’s Law coefficient - 0.22034 Diffusivity (cm2/s) - 1.0 Alpha star - 2. Reactivity - 94. Mesophyll resistance (s/cm)

NO

- 21.5 Henry’s Law coefficient 0.1656 0.15854 Diffusivity (cm2/s)

1.0 1.0 Alpha star 8.0 8. Reactivity 5.0 5. Mesophyll resistance (s/cm)

NO2

3.5 4.09 Henry’s Law coefficient 0.1628 0.1041 Diffusivity (cm2/s)

1.0 1.0 Alpha star 18.0 18. Reactivity 0.0 0. Mesophyll resistance (s/cm)

HNO3

0.00000008 0.00000008 Henry’s Law coefficient


December 2009

Page B1-17

Table B1-17: Size Parameters for Dry Deposition of Particles (Input Group 8) Species Default Project Description

SO4 2 0.48 0.48 Geometric mass mean diameter of SO4 2[μm] SO4 2 2.0 2.0 Geometric standard deviation of SO4 2 [μm] NO3

- 0.48 0.48 Geometric mass mean diameter of NO3 -[μm]

NO3 - 2.0 2.0 Geometric standard deviation of NO3

- [μm] PM2.5 0.48 0.48 Geometric mass mean diameter of PM2.5 [μm] PM2.5 2.0 2.0 Geometric standard deviation of PM2.5 [μm] PM10 0.48 0.48 Geometric mass mean diameter of PM10 [μm] PM10 2.0 2.0 Geometric standard deviation of PM10 [μm]

Table B1-18: Miscellaneous Dry Deposition Parameters (Input Group 9) Parameters Default Project Description

RCUTR 30 30 Reference cuticle resistance (s/cm) RGR 10 10 Reference ground resistance (s/cm) REACTR 8 8 Reference pollutant reactivity NINT 9 9 Number of particle size intervals for effective particle deposition velocity IVEG 1 1 Vegetation in non-irrigated areas is active and unstressed

Table B1-19: Wet Deposition Parameters Species Default Project Description

0.00003 0.00003 Scavenging coefficient for liquid precipitation [s-1] SO2 0.0 0.0 Scavenging coefficient for frozen precipitation [s-1]

0.0001 0.0001 Scavenging coefficient for liquid precipitation [s-1] SO4-2

0.00003 0.00003 Scavenging coefficient for frozen precipitation [s-1] 0.000029 0.000029 Scavenging coefficient for liquid precipitation [s-1] NO

0.0 0.0 Scavenging coefficient for frozen precipitation [s-1] 0.000051 0.00051 Scavenging coefficient for liquid precipitation [s-1] NO2

0.0 0.0 Scavenging coefficient for frozen precipitation [s-1] 0.00006 0.00006 Scavenging coefficient for liquid precipitation [s-1] HNO3

0.0 0.0 Scavenging coefficient for frozen precipitation [s-1] 0.0001 0.0001 Scavenging coefficient for liquid precipitation [s-1] NO3

- 0.00003 0.00003 Scavenging coefficient for frozen precipitation [s-1] 0.0001 0.0001 Scavenging coefficient for liquid precipitation [s-1] PM2.5

0.00003 0.00003 Scavenging coefficient for frozen precipitation [s-1] 0.0001 0.0001 Scavenging coefficient for liquid precipitation [s-1] PM10

0.00003 0.00003 Scavenging coefficient for frozen precipitation [s-1]

Table B1-20: Chemistry Parameters (Input Group 11) Parameters Default Project Description

MOZ 1 0 Monthly background O3 value BCKO3 12*80 12*35 Background monthly O3 concentration (ppb) BCKNH3 12*10 12*0.22 Background NH4 concentration (ppb) RNITE1 0.2 0.2 Nighttime NO2 loss rate in percent/hour RNITE2 2 2 Nighttime NOX loss rate in percent/hour RNITE3 2 2 Nighttime HNO3 loss rate in percent/hour MH202 1 1 Background H2O2 concentrations BCKH202 12*1 12*1 Background monthly H2O2 concentrations (Aqueous phase transformations

not modelled) BCKPMF - - Fine particulate concentration for Secondary Organic Aerosol Option (used

only if MCHEM=4 in the Project MCHEM =3) OFRAC - - Organic fraction of fine particulate for SOA Option (used only if MCHEM=4) VCNX - - VOC/NOx ratio for SOA Option (used only if MCHEM=4)


December 2009

Page B1-18

Table B1-21: Miscellaneous Dispersion and Computational Parameters (Input Group 12) Parameters Default Project Description

SYDEP 550 550 Horizontal size of a puff in metres beyond which the time dependant dispersion equation of Heffter is used

MHFTSZ 0 0 Do not use Heffter formulas for sigma z JSUP 5 5 Stability class used to determine dispersion rates for puffs

above boundary layer CONK1 0.01 0.01 Vertical dispersion constant for stable conditions CONK2 0.1 0.1 Vertical dispersion constant for neutral/stable conditions TBD 0.5 0.5 Use ISC transition point for determining the transition point

between the Schulman-Scire to Huber-Snyder Building Downwash scheme

IURB1 10 10 Lower range of land use categories for which urban dispersion is assumed

IURB2 19 19 Upper range of land use categories for which urban dispersion is assumed

XMXLEN 1 1 Maximum length of emitted slug in meteorological grid units XSAMLEN 1 1 Maximum travel distance of slug or puff in meteorological grid

units during one sampling unit MXNEW 99 99 Maximum number of puffs or slugs released from one source

during one time step MXSAM 99 99 Maximum number of sampling steps during one time step for

a puff or slug NCOUNT 2 2 Number of iterations used when computing the transport wind

for a sampling step that includes transitional plume rise SYMIN 1 1 Minimum sigma y in metres for a new puff or slug SZMIN 1 1 Minimum sigma z in metres for a new puff or slug CDIV 0.0, 0.0 0.0, 0.0 Divergence criteria for dw/dz in met cells WSCALM 0.5 0.5 Minimum wind speed allowed for non-calm conditions (m/s) XMAXZI 3000 3000 Maximum mixing height in metres XMINZI 50 50 Minimum mixing height in metres

1.54 1.54 wind speed category 1 [m/s] 3.09 3.09 wind speed category 2 [m/s] 5.14 5.14 wind speed category 3 [m/s] 8.23 8.23 wind speed category 4 [m/s]

WSCAT

10.80 10.80 wind speed category 5 [m/s] 0.020 0.020 potential temperature gradient for E stability [K/m] PTG0 0.035 0.035 potential temperature gradient for F stability [K/m]

SL2PF 10 10 Slug-to-puff transition criterion factor equal to sigma y/length of slug

NSPLIT 3 3 Number of puffs that result every time a puff is split IRESPLIT Hour 17=1 Hour 17=1 Time(s) of day when split puffs are eligible to be split once

again ZISPLIT 100 100 Minimum allowable last hour’s mixing height for puff splitting ROLDMAX 0.25 0.25 Maximum allowable ratio of last hour’s mixing height and

maximum mixing height experienced by the puff for puff splitting

ASPLITH 5 5 Number of puffs that result every time a puff is horizontally split

SYSPLITH 1 1 Minimum sigma-y of puff before it may be horizontally split SHSPLITH 2 2 Minimum puff elongation rate due to wind shear before it may

be horizontally split CNSPLITH 1.0E-7 1.0E-7 Minimum concentration of each species in puff before it may

be horizontally split EPSSLUG 1.00E-04 1.00E-04 Fractional convergence criterion for numerical SLUG sampling

iteration EPSAREA 1.00E-06 1.00E-06 Fractional convergence criterion for numerical AREA

sampling iteration DRISE 1.0 1.0 Trajectory step length for numerical rise


December 2009

Page B1-19

Parameter

SVMIN SWMIN Stability Class Minimum turbulence (σv) (m/s) Minimum turbulence (σw) (m/s)

A 0.5 0.2 B 0.5 0.12 C 0.5 0.08 D 0.5 0.06 E 0.5 0.03 F 0.5 0.016

Parameter

PLX0 PPC Stability Class Wind speed profile exponent Plume path coefficient

A 0.21 0.8 B 0.21 0.7 C 0.23 0.6 D 0.40 0.5 E 0.62 0.5 F 0.50 0.5

2.7 NOX to NO2 Conversion

The 2009 AENV modelling guidelines recommend a tiered approach in modelling the conversion of NOx to NO2. In this tiered approach, the ozone limiting method (OLM) is suggested if modelling NOx as a conservative pollutant yields unrealistic results. As its term implies, the OLM is based on the fact that the amount of NO2 that can be converted from NOx is dependent on the available ozone. Ozone provides the oxygen needed for this conversion. OLM is expressed as follows:

If [O3] > 0.9 × [NOx] then [NO2] = [NOx] otherwise [NO2] = [O3] + 0.1 × [NOx]

In this expression, terms in brackets refer to ambient concentrations.

The conversion was applied to the maximum NOx concentrations at each receptor predicted by CALPUFF. As suggested by 2009 AENV modelling guidelines, three different background values were used for background ozone, namely:

• 0.05 ppm (98 μg/m³) for converting 1-hour average NOX concentrations to NO2; • 0.035 ppm (69 μg/m³) for 24-hour average concentrations; and • 0.02 ppm (39 μg/m³) for annual average concentrations.

2.8 Background Levels of Acid-Forming Compounds

The deposition of acid-forming compounds takes place through wet and dry processes that can result in adverse long-term effects on aquatic and terrestrial environments. The wet process involves rain and snowfall, while the dry process involves the removal of the compounds


December 2009

Page B1-20

through contact with surfaces such as vegetation. At the same time, the presence of neutralizing compounds can mitigate acidification. The net impact is modeled as potential acid input or PAI. PAI incorporates the following:

• the effects of nitrogen and sulphur species; • effects of dry and wet deposition mechanisms; and • effects of base cations in mitigating acidity. The calculation of PAI is based on the wet and dry deposition of sulphur species (e.g., SO2 gas, SO4

2- particle), nitrogen species (e.g., NO2 gas, NO gas, HNO3 gas, NO3- particle), and base

cations (e.g., Ca2+ particle, Mg+ particle and K+ particle). PAI is expressed in keq/ha/yr, where keq refers to the number of equivalent hydrogen ions (1 keq = 1 kmol H+) deposited on the surface through both natural and anthropogenic processes. PAI is therefore highly variable in space, but since surface processes such as runoff and aquatic flow can redistribute the deposited material, quantifying its impact requires determining the sizes of areas receiving critical loads set by CASA and AENV (1999). A background deposition rate of 0.10 keq/ha/yr for cations and a regional PAI background of 0.11 keq/ha/yr was used based on ambient monitoring in the region.

3.0 MODELLING NON-POINT SOURCES

While stack emissions are straightforward to model, other sources require some representation or parameterization in order to be modelled. This section describes how mines, stockpiles, material handling, urban areas, and highways were treated in CALPUFF. 3.1 Area Sources Fugitive emissions such as windblown dust, heavy equipment exhausts and emissions from urban areas were treated as area sources. Emissions from existing operating facilities in the AQRSA were obtained from facility operators and previously submitted EIA. The coordinates of the corners of the sources were obtained and the sources are represented as polygons. The CALPUFF model requires initial vertical dispersion (σz) and release height to model area sources. Mines, stockpiles, tailings ponds and cities were assumed to be area sources with a characteristic depth of 10 m. This depth yields a release height of 5 m (its vertical midpoint) and an initial vertical dispersion parameter of 4.3 m following the Gaussian approximation that 95 percent of the material will be found within 1/2.15 of this depth. This release height was deemed typical of the elevations of pipes and valves, and approximates the height of urban structures. For open pit mines, this value ignores the partial retention of particulates caused by the mine walls.


December 2009

Page B1-21

3.2 Highways

The highway emissions were modelled as line sources with an effective emission height of 2.0 m. All four major highways in the domain were modelled.

4.0 LITERATURE CITED

Alberta Environment (AENV). 2009. Air Quality Model Guideline. Prepared by A. Idriss & F. Spurrell Climate Change, Air and Land Policy Branch. Available at:

http://environment.gov.ab.ca/info/library/8151.pdf Accessed September 2009

British Columbia Ministry of Environment, Lands and Parks (BC Environment). 2000. Submission by BC Environment to Washington State Energy Facility Site Evaluation Council Regarding the Proposed Sumas Energy Project. Victoria, BC.

Clean Air Strategic Alliance and Alberta Environment (CASA and AENV). 1999. Application of Critical, Target and Monitoring Loads for the Evaluation and Management of Acid Deposition. Publication No. T/472. Clean Air Strategic Alliance, Alberta Environment. Calgary, AB.

Jarvis A., H.I. Reuter, A. Nelson, E. Guevara, 2008, Hole-filled seamless SRTM data V4, International Centre for Tropical Agriculture (CIAT), available from http://srtm.csi.cgiar.org, Accessed June 2009

Olthof, I., Latifovic, R. and Pouliot, D., 2008. Circa-2000 Northern Land Cover of Canada, Earth Sciences Sector, Canada Centre for Remote Sensing, Natural Resources Canada. http://www.ccrs.nrcan.gc.ca/optical/landcover2000_e.php Accessed June 2009.

Scire, J. and C. Escoffier-Czaja. 2004. CALPUFF Training Course, Canadian Prairie and Northern Section of the Air and Waste Management Association. Calgary, AB

Scire, J.S., D.G. Strimaitis and R.J. Yamartino. 2000. A User’s Guide for the CALPUFF Model (Version 5.0). Earth Technologies Inc. Concord, MA.

Sumas Energy 2, Inc. (SE2). 2000. Generation Facility Application. Submitted to Washington State Energy Facility Site Evaluation Council. Washington, DC

Sumas Energy 2, Inc. (SE2). 2001. Generation Facility Second Revisited Application. Submitted to Washington State Energy Site Evaluation Council. Washington, DC

Appendix B2

Emission Sources Information – Criteria Air Contaminants


December 2009


APPENDIX B2: EMISSION SOURCES INFORMATION – CRITERIA AIR CONTAMINANTS TABLE OF CONTENTS

PAGE

1.0 INTRODUCTION......................................................................................................... B2-1

2.0 INDUSTRIAL FACILITIES.......................................................................................... B2-2 2.1 Albian Sands Energy Inc. ................................................................................ B2-2 2.2 Birch Mountain Resources .............................................................................. B2-4 2.3 Canadian Natural Resources Limited.............................................................. B2-4 2.4 Connacher Oil and Gas Limited .................................................................... B2-11 2.5 ConocoPhillips Canada Resources Corporation ........................................... B2-11 2.6 Deer Creek Energy Limited ........................................................................... B2-16 2.7 Devon Energy Corporation............................................................................ B2-16 2.8 EnCana Corporation...................................................................................... B2-20 2.9 Husky Energy ................................................................................................ B2-20 2.10 Imperial Oil/ExxonMobil................................................................................. B2-20 2.11 Japan Canada Oil Sands .............................................................................. B2-27 2.12 MEG Energy Corporation .............................................................................. B2-27 2.13 Northland Forest Products ............................................................................ B2-27 2.14 OPTI Canada/Nexen Canada Limited........................................................... B2-34 2.15 Petro-Canada ................................................................................................ B2-34 2.16 Shell Canada Limited .................................................................................... B2-41 2.17 Statoil Canada Ltd. ........................................................................................ B2-41 2.18 Suncor Energy Inc. ........................................................................................ B2-48 2.19 Syncrude Canada Ltd.................................................................................... B2-56 2.20 Whitesands Insitu Partnership....................................................................... B2-60 2.21 Williams Energy Canada ............................................................................... B2-60

3.0 PROJECT EMISSIONS ............................................................................................ B2-60

4.0 SMALL GAS PRODUCTION AND PROCESSING FACILITIES.............................. B2-60

5.0 COMMUNITIES AND HIGHWAYS ........................................................................... B2-70



December 2009



LIST OF TABLES

Table B2-1: Summary of Albian Sands & ATCO Power Existing and Approved Air Emissions Used for the Baseline, Project and Planned Development Scenarios................................................................................................... B2-3

Table B2-2: Summary of Birch Mountain Resources Air Emissions Used for the Baseline and Project Scenarios........................................................... B2-5

Table B2-3: Summary of Birch Mountain Resources Air Emissions Used for the Planned Development Scenario .......................................................... B2-6

Table B2-4: Summary of CNRL Horizon Existing and Approved Air Emissions Used for the Baseline and Project Scenarios ............................................ B2-7

Table B2-5: Summary of CNRL Horizon Existing, Approved and Proposed Air Emissions Used for the Planned Development Scenario .......................... B2-9

Table B2-6: Summary of the Connacher Existing and Approved Air Emissions Used for the Baseline and Project Scenarios .......................................... B2-12

Table B2-7: Summary of Connacher Existing, Approved and Proposed Air Emissions Used for the Planned Development Scenario ........................ B2-13

Table B2-8: Summary of ConocoPhillips Existing and Approved Air Emissions Included in the Baseline and Project Scenarios..................... B2-14

Table B2-9: Summary of ConocoPhillips Existing, Approved and Proposed Air Emissions Included in the Planned Development Scenario............... B2-15

Table B2-10: Summary of DCEL Joslyn Creek Approved Air Emissions Used for the Baseline and Project Scenarios ................................................... B2-17

Table B2-11: Summary of DCEL Joslyn Creek Approved and Proposed Air Emissions Used for the Planned Development Scenario ........................ B2-18

Table B2-12: Summary of Devon Existing, Approved and Proposed Air Emissions Included in the Project and Planned Development Scenarios................. B2-19

Table B2-13: Summary of EnCana Existing and Approved Air Emissions Included in the Baseline and Project Scenarios..................................................... B2-21

Table B2-14: Summary of EnCana Existing, Approved and Proposed Air Emissions Included in the Planned Development Scenario...................................... B2-23

Table B2-15: Summary of Husky Sunrise Air Emissions Used for the Baseline, Project and Planned Development Scenarios ......................................... B2-25

Table B2-16: Summary of IOL/ExxonMobil Approved Kearl Air Emissions Used for the Baseline, Project and Planned Development Scenarios .............. B2-26

Table B2-17: Summary of JACOS Existing Air Emissions Used for the Baseline and Project Scenarios............................................................... B2-28

Table B2-18: Summary of JACOS Existing and Proposed Air Emissions Used for the Planned Development Scenario................................................... B2-29

Table B2-19: Summary of MEG Existing and Approved Air Emissions Used for the Baseline and Project Scenarios......................................................... B2-30

Table B2-20: Summary of MEG Existing, Approved and Proposed Air Emissions Used for the Planned Development Scenario ......................................... B2-31

Table B2-21: Summary of Northlands Forest Products Existing Air Emissions Included in the Baseline, Project and Planned Development Scenarios ............... B2-33


December 2009



Table B2-22: Summary of OPTI/Nexen Approved Air Emissions Included in the

Baseline and Project Scenarios............................................................... B2-35 Table B2-23: Summary of OPTI/Nexen Existing, Approved and Proposed Air

Emissions Included in the Planned Development Scenario .................... B2-36 Table B2-24: Summary of Petro-Canada Existing and Approved Air Emissions

Used for the Baseline and Project Scenarios .......................................... B2-38 Table B2-25: Summary of Petro-Canada Existing, Approved and Proposed Air

Emissions Used for the Planned Development Scenario ........................ B2-39 Table B2-26: Summary of Shell Approved Air Emissions Used for the Baseline

and Project Scenarios ............................................................................. B2-42 Table B2-27: Summary of Shell Approved and Proposed Air Emissions Used for

the Planned Development Scenario ........................................................ B2-43 Table B2-28: Summary of Statoil Existing and Approved Air Emissions Used for

the Baseline and Project Scenarios......................................................... B2-44 Table B2-29: Summary of Statoil Existing, Approved and Proposed Air Emissions

Used for the Planned Development Scenario ......................................... B2-45 Table B2-30: Summary of Suncor Existing and Approved Air Emissions Used for

the Baseline and Project Scenarios......................................................... B2-49 Table B2-31: Summary of Suncor Existing and Approved Air Emissions Used for

the Planned Development Scenarios ...................................................... B2-52 Table B2-32: Summary of Syncrude Air Emissions Used for the Baseline, Project

and Planned Development Scenarios ..................................................... B2-57 Table B2-33: Summary of Whitesands Insitu Partnership Air Emissions Included

in the Baseline, Project and Planned Development Scenarios ............... B2-61 Table B2-34: Summary of Williams Energy Existing Air Emissions Included

in the Baseline, Project and Planned Development Scenarios ............... B2-62 Table B2-35: Summary Project Air Emissions Included in the Project and

Planned Development Scenarios ............................................................ B2-63 Table B2-36: Summary of Gas Production and Processing Facility Emissions Included

in the Baseline, Project and Planned Development Scenarios ............... B2-64 Table B2-37: Summary of Community and Highway Emissions Included in the

Baseline and Project Scenarios............................................................... B2-70 Table B2-38: Summary of Community and Highway Emissions Included in the

Planned Development Scenario .............................................................. B2-70 S:\Project Ce\Ce03745\EIA\Vol 3\app b2-Volume 3-final EIA-ce03745-dec09-dr.doc


December 2009

Page B2-1

APPENDIX B2: EMISSION SOURCES INFORMATION – CRITERIA AIR CONTAMINANTS

1.0 INTRODUCTION

This appendix lists the emission source characteristics and emission rate details of the Criteria Air Contaminants, including SO2, NOx, CO, PM2.5 and total VOCs within the AQRSA. The air quality impacts as a result of emissions of SO2, NOx, CO and PM2.5 are assessed and provided in the main report (Volume 2, Section 4), while a fraction of the species that comprise the VOC emissions (Appendix B4) are modeled as part of the human health risk assessment. The facility and planned emission information was obtained from direct contact with regional operators or proponents, and from recent EIA. The facility and planned emissions within the AQRSA that were included in the baseline, project and planned development (Planned) emission scenarios of this air quality assessment are presented on a company-by-company basis. Background emission sources for the project emission scenario were considered to be the same as those for the Baseline scenario. Most of the documented emission sources fall into the following three general categories:

• Fully integrated oil sands mining, bitumen extraction and bitumen upgrading facilities. The facilities primary fuel type is a combination of processed (pipeline spec) natural gas and desulphurized “refinery-type” fuel gas (containing negligible H2S) in gas turbine/heat recovery steam generators/electricity co-generation facilities and additional steam boilers/generators and heaters. The major SO2 emission source for these types of facilities is the sulphur recovery facility, which is part of the processing plant facility. SO2 emissions from the mining fleet equipment are considered to be a minor contributor to the facility total since low-sulphur diesel fuel or low-sulphur synthetic diesel produced on site is utilized in internal combustion engines. In regards to NOx emissions, NOx from processing plant facilities (combustion sources) and the mining fleet (internal combustion engines) are considered equally significant.

• SAGD operations, primarily using processed natural gas fuel (containing negligible H2S) and small quantities of produced gas (containing some H2S) in steam boilers/generators and heaters. For this type of industrial development, the only significant major SO2 and NOx emission sources are the steam boilers/generators. Compared to integrated mining and bitumen extraction/upgrading facilities, SAGD facilities emit less SO2 and NOx on a bitumen production basis.

• Oil sands mining and bitumen extraction facilities using predominantly processed natural gas fuel (containing negligible H2S) in gas turbine/heat recovery steam generators/ electricity co-generation facilities and “supplemental” steam boilers/generators and heaters. In comparison to the other two types of facilities mentioned above, these facilities emit predominantly NOx, with emissions apportioned more or less equally between those from the processing plant facilities (combustion sources) and those from the mining fleet (internal combustion engines). SO2 emissions from the mining fleet are considered minor since the mining fleet equipment uses low-sulphur diesel fuel.


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This appendix also presents the estimated emissions from a number of communities and highways, as well as a summary of small gas production and processing facilities in the region. All of the listed facilities and projects are located within the AQRSA and have been selected for inclusion in the air quality assessment.

2.0 INDUSTRIAL FACILITIES

2.1 Albian Sands Energy Inc.

Albian Sands Energy Inc. (Albian Sands) was established as a joint venture between Shell Canada (60%), Marathon Oil Corp. (20%), and Chevron Canada Resources (20%) to develop and operate the Muskeg River Mine.

Emissions Included in Baseline, Project and Planned Development Scenarios The Muskeg River Mine is located 75 km north of Fort McMurray and east of the Athabasca River. First bitumen production started in December 2002 and full production is expected to yield 155 000 b/d. Combustion emissions result mainly from the mine fleet (trucks and shovels) exhausts and fugitive emissions are largely attributed to the mine surfaces and tailings pond. Albian Sands received the approval for the Muskeg River Mine Expansion on December 2006. It will be located on the west side of the Muskeg River. Expansion of Muskeg River Mine (Phase 2, or Shark Bite Project) is planned to raise total production to approximately 255 000 b/d of bitumen by 2010.

ATCO Power Ltd.

ATCO Power operates the Muskeg River Phase 1 power (cogeneration) and steam boiler facilities. The facility received approval in February 2000 and commenced operation in conjunction with the start-up of the Muskeg River Mine in 2002. The facility has not changed from what was approved for Muskeg River Phase 1 and is included with the Albian Sands sources in Table B2-1. Emissions originate from co-generation units, boilers, and heaters and this energy is primarily used for extraction and operation of the Muskeg River Mine facility with excess power provided to the Alberta electrical grid. Table B2-1 provides a summary of the emissions for Albian Sands and ATCO Power that were included in the baseline, project and planned development scenarios. ATCO Power emissions are only used for the Baseline and project scenarios.


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Table B2-1: Summary of Albian Sands & ATCO Power Existing and Approved Air Emissions Used for the Baseline, Project and Planned Development Scenarios

Point Sources

Facility Emission Source UTM E (m)

UTM N (m)

Elevation (masl)

Stack Height (m)

Stack Diameter (m)

Exit Velocity (m/s)

Exit Temp (K)

SO2

(t/d) NOX

(t/d)) CO(t/d)

VOC(t/d)

PM2.5

(t/d) Co-generator 1 469565 6346240 285 37.5 5.0 18.3 398 0.00 2.13 0.99 0.06 0.12

Co-generator 2 469580 6346240 285 37.5 5.0 18.3 398 0.00 2.13 0.99 0.06 0.12

Fuel Heater 1 469625 6346240 285 8.0 0.3 18.3 448 0.00 0.007 0.011 0.001 0.001

Fuel Heater 2 469640 6346240 285 8.0 0.3 18.3 448 0.00 0.007 0.011 0.001 0.001

Boiler 1 469600 6346125 285 37.5 2.4 18.3 448 0.00 0.95 0.62 0.06 0.08

ATCO Power (formerly Muskeg River Phase 1)

Boiler 2 469575 6346125 285 37.5 2.4 18.3 448 0.00 1.072 0.69 0.06 0.11

Boiler 3 469565 6345851 285 38.0 2.0 18.0 442 0.00 0.51 0.45 0.03 0.05

Boiler 4 469581 6345855 285 38.0 2.0 18.0 442 0.00 0.51 0.45 0.03 0.05

Boiler 5 469578 6345801 285 38.0 2.0 18.0 442 0.00 0.46 0.39 0.03 0.04

Boiler 6 469594 6345806 285 38.0 2.0 18.0 442 0.00 0.46 0.39 0.03 0.04

Boiler 7 469549 6345847 285 38.0 2.0 18.0 442 0.00 0.45 0.38 0.03 0.03

Boiler 8 469562 6345798 285 38.0 2.0 18.0 442 0.00 0.45 0.38 0.03 0.03

Muskeg River Phase 2

Fuel Heater 3 469571 6345606 285 8.0 0.3 18.0 453 0.00 0.01 0.01 0.00 0.00 Area Sources

Facility Emission Source NW UTM E

NW UTM N

NE UTM E

NE UTM N

SE UTM E

SE UTM N

SW UTM E

SW UTM N

Area (m2)

Elevation(masl)

SO2

(t/d) NOX

(t/d) CO(t/d)

VOC(t/d)

PM2.5

(t/d) Mine Fleet NW Pit 462177 6348638 465177 6348638 465177 6347138 462177 6347138 4500000 2961 0.56 20.60 19.45 2.78 0.88

Mine Fleet Lease 90 467009 6339217 469266 6339217 469266 6337208 467009 6337208 4534313 2991 0.05 1.94 1.84 0.26 0.08

Mine Fugitives NW Pit 462177 6348638 465177 6348638 465177 6347138 462177 6347138 4500000 296 0.00 0.00 0.00 8.22 0.00

Mine Fugitives Lease 90 467009 6339217 469266 6339217 469266 6337208 467009 6337208 4534313 299 0.00 0.00 0.00 0.78 0.00

Muskeg River Phase 1 & 2

Tailings Pond 464930 6344288 467538 6344288 467538 6341580 464930 6341680 6801664 284 0.00 0.00 0.00 14.38 0.00 Albian Sands/ATCO Power Air Emission Totals used for the Baseline, Project and Planned Development Scenarios 0.61 31.81 27.10 26.85 1.64

1 Elevation sunken 50 m in modelling to compensate for the mine pit.


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2.2 Birch Mountain Resources

Emissions Included in the Baseline and Project Scenarios Birch Mountain Resources has received regulatory approval to operate an open pit limestone quarry, the Muskeg Valley Quarry, approximately 5 km east of Fort McKay and immediately south of the Muskeg River Mine. Table B2-2 presents a summary of the emissions included in the baseline and project scenarios.

Emissions Included in the Planned Development Scenario Birch Mountain also has planned the Hammerstone Project which will be the successor to the Muskeg Valley Quarry. The project will include lime producing facilities with hydrated lime and milk of lime plants, as well as a cement plant and a facility to receive and regenerate spent lime produced in oil sands water treatment. Table B2-3 presents a summary of the emissions included in the Planned Development scenario.

2.3 Canadian Natural Resources Limited

Emissions Included In the Baseline and Project Scenarios Canadian Natural Resources Limited operates the Horizon Oil Sands Project and the Kirby SAGD Project. The Horizon Project includes an oil sands mine, bitumen extraction plant, a bitumen upgrader, and associated facilities. The site is located 30 km north of Fort McKay on the west side of the Athabasca River, immediately north of the Joslyn lease. The Horizon Project is planned in three phases with the initial production starting in 2008 and increasing to full production of 232 000 b/d by approximately 2012. The Kirby project is a 20 000 b/d SAGD facility located in the Christina Lake area. Table B2-4 is a summary of the emissions that were included in the baseline and project scenarios.

Emissions Included In the Baseline and Project Scenarios Planned Development case emissions for Horizon included the planned Horizon SAGD project. The emissions from Kirby are unchanged. Table B2-5 is a summary of the emissions that were included in the Planned Development scenario.


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Table B2-2: Summary of Birch Mountain Resources Air Emissions Used for the Baseline and Project Scenarios Area Source

Facility Emission Source NE UTM E

NE UTM N

SW UTM E

SW UTM N

Area (m2)

Elevation (masl)

SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Muskeg Valley Quarry Quarry 466406 6338297 466156 6338047 62500 249 0.01 0.29 0.10 0.02 0.03

Volume Sources

Facility Emission Source # of

Volume Sources

Start UTM E

Start UTM N

End UTM E

End UTM N

Elevation Range (masl)

Effective Height

(m) SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Aggregate Transport Off-Site 10 466406 6338047 467000 6340400 277 - 281 5.00 0.01 0.40 0.14 0.02 0.02 Muskeg Valley Quarry Waste & Overburden

Transport/Unloading 6 466406 6338047 467306 6339147 276 - 289 5.00 0.00 0.18 0.06 0.01 0.00

Birch Mountain Resources Air Emission Totals for Baseline and Project Scenarios 0.02 0.88 0.30 0.05 0.05


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Table B2-3: Summary of Birch Mountain Resources Air Emissions Used for the Planned Development Scenario Point Sources


UTM N (m)

Elevation (masl)

Stack Height (m)

Stack Diameter

(m)

Exit Velocity

(m/s)

Exit Temp (K)

SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC(t/d)

PM2.5 (t/d)

Activated Lime Kiln #1 466006 6338958 276 65.00 3.26 20.00 533 0.56 4.80 2.29 0.52 0.16 Quicklime Kiln #1 466034 6338924 279 65.00 1.78 20.00 563 1.49 1.20 0.65 0.15 0.05 Coke Mill Filter #1 465915 6338938 278 35.00 0.78 20.00 373 0.00 0.00 0.00 0.00 0.01 Limestone Grinding Mill #1 466041 6338942 276 35.00 1.26 20.00 293 0.00 0.00 0.00 0.00 0.02 Activated Lime Kiln #2 466006 6339008 276 65.00 3.26 20.00 533 0.56 4.80 2.29 0.52 0.16 Quicklime Kiln #2 466034 6338974 276 65.00 1.78 20.00 563 1.49 1.20 0.65 0.15 0.05 Coke Mill Filter #2 465915 6338988 278 35.00 0.78 20.00 373 0.00 0.00 0.00 0.00 0.01 Limestone Grinding Mill #2 466041 6338992 276 35.00 1.26 20.00 293 0.00 0.00 0.00 0.00 0.02 Activated Lime Kiln #3 466006 6339058 277 65.00 3.26 20.00 533 0.56 4.80 2.29 0.52 0.16 Quicklime Kiln #3 466034 6339024 276 65.00 3.10 20.00 563 4.48 3.60 1.97 0.45 0.15 Coke Mill Filter #3 465915 6339038 278 35.00 1.30 20.00 373 0.00 0.00 0.00 0.00 0.03

Lime Plant

Limestone Grinding Mill #3 466041 6339042 275 35.00 1.26 20.00 293 0.00 0.00 0.00 0.00 0.02 Mill-Kiln Filter Stack #1 466329 6338858 282 65.00 2.45 20.00 383 6.95 3.00 1.94 0.36 0.08 Coke Mill Filter #4 466285 6338846 281 35.00 0.78 20.00 373 0.00 0.00 0.00 0.00 0.01 Clinker Cooler Filter #1 466223 6338849 281 40.00 2.26 20.00 503 0.00 0.00 0.00 0.00 0.08 Clinker Dome Filter #1 466247 6338774 282 30.00 0.78 20.00 293 0.00 0.00 0.00 0.00 0.01 Air Separator Filter #1 466195 6338830 282 35.00 1.63 20.00 353 0.00 0.00 0.00 0.00 0.04

Cement Plant

Mill Filter #1 466182 6338830 282 35.00 0.78 20.00 293 0.00 0.00 0.00 0.00 0.01 Recalcining Plant Flash Recalcining Kiln 466145 6339108 275 35.00 1.46 20.00 533 0.61 0.48 0.46 0.10 0.03

Facility Emission Source NE UTM E

NE UTM N

SW UTM E

SW UTM N

Area (m2)

Elevation (masl)

SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC(t/d)

PM2.5 (t/d)

Aggregate-1 466800 6336369 466500 6336069 90000 235 0.01 0.42 0.14 0.02 0.04 Aggregate-2 465954 6336258 465765 6336069 35721 236 0.00 0.17 0.06 0.01 0.01 Aggregate-3 466198 6335683 465931 6335416 71289 250 0.01 0.34 0.11 0.02 0.03

Hammerstone Quarry

Aggregate-4 466767 6335683 466500 6335416 71289 255 0.01 0.34 0.11 0.02 0.03

Facility Emission Source # of

Volume Sources

Start UTM E

Start UTM N

End UTM E

End UTM N

Elevation Range (masl)

Effective Height

(m) SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC(t/d)

PM2.5 (t/d)

Aggregate Transport Off-Site - Unpaved Section 1 4 466198 6335550 466708 6336916 277 - 281 5.00 0.01 0.29 0.10 0.02 0.02 Aggregate Transport Off-Site - Paved Section 1 15 466708 6336916 466314 6339000 276 - 289 5.00 0.04 1.42 0.48 0.08 0.06 Aggregate Transport Off-Site - Unpaved Section 2 2 466314 6339000 466903 6339239 279 - 282 5.00 0.00 0.01 0.00 0.00 0.00 Waste & Overburden Transport/Unloading - Unpaved Section 1 9 466225 6334842 466912 6336916 277 - 281 5.00 0.01 0.58 0.19 0.03 0.01

Waste & Overburden Transport/Unloading - Paved Section 1 5 466708 6336916 466825 6338310 280 - 289 5.00 0.00 0.18 0.06 0.01 0.00

Hammerstone Expansion

Waste & Overburden Transport/Unloading - Unpaved Section 2 2 466825 6338310 467029 6338310 279 - 280 5.00 0.00 0.03 0.01 0.00 0.00

Birch Mountain Resources Air Emission Totals for Planned Development Scenario 16.80 27.66 13.81 3.00 1.31


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Table B2-4: Summary of CNRL Horizon Existing and Approved Air Emissions Used for the Baseline and Project Scenarios Point Sources


UTM N (m)

Elevation (masl)

Stack Height (m)

Stack Diameter (m)

Exit Velocity (m/s)

Exit Temp (K)

SO2 (t/d)

NOX (t/d))

CO (t/d)

VOC(t/d)

PM2.5 (t/d)

Diluent Recovery Unit 1 454784 6355374 293 30.50 3.00 6.20 474 0.04 0.30 0.25 0.02 0.02 Diluent Recovery Unit 2 454807 6355374 293 30.50 3.00 6.20 474 0.04 0.30 0.25 0.02 0.02 Diluent Recovery Unit 3 454704 6355375 293 30.50 3.00 6.20 474 0.04 0.30 0.25 0.02 0.02 Diluent Recovery Unit 4 454727 6355375 293 30.50 3.00 6.20 474 0.04 0.30 0.25 0.02 0.02 Vacuum Tower 1 454598 6355380 294 30.50 1.90 6.20 474 0.02 0.12 0.10 0.01 0.01 Vacuum Tower 2 454621 6355380 294 30.50 1.40 6.20 474 0.01 0.04 0.05 0.00 0.01 Delayed Coking Unit 1 454815 6355468 294 70.00 2.70 9.10 523 0.06 0.40 0.35 0.02 0.03 Delayed Coking Unit 2 454771 6355468 294 70.00 2.70 9.10 523 0.06 0.40 0.35 0.02 0.03 Delayed Coking Unit 3 454726 6355469 294 70.00 2.70 9.10 523 0.06 0.40 0.35 0.02 0.03 Hydrogen Plant 1 455060 6355057 294 30.50 3.90 15.00 421 0.03 1.37 1.22 0.08 0.11 Hydrogen Plant 2 455058 6354885 294 30.50 4.40 15.00 421 0.03 1.37 1.54 0.10 0.14 Naphtha Hydrotreater 1 454896 6355066 294 30.50 0.90 12.40 555 0.01 0.04 0.05 0.00 0.01 Distillate Hydrotreater 1 454580 6355069 294 30.50 1.50 11.60 799 0.02 0.11 0.09 0.01 0.01 Gas Oil Hydrotreater 1 454695 6355067 294 30.50 1.50 13.70 799 0.02 0.12 0.11 0.01 0.01 Gas Oil Hydrotreater 2 454961 6354888 294 30.50 1.30 10.00 688 0.01 0.06 0.08 0.01 0.01 Isomer Hydrotreater 1 454759 6354904 294 30.50 1.50 12.90 799 0.02 0.12 0.10 0.01 0.01 Isomer Hydrotreater 2 454758 6354893 294 30.50 1.50 12.10 799 0.02 0.11 0.10 0.01 0.01 Utility Boiler 454476 6355339 297 30.00 4.00 11.70 393 0.01 1.25 1.07 0.07 0.10 Cogeneration Unit 1 454413 6355319 298 38.00 5.50 21.70 405 0.01 2.16 1.69 0.06 0.14 Cogeneration Unit 2 454301 6355320 298 38.00 5.50 21.70 405 0.01 2.16 1.69 0.06 0.14

Horizon

Sulphur Recovery Unit 455245 6355319 293 106.70 3.40 17.00 811 14.99 0.28 0.12 0.01 0.01 Steam Generator 1 498263 6132807 732 45.50 2.00 18.30 450.00 0.33 0.47 0.40 0.03 0.04 Steam Generator 2 498263 6132791 732 45.50 2.00 18.30 450.00 0.33 0.47 0.40 0.03 0.04 Steam Generator 3 498263 6132775 732 45.50 2.00 18.30 450.00 0.33 0.47 0.40 0.03 0.04 Steam Generator 4 498312 6132807 732 45.50 2.00 18.30 450.00 0.33 0.47 0.40 0.03 0.04 Steam Generator 5 498312 6132791 732 45.50 2.00 18.30 450.00 0.33 0.47 0.40 0.03 0.04 Steam Generator 6 498312 6132775 732 45.50 2.00 18.30 450.00 0.33 0.47 0.40 0.03 0.04 Glycol Heater 498262 6132828 732 12.00 0.91 13.70 609.00 0 0.03 0.04 0.00 0.00 HP Flare 498663 6132984 730 41.59 2.39 0.50 1273.00 0 0.02 0.01 0.00 0

Kirby

LP Flare 498663 6132984 730 41.59 2.87 0.40 1273.00 0 0.02 0.01 0.00 0


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Area Sources


NW UTM N

NE UTM E

NE UTM N

SE UTM E

SE UTM N

SW UTM E

SW UTM N

Area (m2)

Elevation(masl)

SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC(t/d)

PM2.5 (t/d)

Mine Fleet 448002 6356146 451740 6356146 451740 6351868 448002 6351868 15991164 3211 0.43 33.12 20.89 4.59 1.20 Space Heating (Bitu Production) 453376 6355577 454154 6355577 454154 6355037 453376 6355037 42062 300 0.00 0.32 0.28 0.02 0.03 Space Heating (Mine) 451795 6355890 452121 6355890 452121 6355295 451795 6355295 194299 315 0.01 0.98 0.89 0.06 0.08 Space Heating (Infrastructure) 452555 6355580 453313 6355580 453313 6355103 452555 6355103 361925 304 0.01 0.82 0.78 0.05 0.07 Space Heating (Infrastructure) 454306 6354343 454712 6354343 454712 6354109 454306 6354109 95285 300 0.00 0.25 0.22 0.01 0.02 Space Heating (Infrastructure) 455625 6354711 456090 6354711 456090 6354514 455625 6354514 91515 281 0.00 0.25 0.22 0.01 0.02 Plant Fugitives 454533 6355615 455802 6355615 455802 6354851 454533 6354851 969162 300 0.00 0.00 0.00 4.13 0.00 Mine Face 448002 6356146 451740 6356146 451740 6351868 448002 6351868 15991164 321 0.00 0.00 0.00 8.46 0.00

Horizon

Tailings Pond 443556 6359810 447599 6359810 447599 6352949 443556 6352949 27739023 347 0.00 0.00 0.00 55.74 0.00 Canadian Natural Resources Limited Air Emission Totals for the Baseline and Project Scenarios 17.98 50.33 35.80 73.82 2.53 1 Elevation sunken 50 m in modelling to compensate for the mine pit.


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Table B2-5: Summary of CNRL Horizon Existing, Approved and Proposed Air Emissions Used for the Planned Development Scenario Point Sources


UTM N (m)

Elevation (masl)

Stack Height (m)

Stack Diameter (m)

Exit Velocity (m/s)

Exit Temp (K)

SO2 (t/d)

NOX (t/d))

CO(t/d)

VOC(t/d)

PM2.5 (t/d)

Diluent Recovery Unit 1 454784 6355374 293 30.50 3.00 6.20 474 0.04 0.30 0.25 0.02 0.02 Diluent Recovery Unit 2 454807 6355374 293 30.50 3.00 6.20 474 0.04 0.30 0.25 0.02 0.02 Diluent Recovery Unit 3 454704 6355375 293 30.50 3.00 6.20 474 0.04 0.30 0.25 0.02 0.02 Diluent Recovery Unit 4 454727 6355375 293 30.50 3.00 6.20 474 0.04 0.30 0.25 0.02 0.02 Vacuum Tower 1 454598 6355380 294 30.50 1.90 6.20 474 0.02 0.12 0.10 0.01 0.01 Vacuum Tower 2 454621 6355380 294 30.50 1.40 6.20 474 0.01 0.04 0.05 0.00 0.01 Delayed Coking Unit 1 454815 6355468 294 70.00 2.70 9.10 523 0.06 0.40 0.35 0.02 0.03 Delayed Coking Unit 2 454771 6355468 294 70.00 2.70 9.10 523 0.06 0.40 0.35 0.02 0.03 Delayed Coking Unit 3 454726 6355469 294 70.00 2.70 9.10 523 0.06 0.40 0.35 0.02 0.03 Hydrogen Plant 1 455060 6355057 294 30.50 3.90 15.00 421 0.03 1.37 1.22 0.08 0.11 Hydrogen Plant 2 455058 6354885 294 30.50 4.40 15.00 421 0.03 1.37 1.54 0.10 0.14 Naphtha Hydrotreater 1 454896 6355066 294 30.50 0.90 12.40 555 0.01 0.04 0.05 0.00 0.01 Distillate Hydrotreater 1 454580 6355069 294 30.50 1.50 11.60 799 0.02 0.11 0.09 0.01 0.01 Gas Oil Hydrotreater 1 454695 6355067 294 30.50 1.50 13.70 799 0.02 0.12 0.11 0.01 0.01 Gas Oil Hydrotreater 2 454961 6354888 294 30.50 1.30 10.00 688 0.01 0.06 0.08 0.01 0.01 Isomer Hydrotreater 1 454759 6354904 294 30.50 1.50 12.90 799 0.02 0.12 0.10 0.01 0.01 Isomer Hydrotreater 2 454758 6354893 294 30.50 1.50 12.10 799 0.02 0.11 0.10 0.01 0.01 Utility Boiler 454476 6355339 297 30.00 4.00 11.70 393 0.01 1.25 1.07 0.07 0.10 Cogeneration Unit 1 454413 6355319 298 38.00 5.50 21.70 405 0.01 2.16 1.69 0.06 0.14 Cogeneration Unit 2 454301 6355320 298 38.00 5.50 21.70 405 0.01 2.16 1.69 0.06 0.14

Horizon

Sulphur Recovery Unit 455245 6355319 293 106.70 3.40 17.00 811 14.99 0.28 0.12 0.01 0.01 Steam Generator 1 454700 6356500 295 27.00 1.30 27.50 553 0.08 0.42 0.41 0.04 Steam Generator 2 454720 6356500 295 27.00 1.30 27.50 553 0.08 0.42 0.41 0.00 0.04 Steam Generator 3 454740 6356500 295 27.00 1.30 27.50 553 0.08 0.42 0.41 0.00 0.04 Steam Generator 4 454760 6356500 295 27.00 1.30 27.50 553 0.08 0.42 0.41 0.00 0.04

Horizon Insitu

Steam Generator 5 454780 6356500 294 27.00 1.30 27.50 553 0.08 0.42 0.41 0.00 0.04 Steam Generator 1 498263 6132807 732 45.50 2.00 18.30 450 0.33 0.47 0.40 0.03 0.04 Steam Generator 2 498263 6132791 732 45.50 2.00 18.30 450 0.33 0.47 0.40 0.03 0.04 Steam Generator 3 498263 6132775 732 45.50 2.00 18.30 450 0.33 0.47 0.40 0.03 0.04 Steam Generator 4 498312 6132807 732 45.50 2.00 18.30 450 0.33 0.47 0.40 0.03 0.04 Steam Generator 5 498312 6132791 732 45.50 2.00 18.30 450 0.33 0.47 0.40 0.03 0.04 Steam Generator 6 498312 6132775 732 45.50 2.00 18.30 450 0.33 0.47 0.40 0.03 0.04 Glycol Heater 498262 6132828 732 12.00 0.91 13.70 609 0 0.03 0.04 0.00 0.00 HP Flare 498663 6132984 730 41.59 2.39 0.50 1273 0 0.02 0.01 0.00 0

Kirby

LP Flare 498663 6132984 730 41.59 2.87 0.40 1273 0 0.02 0.01 0.00 0


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Area Sources


NW UTM N

NE UTM E

NE UTM N

SE UTM E

SE UTM N

SW UTM E

SW UTM N

Area (m2)

Elevation(masl)

SO2 (t/d)

NOX (t/d)

CO(t/d)

VOC(t/d)

PM2.5 (t/d)

Mine Fleet 448002 6356146 451740 6356146 451740 6351868 448002 6351868 15991164 3211 0.43 33.12 20.89 4.59 1.20 Space Heating (Bitu Production) 453376 6355577 454154 6355577 454154 6355037 453376 6355037 42062 300 0.00 0.32 0.28 0.02 0.03 Space Heating (Mine) 451795 6355890 452121 6355890 452121 6355295 451795 6355295 194299 315 0.01 0.98 0.89 0.06 0.08 Space Heating (Infrastructure) 452555 6355580 453313 6355580 453313 6355103 452555 6355103 361925 304 0.01 0.82 0.78 0.05 0.07 Space Heating (Infrastructure) 454306 6354343 454712 6354343 454712 6354109 454306 6354109 95285 300 0.00 0.25 0.22 0.01 0.02 Space Heating (Infrastructure) 455625 6354711 456090 6354711 456090 6354514 455625 6354514 91515 281 0.00 0.25 0.22 0.01 0.02 Plant Fugitives 454533 6355615 455802 6355615 455802 6354851 454533 6354851 969162 300 0.00 0.00 0.00 4.13 0.00 Mine Face 448002 6356146 451740 6356146 451740 6351868 448002 6351868 15991164 321 0.00 0.00 0.00 8.46 0.00

Horizon

Tailings Pond 443556 6359810 447599 6359810 447599 6352949 443556 6352949 27739023 347 0.00 0.00 0.00 55.74 0.00 Canadian Natural Resources Limited Air Emission Totals for the Planned Development Scenarios 17.98 50.33 35.80 73.82 2.53



December 2009

Page B2-11

2.4 Connacher Oil and Gas Limited

Emissions Included In the Baseline and Project Scenarios Connacher has received the approval to develop the Great Divide SAGD Project which is located 80 km southwest of Fort McMurray. The Great Divide Project is designed for a bitumen production rate of 10 000 b/d for approximately 25 years. First production began in 2007. Table B2-6 is a summary of the emissions that were included in the baseline and project Scenarios.

Emissions Included In the Planned Development Scenario Connacher has filed for regulatory approval for its Algar Project, which represents the second stage of their Great Divide development. Similar to the project underway, Algar is a 10 000 bpd in-situ project. Table B2-7 is a summary of the emissions that were included in the Planned Development scenario.

2.5 ConocoPhillips Canada Resources Corporation

Emissions Included In the Baseline and Project Scenarios ConocoPhillips currently operates the Surmont pilot SAGD facility approximately 60 km southeast of Fort McMurray. This facility has been operating since July 2001. The Surmont pilot production capacity is approximately 2 000 b/d. ConocoPhillips has received regulatory approval for the 100 000 b/d Surmont SAGD Project which was designed in stages. The 25 000 b/d Phase 1 (of four initially contemplated phases) has been constructed and first steam began in 2006. Table B2-8 provides a summary of emissions from the existing and approved ConocoPhillips facilities included in the baseline and project scenarios.

Emissions Included in the Planned Development Scenario The Planned Development case emissions reflect the planned expansion of the Surmont facility by 75 000 b/d. Table B2-9 provides a summary of emissions from the existing, approved and proposed ConocoPhillips facilities included in the Planned Development scenario.


December 2009

Page B2-12

Table B2-6: Summary of the Connacher Existing and Approved Air Emissions Used for the Baseline and Project Scenarios Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity (m/s)

Exit Temp (K)

SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Steam Boiler 448529 6219128 710 30.3 1.68 15.62 450 0.04 0.23 0.19 – 0.02

Steam Boiler 448557 6219145 710 30.3 1.68 15.62 450 0.04 0.23 0.19 – 0.02

Utility Boiler 448609 6219097 710 10.1 0.51 8.94 495 – 0.01 0.01 – 0.00

Glycol Heater 448638 6219007 710 8.5 0.61 5.17 438 – 0.01 0.01 – 0.00

Great Divide SAGD Project

Recycle Treater 448579 6219017 710 12.2 0.25 4.01 588 – 0.01 0.00 – 0.00

Connacher Air Emission Totals used for the Baseline and Project Scenarios 0.08 0.49 0.40 – 0.04


December 2009

Page B2-13

Table B2-7: Summary of Connacher Existing, Approved and Proposed Air Emissions Used for the Planned Development Scenario Point Sources


UTM N (m)

Elevation (masl)

Stack Height (m)

Stack Diameter

(m)

Exit Velocity

(m/s)

Exit Temp (K)

SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC(t/d)

PM2.5 (t/d)

Steam Boiler 448529 6219128 710 30.3 1.68 15.62 450 0.04 0.23 0.19 – 0.02

Steam Boiler 448557 6219145 710 30.3 1.68 15.62 450 0.04 0.23 0.19 – 0.02

Utility Boiler 448609 6219097 710 10.1 0.51 8.94 495 – 0.01 0.01 – 0.00

Glycol Heater 448638 6219007 710 8.5 0.61 5.17 438 – 0.01 0.01 – 0.00

Great Divide SAGD Project

Recycle Treater 448579 6219017 710 12.2 0.25 4.01 588 – 0.01 0.00 – 0.00

Steam Boiler 455534 6218957 750 30.3 1.68 15.6 450 0.04 0.23 0.19 – 0.02

Steam Boiler 455563 6218974 750 30.3 1.68 15.6 450 0.04 0.23 0.19 – 0.02

Utility Boiler 455606 6218921 750 10.1 0.51 8.9 495 – 0.01 0.01 – 0.00

Glycol Heater 455643 6218837 750 8.5 0.61 5.2 438 – 0.01 0.01 – 0.00

Algar SAGD Project

Recycle Treater 455585 6218846 750 12.2 0.25 4 588 – 0.01 0.00 – 0.00

Connacher Air Emission Totals used for the Planned Development Scenario 0.16 0.98 0.80 – 0.08


December 2009

Page B2-14

Table B2-8: Summary of ConocoPhillips Existing and Approved Air Emissions Included in the Baseline and Project Scenarios Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s)

Exit Temp.

(K)

SO2 (t/d)

NOX (t/d)

CO (t/d)

PM2.5 (t/d)

Surmont Pilot Steam Generator 501850 6229700 595 13.3 0.9 8.3 423 0.16 0.08 0.08 0.00

Steam Generator 1 503363 6227513 642 27 1.676 20.1 469 0.02 0.17 0.27 0.02

Steam Generator 2 503363 6227528 642 27 1.676 20.1 469 0.02 0.17 0.27 0.02

Steam Generator 3 503434 6227513 642 27 1.676 20.1 469 0.02 0.17 0.27 0.02

Steam Generator 4 503434 6227528 642 27 1.676 20.1 469 0.02 0.17 0.27 0.02

Slop Treater X-240 503448 6227575 641 10.2 0.387 3.66 811 0 0.0024 0.003 0.0003

Glycol Trim Heater H-601 503440 6227633 641 15 0.898 7.84 652 0.04 0.016 0.02 0.002

Surmont Phase 1

Flare FS-701 503418 6227513 643 48.8 0.763 20 1273 0.04 0.02 0.0011 0.0016

ConocoPhillips Surmont Air Emission Totals used for the Baseline and Project Scenarios 0.32 0.80 1.18 0.08


December 2009

Page B2-15

Table B2-9: Summary of ConocoPhillips Existing, Approved and Proposed Air Emissions Included in the Planned Development Scenario Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s)

Exit Temp.

(K) SO2 (t/d)

NOX (t/d)

CO (t/d)

PM2.5 (t/d)

Surmont Pilot Steam Generator 501850 6229700 595 13.3 0.9 8.3 423 0.16 0.08 0.08 0.00 Steam Generator 1 503363 6227513 642 27 1.676 20.1 469 0.02 0.17 0.27 0.02 Steam Generator 2 503363 6227528 642 27 1.676 20.1 469 0.02 0.17 0.27 0.02 Steam Generator 3 503434 6227513 642 27 1.676 20.1 469 0.02 0.17 0.27 0.02 Steam Generator 4 503434 6227528 642 27 1.676 20.1 469 0.02 0.17 0.27 0.02 Slop Treater X-240 503448 6227575 641 10.2 0.387 3.66 811 0 0.0024 0.003 0.0003 Glycol Trim Heater H-601 503440 6227633 641 15 0.898 7.84 652 0.04 0.016 0.02 0.002

Surmont Phase 1

Flare FS-701 503418 6227513 643 48.8 0.763 20 1273 0.04 0.02 0.0011 0.0016 Steam Generator 531A 504118 6227777 620 27 1.676 20.1 469 0.02 0.17 0.27 0.02 Steam Generator 531C 504118 6227792 618 27 1.676 20.1 469 0.02 0.17 0.27 0.02 Steam Generator 531E 504118 6227807 618 27 1.676 20.1 469 0.02 0.17 0.27 0.02 Steam Generator 531G 504118 6227822 618 27 1.676 20.1 469 0.02 0.17 0.27 0.02 Steam Generator 531I 504118 6227837 618 27 1.676 20.1 469 0.02 0.17 0.27 0.02 Steam Generator 531K 504118 6227852 618 27 1.676 20.1 469 0.02 0.17 0.27 0.02 Steam Generator 531M 504118 6227867 618 27 1.676 20.1 469 0.02 0.17 0.27 0.02 Steam Generator 531B 504200 6227777 617 27 1.676 20.1 469 0.02 0.17 0.27 0.02 Steam Generator 531D 504200 6227792 617 27 1.676 20.1 469 0.02 0.17 0.27 0.02 Steam Generator 531F 504200 6227807 617 27 1.676 20.1 469 0.02 0.17 0.27 0.02 Steam Generator 531H 504200 6227822 617 27 1.676 20.1 469 0.02 0.17 0.27 0.02 Steam Generator 531J 504200 6227837 610 27 1.676 20.1 469 0.02 0.17 0.27 0.02 Steam Generator 531L 504200 6227852 610 27 1.676 20.1 469 0.02 0.17 0.27 0.02 Steam Generator 531N 504200 6227867 610 27 1.676 20.1 469 0.02 0.17 0.27 0.02 Slop Treater 2X-240 504144 6227407 629 10.2 0.387 3.66 811 0 0.0024 0.003 0.0003 Glycol Trim Heater 2H-601A 504058 6227733 620 15 0.898 7.84 652 0.04 0.016 0.02 0.002 Glycol Trim Heater 2H-601B 504058 6227741 620 15 0.898 7.84 652 0.04 0.016 0.02 0.002 Glycol Trim Heater 2H-601C 504058 6227749 620 15 0.898 7.84 652 0.04 0.016 0.02 0.002 Flare 2FS-701 504488 6227645 613 48.8 0.763 20 1273 0.04 0.02 0.0011 0.0016

Surmont Phase 2

Sulphur Plant Incinerator 504344 6227647 619 30.5 0.915 0.87 923 0.1 0.0002 0.12 0.00003 ConocoPhillips Surmont Air Emission Totals used for the Planned Development Scenario 0.86 3.25 5.15 0.37


December 2009

Page B2-16

2.6 Deer Creek Energy Limited

Emissions Included In the Baseline and Project Scenarios Deer Creek Energy Limited (DCEL, a wholly-owned subsidiary of Total Canada Ltd.) has received regulatory approval to develop its Joslyn Creek Phase II SAGD Project (12 000 b/d) and the Phase I project has been abandoned as Phase II facilities are near to being commissioned. Table B2-10 provides a summary of emissions from the approved Phase II facility that was included in the baseline and project scenarios.

Emissions Included In the Planned Development Scenario Deer Creek has submitted project s for approvals to develop a 40 000 b/d SAGD facility (Phase III), as well as a 100 000 b/d mine and bitumen extraction facility (North Mine Project) on the eastern part of its Joslyn Creek lease area. The SAGD Project was submitted in March 2005, while the North Mine Project was submitted in February 2006. Table B2-11 provides a summary of the emissions included in the Planned Development scenario.

2.7 Devon Energy Corporation

Emissions Included in Baseline, Project and Planned Development Scenarios The Devon Jackfish Project is located 15 km south of Conklin. First bitumen production is anticipated in late 2009 and full production is expected to yield 35 000 b/d. Devon applied for approval of the Jackfish 2 Project in 2006. It will be located adjacent to the Jackfish facility. Jackfish 2 is slated to produce an additional 35 000 b/d by 2010. Table B2-12 provides a summary of the emissions that were included in the baseline, project and planned development scenarios.


December 2009

Page B2-17

Table B2-10: Summary of DCEL Joslyn Creek Approved Air Emissions Used for the Baseline and Project Scenarios Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s)

Exit Temp (K)

SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Steam Generator 1 445741 6348200 348 30 3.5 5 553 0.368 0.23 0.228 0.018 0.021

Steam Generator 2 445753 6348200 348 30 3.5 5 553 0.368 0.23 0.228 0.016 0.021

Utility Boiler 445631 6348261 348 11 0.4 22.6 475 0.000 0.025 0.005 0.000 0.000

Glycol Heater 1 445778 6348220 348 5 0.5 2.1 476 0.002 0.003 0.003 0.000 0.000

Glycol Heater 2 445780 6348220 348 5 0.5 2.1 476 0.002 0.003 0.003 0.000 0.000

Glycol Heater 3 445782 6348220 348 5 0.5 2.1 476 0.002 0.003 0.003 0.000 0.000

Glycol Heater 4 445784 6348220 348 5 0.5 2.1 476 0.002 0.003 0.003 0.000 0.000

Recycle Treater 445687 6348295 348 10 0.8 2.7 476 0.000 0.011 0.005 0.000 0.000

Joslyn Phase II

Slop Heater 445688 6348272 348 4.9 0.5 3.3 476 0.000 0.006 0.002 0.000 0.000

DCEL Joslyn Creek Air Emission Totals used for the Baseline and Project Scenarios 0.74 0.51 0.48 0.03 0.04


December 2009

Page B2-18

Table B2-11: Summary of DCEL Joslyn Creek Approved and Proposed Air Emissions Used for the Planned Development Scenario

Point Sources


UTM N (m)

Elevation (masl)

Stack Height (m)

Stack Diameter (m)

Exit Velocity (m/s)

Exit Temp (K)

SO2 (t/d)

NOX (t/d))

CO (t/d)

VOC(t/d)

PM2.5 (t/d)

Steam Generator 1 445741 6348200 348 30 3.5 5 553 0.368 0.230 0.228 0.018 0.021

Steam Generator 2 445753 6348200 348 30 3.5 5 553 0.368 0.230 0.228 0.016 0.021

Utility Boiler 445631 6348261 348 11 0.4 22.6 475 0.000 0.025 0.005 0.000 0.000

Glycol Heater 1 445778 6348220 348 5 0.5 2.1 476 0.002 0.003 0.003 0.000 0.000

Glycol Heater 2 445780 6348220 348 5 0.5 2.1 476 0.002 0.003 0.003 0.000 0.000

Glycol Heater 3 445782 6348220 348 5 0.5 2.1 476 0.002 0.003 0.003 0.000 0.000

Glycol Heater 4 445784 6348220 348 5 0.5 2.1 476 0.002 0.003 0.003 0.000 0.000

Recycle Treater 445687 6348295 348 10 0.8 2.7 476 0.000 0.011 0.005 0.000 0.000

Joslyn Phase II

Slop Heater 445688 6348272 348 4.9 0.5 3.3 476 0.000 0.006 0.002 0.000 0.000

Steam Generator 1 445794 6348200 348 30 1.8 17.3 437 0.475 0.334 0.330 0.022 0.030

Steam Generator 2 445806 6348200 348 30 1.8 17.3 437 0.475 0.334 0.330 0.022 0.030

Utility Boiler 445782 6348222 348 5 0.5 8.0 533 0.000 0.012 0.005 0.000 0.000

Slop Heater 445689 6348182 348 4.9 0.5 4.1 533 0.006 0.008 0.003 0.000 0.000

Joslyn Phase III

Evaporator 445633 6348261 348 11 0.4 22.3 533 0.000 0.025 0.005 0.000 0.000

Steam Generator 1 450400 6347270 325 38 1.8 18 383 0.007 0.370 0.155 0.000 0.026

Steam Generator 2 450350 6347230 325 38 1.8 18 383 0.007 0.370 0.155 0.000 0.026

Steam Generator 3 450300 6347190 325 38 1.8 18 383 0.007 0.370 0.155 0.000 0.026

Cogenerator 450500 6347350 325 38 4.6 22 393 0.022 1.399 0.566 0.108 0.048

Joslyn North Mine

Flare Pilot 451050 6346400 325 150 1.2 n/a n/a 0.000 0.000 0.000 0.000 0.000

Area Sources


NW UTM N

NE UTM E

NE UTM N

SE UTM E

SE UTM N

SW UTM E

SW UTM N

Area (m2)

Elevation(masl)

SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC(t/d)

PM2.5 (t/d)

Mine Fleet/Fugitives 454040 6351940 456240 6351940 456240 6349380 454040 6350440 4466000 2991 0.007 10.124 8.922 3.270 0.260

Space Heat 451720 6348380 452230 6347700 450580 6346460 450070 6347130 1747200 325 0.000 0.023 0.000 0.000 0.000 Joslyn North Mine

Tailings Pond 451960 6351140 453180 6351140 453180 6349080 451960 6349080 2098400 307 0.000 0.000 0.000 43.197 0.000

DCEL Air Emission Totals for Planned Development Scenario 1.75 13.88 11.11 46.65 0.49



December 2009

Page B2-19

Table B2-12: Summary of Devon Existing, Approved and Proposed Air Emissions Included in the Project and Planned Development Scenarios

Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s)

Exit Temp (K)

SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Steam Generator 507855 6153524 624 28.90 1.83 15.50 443 0.33 0.31 0.22 0.01 0.02 Steam Generator 507846 6153515 624 28.90 1.83 15.50 443 0.33 0.31 0.22 0.01 0.02 Steam Generator 507838 6153507 624 28.90 1.83 15.50 443 0.33 0.31 0.22 0.01 0.02 Steam Generator 507830 6153498 623 28.90 1.83 15.50 443 0.33 0.31 0.22 0.01 0.02 Steam Generator 507821 6153490 623 28.90 1.83 15.50 443 0.33 0.31 0.22 0.01 0.02 Steam Generator 507813 6153481 623 28.90 1.83 15.50 443 0.33 0.31 0.22 0.01 0.02 Flash Treater 508009 6153513 625 6.00 0.15 23.20 443 0.00 0.01 0.00 0.00 0.00 Glycol Heater 508036 6153691 621 6.70 0.71 27.70 399 0.00 0.07 0.02 0.00 0.00 Glycol Heater 508028 6153684 622 6.70 0.71 27.70 399 0.00 0.07 0.02 0.00 0.00

Jackfish

Flare 508148 6153476 622 41.70 3.85 0.02 1273 0.00 0.00 0.00 0.00 0.00 Steam Generator 500304 6153067 676 28.90 1.83 15.50 443 0.33 0.31 0.22 0.01 0.02 Steam Generator 500311 6153077 676 28.90 1.83 15.50 443 0.33 0.31 0.22 0.01 0.02 Steam Generator 500318 6153086 677 28.90 1.83 15.50 443 0.33 0.31 0.22 0.01 0.02 Steam Generator 500325 6153096 677 28.90 1.83 15.50 443 0.33 0.31 0.22 0.01 0.02 Steam Generator 500332 6153106 678 28.90 1.83 15.50 443 0.33 0.31 0.22 0.01 0.02 Steam Generator 500339 6153115 678 28.90 1.83 15.50 443 0.33 0.31 0.22 0.01 0.02 Flash Treater 500150 6153054 670 6.00 0.15 23.20 443 0.00 0.01 0.00 0.00 0.00 Glycol Heater 500150 6152875 671 6.70 0.71 27.70 399 0.00 0.07 0.02 0.00 0.00 Glycol Heater 500156 6152883 671 6.70 0.71 27.70 399 0.00 0.07 0.02 0.00 0.00

Jackfish 2

Flare 500007 6153071 675 41.70 3.85 0.02 1273 0.00 0.00 0.00 0.00 0.00 Devon Energy Air Emission Totals for Baseline, Project and Planned Development Scenario 3.96 4.02 2.72 0.12 0.24


December 2009

Page B2-20

2.8 EnCana Corporation

Emissions Included In the Baseline and Project Scenarios EnCana Corporation operates the Christina Lake and Foster Creek SAGD facilities in a 50/50 joint venture with ConocoPhillips. Christina Lake is located approximately 120 km south of Fort McMurray and has been approved to produce 95 000 b/d at full capacity in 2013. Foster Creek currently produces 100 000 b/d. Table B2-13 provides a summary of the facility emission estimates included in the baseline and project scenarios.

Emissions Included in the Planned Development Scenario EnCana Corporation has initiated the regulatory approval process for its proposed Borealis Project. EnCana plans to develop a commercial scale bitumen production project based on SAGD thermal technology and will be designed and built to produce approximately 35 000 b/d of bitumen. Table B2-14 provides a summary of the facility emission estimates included in the Planned Development scenario.

2.9 Husky Energy

Emissions Included in the Baseline, Project and Planned Development Scenarios Husky has received regulatory approval for its Sunrise Thermal Project (a joint venture with BP) located approximately 60 km northeast of Fort McMurray. The SAGD development is planned in three phases and will ultimately produce 200 000 b/d of bitumen. Table B2-15 provides a summary of the emissions included in the baseline, project and planned development scenarios.

2.10 Imperial Oil/ExxonMobil

Emissions Included in the Baseline, Project and Planned Development Scenarios Imperial Oil Resources Ventures Limited (Imperial Oil) and ExxonMobil Canada Properties (ExxonMobil Canada) received the approval to develop the Kearl Oil Sands Mine Project in February 2007. The Kearl Project will be located north of Kearl Lake, approximately 70 km north of Ft. McMurray. Once all three trains are operational, the expected production capability will be about 300 000 b/d of partially de-asphalted bitumen (clean bitumen), for a maximum production rate of 345 000 b/d of clean bitumen. Table B2-16 provides a summary of the emissions included in the baseline, project and planned development scenarios.


December 2009

Page B2-21

Table B2-13: Summary of EnCana Existing and Approved Air Emissions Included in the Baseline and Project Scenarios Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s) Exit

Temp (K) SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Central Flare 506892 6159344 569 24.40 0.50 1.00 1273 0.00 0.00 0.03 0.00 0.00 Glycol Heater 506936 6159483 568 5.90 0.70 5.10 436 0.00 0.06 0.03 0.00 0.00 Steam Generator 506877 6159497 567 26.20 1.40 20.70 466 1.17 0.18 0.16 0.01 0.01 Steam Generator 506871 6159489 568 14.20 0.90 13.00 466 0.32 0.03 0.04 0.00 0.00

Christina Lake Phase 1

Heat Medium Heater 511981 6159339 571 5.50 0.90 8.80 603 0.14 0.09 0.04 0.00 0.00 Steam Generator 512041 6159469 571 25.90 1.40 13.90 459 0.57 0.18 0.16 0.01 0.01 Steam Generator 512031 6159459 571 25.90 1.40 13.90 459 0.57 0.18 0.16 0.01 0.01 Steam Generator 511911 6159169 571 25.90 1.40 13.90 459 0.57 0.18 0.16 0.01 0.01 Steam Generator 511911 6159169 571 25.90 1.40 13.90 459 0.57 0.18 0.16 0.01 0.01


Heat Medium Heater 509981 6157339 586 5.50 0.90 8.80 603 0.14 0.09 0.04 0.00 0.00 Steam Generator 510041 6157469 585 25.90 1.40 13.90 459 0.57 0.18 0.16 0.01 0.01 Steam Generator 510031 6157459 585 25.90 1.40 13.90 459 0.57 0.18 0.16 0.01 0.01 Steam Generator 509911 6157169 586 25.90 1.40 13.90 459 0.57 0.18 0.16 0.01 0.01


Steam Generator 509911 6157169 586 25.90 1.40 13.90 459 0.57 0.18 0.16 0.01 0.01 Glycol Reboiler 529411 6102733 671 6.10 0.50 4.00 672 0.00 0.00 0.00 – 0.00 Steam Generator 529490 6102769 671 6.10 0.50 4.00 672 0.07 0.15 0.05 – 0.00 Steam Generator 529490 6102760 667 25.90 3.70 21.10 448 0.07 0.15 0.05 – 0.00 Steam Generator 529490 6102747 667 25.90 3.70 21.10 448 0.07 0.04 0.05 – 0.00 Utility Boiler 529463 6102747 667 8.00 0.60 2.00 533 0.01 0.02 0.01 – 0.00 Utility Boiler 529457 6102770 668 8.20 0.80 12.00 533 0.01 0.02 0.01 – 0.00

Foster Creek Pilot

Utility Boiler 529462 6102770 668 6.60 0.40 3.60 533 0.01 0.02 0.01 – 0.00 Cogeneration 529715 6102194 666 6.60 0.40 3.60 533 0.33 0.92 0.63 – 0.05 Cogeneration 529692 6102159 659 6.60 0.40 3.60 533 0.33 0.92 0.63 – 0.05 Fuel Gas Heater 529842 6102391 674 6.60 0.40 3.60 533 0.00 0.00 0.00 – 0.00 Glycol Heater 529764 6102390 667 9.10 0.60 2.40 533 0.03 0.04 0.02 – 0.00 Wellpad Glycol Heater 528948 6102547 670 8.00 0.60 4.60 533 0.00 0.00 0.00 – 0.00 Wellpad Glycol Heater 529906 6102242 668 27.00 1.40 15.60 447 0.00 0.00 0.00 – 0.00 Wellpad Glycol Heater 530551 6102624 668 27.00 1.40 15.60 447 0.00 0.00 0.00 – 0.00 Wellpad Glycol Heater 529076 6102537 669 27.00 1.40 15.60 447 0.00 0.00 0.00 – 0.00 Gas Heater 529839 6102394 669 27.00 1.40 15.60 447 0.00 0.03 0.00 – 0.00 Hot Oil Heater 529710 6102438 668 27.00 1.40 15.60 447 0.01 0.01 0.01 – 0.00 Steam Generator 529782 6102330 671 8.20 0.80 12.00 533 0.10 0.20 0.14 – 0.02 Steam Generator 529775 6102320 671 27.00 1.70 19.70 490 0.10 0.20 0.14 – 0.02 Steam Generator 529732 6102364 671 27.00 1.70 19.70 490 0.10 0.20 0.14 – 0.02 Steam Generator 529727 6102355 673 27.00 1.70 19.70 490 0.10 0.20 0.14 – 0.02

Foster Creek Phase 1

Steam Generator 529757 6102293 671 27.00 1.70 19.70 490 0.10 0.20 0.14 – 0.02


December 2009

Page B2-22

Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s)

Exit Temp (K)

SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Glycol Heater 529830 6102620 666 7.10 0.50 6.80 950 0.00 0.04 0.00 – 0.00 Steam Generator 529850 6102623 715 7.90 0.60 3.50 533 0.00 0.25 0.00 – 0.00 Steam Generator 529858 6102635 714 9.50 0.60 8.50 533 0.00 0.25 0.00 – 0.00 Steam Generator 529801 6102683 700 8.20 0.90 1.50 533 0.00 0.25 0.00 – 0.00 Steam Generator 529867 6102648 712 24.40 1.70 21.70 482 0.00 0.25 0.00 – 0.00

Foster Creek Phase 1C

SRU Heater 529886 6102399 712 24.40 1.70 21.70 482 0.00 0.01 0.00 – 0.00 Fuel Gas Heater 538559 6100231 710 24.40 1.70 21.70 482 0.00 0.01 0.01 – 0.00 Flash Treater 538606 6100205 711 24.40 1.70 21.70 482 0.00 0.01 0.04 – 0.00 Glycol Heater 538501 6099990 708 24.40 1.70 21.70 482 0.00 0.01 0.01 – 0.00 Steam Generator 538505 6100223 709 24.40 1.70 21.70 482 0.26 0.26 0.80 – 0.02 Steam Generator 538490 6100223 671 6.10 0.50 4.00 672 0.26 0.26 0.80 – 0.02 Steam Generator 538460 6100223 671 6.10 0.50 4.00 672 0.26 0.26 0.80 – 0.02 Steam Generator 538475 6100223 667 25.90 3.70 21.10 448 0.26 0.26 0.80 – 0.02 Steam Generator 538430 6100223 667 25.90 3.70 21.10 448 0.26 0.26 0.80 – 0.02


Steam Generator 538445 6100223 667 8.00 0.60 2.00 533 0.26 0.26 0.80 – 0.02 EnCana Air Emission Totals for Baseline and Project Scenarios 9.33 7.85 8.65 0.09 0.41


December 2009

Page B2-23

Table B2-14: Summary of EnCana Existing, Approved and Proposed Air Emissions Included in the Planned Development Scenario Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s)

Exit Temp (K)

SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Central Flare 506892 6159344 569 24.40 0.50 1.00 1273 0.00 0.00 0.03 0.00 0.00 Glycol Heater 506936 6159483 568 5.90 0.70 5.10 436 0.00 0.06 0.03 0.00 0.00 Steam Generator 506877 6159497 567 26.20 1.40 20.70 466 1.17 0.18 0.16 0.01 0.01 Steam Generator 506871 6159489 568 14.20 0.90 13.00 466 0.32 0.03 0.04 0.00 0.00


Heat Medium Heater 511981 6159339 571 5.50 0.90 8.80 603 0.14 0.09 0.04 0.00 0.00 Steam Generator 512041 6159469 571 25.90 1.40 13.90 459 0.57 0.18 0.16 0.01 0.01 Steam Generator 512031 6159459 571 25.90 1.40 13.90 459 0.57 0.18 0.16 0.01 0.01 Steam Generator 511911 6159169 571 25.90 1.40 13.90 459 0.57 0.18 0.16 0.01 0.01 Steam Generator 511911 6159169 571 25.90 1.40 13.90 459 0.57 0.18 0.16 0.01 0.01


Heat Medium Heater 509981 6157339 586 5.50 0.90 8.80 603 0.14 0.09 0.04 0.00 0.00 Steam Generator 510041 6157469 585 25.90 1.40 13.90 459 0.57 0.18 0.16 0.01 0.01 Steam Generator 510031 6157459 585 25.90 1.40 13.90 459 0.57 0.18 0.16 0.01 0.01 Steam Generator 509911 6157169 586 25.90 1.40 13.90 459 0.57 0.18 0.16 0.01 0.01


Steam Generator 509911 6157169 586 25.90 1.40 13.90 459 0.57 0.18 0.16 0.01 0.01 Glycol Reboiler 529411 6102733 671 6.10 0.50 4.00 672 0.00 0.00 0.00 - 0.00 Steam Generator 529490 6102769 671 6.10 0.50 4.00 672 0.07 0.15 0.05 - 0.00 Steam Generator 529490 6102760 667 25.90 3.70 21.10 448 0.07 0.15 0.05 - 0.00 Steam Generator 529490 6102747 667 25.90 3.70 21.10 448 0.07 0.04 0.05 - 0.00 Utility Boiler 529463 6102747 667 8.00 0.60 2.00 533 0.01 0.02 0.01 - 0.00 Utility Boiler 529457 6102770 668 8.20 0.80 12.00 533 0.01 0.02 0.01 - 0.00

Foster Creek Pilot

Utility Boiler 529462 6102770 668 6.60 0.40 3.60 533 0.01 0.02 0.01 - 0.00 Cogeneration 529715 6102194 666 6.60 0.40 3.60 533 0.33 0.92 0.63 - 0.05 Cogeneration 529692 6102159 659 6.60 0.40 3.60 533 0.33 0.92 0.63 - 0.05 Fuel Gas Heater 529842 6102391 674 6.60 0.40 3.60 533 0.00 0.00 0.00 - 0.00 Glycol Heater 529764 6102390 667 9.10 0.60 2.40 533 0.03 0.04 0.02 - 0.00 Wellpad Glycol Heater 528948 6102547 670 8.00 0.60 4.60 533 0.00 0.00 0.00 - 0.00 Wellpad Glycol Heater 529906 6102242 668 27.00 1.40 15.60 447 0.00 0.00 0.00 - 0.00 Wellpad Glycol Heater 530551 6102624 668 27.00 1.40 15.60 447 0.00 0.00 0.00 - 0.00 Wellpad Glycol Heater 529076 6102537 669 27.00 1.40 15.60 447 0.00 0.00 0.00 - 0.00 Gas Heater 529839 6102394 669 27.00 1.40 15.60 447 0.00 0.03 0.00 - 0.00 Hot Oil Heater 529710 6102438 668 27.00 1.40 15.60 447 0.01 0.01 0.01 - 0.00 Steam Generator 529782 6102330 671 8.20 0.80 12.00 533 0.10 0.20 0.14 - 0.02 Steam Generator 529775 6102320 671 27.00 1.70 19.70 490 0.10 0.20 0.14 - 0.02 Steam Generator 529732 6102364 671 27.00 1.70 19.70 490 0.10 0.20 0.14 - 0.02 Steam Generator 529727 6102355 673 27.00 1.70 19.70 490 0.10 0.20 0.14 - 0.02


Steam Generator 529757 6102293 671 27.00 1.70 19.70 490 0.10 0.20 0.14 - 0.02


December 2009

Page B2-24

Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s) Exit

Temp (K) SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Glycol Heater 529830 6102620 666 7.10 0.50 6.80 950 0.00 0.04 0.00 - 0.00 Steam Generator 529850 6102623 715 7.90 0.60 3.50 533 0.00 0.25 0.00 - 0.00 Steam Generator 529858 6102635 714 9.50 0.60 8.50 533 0.00 0.25 0.00 - 0.00 Steam Generator 529801 6102683 700 8.20 0.90 1.50 533 0.00 0.25 0.00 - 0.00 Steam Generator 529867 6102648 712 24.40 1.70 21.70 482 0.00 0.25 0.00 - 0.00

Foster Creek Phase 1C

SRU Heater 529886 6102399 712 24.40 1.70 21.70 482 0.00 0.01 0.00 - 0.00 Fuel Gas Heater 538559 6100231 710 24.40 1.70 21.70 482 0.00 0.01 0.01 - 0.00 Flash Treater 538606 6100205 711 24.40 1.70 21.70 482 0.00 0.01 0.04 - 0.00 Glycol Heater 538501 6099990 708 24.40 1.70 21.70 482 0.00 0.01 0.01 - 0.00 Steam Generator 538505 6100223 709 24.40 1.70 21.70 482 0.26 0.26 0.80 - 0.02 Steam Generator 538490 6100223 671 6.10 0.50 4.00 672 0.26 0.26 0.80 - 0.02 Steam Generator 538460 6100223 671 6.10 0.50 4.00 672 0.26 0.26 0.80 - 0.02 Steam Generator 538475 6100223 667 25.90 3.70 21.10 448 0.26 0.26 0.80 - 0.02 Steam Generator 538430 6100223 667 25.90 3.70 21.10 448 0.26 0.26 0.80 - 0.02


Steam Generator 538445 6100223 667 8.00 0.60 2.00 533 0.26 0.26 0.80 - 0.02 Glycol Heater 537806 6336806 510 8.2 1.457 4.1 580 0.0002 0.0216 0.0344 0.002 0.0027 Steam Generator 537669 6337094 510 27.0 1.68 19.71 490 0.3309 0.2791 0.2602 0.017 0.0229 Steam Generator 537684 6337094 510 27.0 1.68 19.71 490 0.3309 0.2791 0.2602 0.017 0.0229 Steam Generator 537699 6337094 510 27.0 1.68 19.71 490 0.3309 0.2791 0.2602 0.017 0.0229 Steam Generator 537714 6337094 510 27.0 1.68 19.71 490 0.3309 0.2791 0.2602 0.017 0.0229 Flash Treater Reheater 537835 6337129 510 9.5 0.62 14.1 889 0.0001 0.0088 0.0067 0.001 0.0010

EnCana Borealis

Air Compressor 536771 6339494 520 6.2 0.3 35.8 720 0.029 0.213 0.117 0.011 0.007 EnCana Air Emission Totals for Planned Development Scenario 10.68 9.21 9.85 0.17 0.51


December 2009

Page B2-25

Table B2-15: Summary of Husky Sunrise Air Emissions Used for the Baseline, Project and Planned Development Scenarios Point Sources


UTM N (m)

Elevation (masl)

Stack Height (m)

Stack Diameter (m)

Exit Velocity (m/s)

Exit Temp (K)

SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Steam Generator 496251 6344268 484 27.00 1.65 24.00 458 0.05 0.29 0.90 0.00 0.00 Steam Generator 496251 6344254 484 27.00 1.65 24.00 458 0.05 0.29 0.90 0.00 0.00 Steam Generator 496251 6344240 484 27.00 1.65 24.00 458 0.05 0.29 0.90 0.00 0.00 Steam Generator 496251 6344226 484 27.00 1.65 24.00 458 0.05 0.29 0.90 0.00 0.00 Steam Generator 496251 6344212 484 27.00 1.65 24.00 458 0.05 0.29 0.90 0.00 0.00 Steam Generator 496251 6344198 484 27.00 1.65 24.00 458 0.05 0.29 0.90 0.00 0.00 Glycol Heater 496234 6344291 484 14.80 1.16 7.10 473 0.00 0.03 0.11 0.00 0.00 Glycol Heater 496235 6344279 484 14.80 1.16 7.10 473 0.00 0.03 0.11 0.00 0.00 HP Flare 495935 6344467 486 40.00 0.25 1.00 1273 0.00 0.00 0.00 0.02 0.00

Sunrise Stage 1

LP Flare 495935 6344467 486 40.00 0.31 1.00 1273 0.00 0.00 0.00 0.02 0.00 Steam Generator 496482 6344247 486 27.00 1.65 24.00 458 0.05 0.29 0.90 0.00 0.00 Steam Generator 496482 6344233 486 27.00 1.65 24.00 458 0.05 0.29 0.90 0.00 0.00 Steam Generator 496482 6344219 486 27.00 1.65 24.00 458 0.05 0.29 0.90 0.00 0.00 Steam Generator 496482 6344205 486 27.00 1.65 24.00 458 0.05 0.29 0.90 0.00 0.00 Steam Generator 496482 6344191 486 27.00 1.65 24.00 458 0.05 0.29 0.90 0.00 0.00 Steam Generator 496482 6344177 486 27.00 1.65 24.00 458 0.05 0.29 0.90 0.00 0.00 Steam Generator 496482 6344163 486 27.00 1.65 24.00 458 0.05 0.29 0.90 0.00 0.00 Steam Generator 496482 6344149 486 27.00 1.65 24.00 458 0.05 0.29 0.90 0.00 0.00 Glycol Heater 496498 6344271 486 14.80 1.16 10.65 473 0.00 0.05 0.16 0.00 0.00 Glycol Heater 496498 6344258 486 14.80 1.16 10.65 473 0.00 0.05 0.16 0.00 0.00 HP Flare 496797 6344467 490 40.00 0.25 1.00 1273 0.00 0.01 0.00 0.04 0.00

Sunrise Stage 2

LP Flare 496797 6344467 490 40.00 0.31 1.00 1273 0.00 0.01 0.00 0.04 0.00 Steam Generator 496482 6344076 486 27.00 1.65 24.00 458 0.05 0.29 0.90 0.00 0.00 Steam Generator 496482 6344062 486 27.00 1.65 24.00 458 0.05 0.29 0.90 0.00 0.00 Steam Generator 496482 6344048 486 27.00 1.65 24.00 458 0.05 0.29 0.90 0.00 0.00 Steam Generator 496482 6344034 486 27.00 1.65 24.00 458 0.05 0.29 0.90 0.00 0.00 Steam Generator 496482 6344020 486 27.00 1.65 24.00 458 0.05 0.29 0.90 0.00 0.00 Steam Generator 496482 6344006 486 27.00 1.65 24.00 458 0.05 0.29 0.90 0.00 0.00 Steam Generator 496482 6343992 486 27.00 1.65 24.00 458 0.05 0.29 0.90 0.00 0.00 Steam Generator 496482 6343978 486 27.00 1.65 24.00 458 0.05 0.29 0.90 0.00 0.00 Glycol Heater 496498 6343966 486 14.80 1.16 10.65 473 0.00 0.05 0.16 0.00 0.00 Glycol Heater 496498 6343955 486 14.80 1.16 10.65 473 0.00 0.05 0.16 0.00 0.00 HP Flare 496797 6343757 492 40.00 0.25 1.00 1273 0.00 0.01 0.00 0.04 0.00

Sunrise Stage 3

LP Flare 496797 6343757 492 40.00 0.31 1.00 1273 0.00 0.01 0.00 0.04 0.00 Husky Air Emission Totals for Baseline, Project and Planned Development Scenario 1.10 6.68 20.66 0.20 0.00


December 2009

Page B2-26

Table B2-16: Summary of IOL/ExxonMobil Approved Kearl Air Emissions Used for the Baseline, Project and Planned Development Scenarios

Point Sources


UTM N (m)

Elevation (masl)

Stack Height (m)

Stack Diameter (m)

Exit Velocity (m/s)

Exit Temp (K)

SO2 (t/d)

NOX (t/d))

CO (t/d)

VOC(t/d)

PM2.5 (t/d)

Cogeneration Unit 1 496039 6362017 372 30.0 5.0 18.3 387 0.01 2.19 1.38 0.06 0.12



Auxiliary Boiler 1 495784 6362017 372 30.0 3.5 17.0 387 0.01 1.56 1.23 0.08 0.11

Steam Generator 495784 6362117 372 30.0 3.5 17.0 387 0.01 1.56 1.23 0.08 0.11

Kearl

Steam Generator 495784 6362217 372 30.0 3.5 17.0 387 0.01 1.56 1.23 0.08 0.11

Area Sources


NW UTM N

NE UTM E

NE UTM N

SE UTM E

SE UTM N

SW UTM E

SW UTM N

Area (m2)

Elevation(masl)

SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC(t/d)

PM2.5 (t/d)

Space Heating Plant 495000 6362500 496500 6362500 496500 6361500 495000 6361500 1500000 369 0.002 0.58 0.26 0.02 0.02

Space Heating Mine 496001 6361486 496417 6361486 496621 6360774 496237 6360664 319184 3761 0.02 2.41 2.47 0.17 0.23

Mine Fleet - Area North 1 489088 6365143 490112 6365143 490042 6361857 489229 6361839 3027544 2961 0.06 3.01 1.91 1.54 0.11





Tailings Pond Fugitives 492298 6366023 499117 6366091 499173 6362866 494246 6362754 19160717 354 0.00 0.00 0.00 137.95 0.00

Kearl

Plant Fugitives 495000 6362500 496500 6362500 496500 6361500 495000 6361500 1500000 369 0.00 0.00 0.00 3.55 0.00

IOL/ExxonMobil Kearl Air Emission Totals for Baseline, Project and Planned Development Scenarios 0.66 42.68 28.61 156.71 1.96 1 Elevation sunken 50 m in modelling to compensate for the mine pit.


December 2009

Page B2-27

2.11 Japan Canada Oil Sands

Emissions Included in the Baseline and Project Scenarios JACOS has been operating the Hangingstone Demonstration Project since 1997. The pilot project produces approximately 11 000 b/d of bitumen using SAGD technology. The Hangingstone site is located approximately 50 km southwest of Fort McMurray. Table B2-17 provides a summary of the emissions that were included in the baseline and project scenarios.

Emissions Included in the Planned Development Scenario JACOS plans to develop a commercial SAGD recovery facility located approximately 5 km southwest of the Hangingstone Demonstration Project site. Production capacity for the project is expected to be 35 000 b/d. Table B2-18 provides a summary of the emissions that were included in the Planned Development scenario.

2.12 MEG Energy Corporation

Emissions Included in the Baseline and Project Scenarios MEG has been operating the Christina Lake Regional Project. Currently Phase 1 is operational and Phase 2 has received regulatory approval and is under construction. Phase 2 will bring total production to 60 000 b/d. Table B2-19 provides a summary of the emissions that were included in the baseline and project scenarios.

Emissions Included in the Planned Development Scenario MEG plans to expand the existing facility in Phase 3 to produce an additional 150 000 b/d. Table B2-20 provides a summary of the emissions that were included in the Planned Development scenario.

2.13 Northland Forest Products

Emissions Included in the Baseline, Project and Planned Development Scenarios Northlands Forest Products operates a sawmill in the RSA. The facility is located approximately 15 km north of Fort McMurray. Table B2-21 provides a summary of the emissions from this facility that are included in all three scenarios.


December 2009

Page B2-28

Table B2-17: Summary of JACOS Existing Air Emissions Used for the Baseline and Project Scenarios Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s)

Exit Temp

(K)

SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC(t/d)

PM2.5 (t/d)

Glycol Heater H-701 460340 6241771 563 9.0 0.5 4.5 416 0.00 0.01 0.01 0.00 0.00 HP Flare FS-701N Continuous 460367 6241846 563 27.4 2.0 0.6 1273 0.16 0.00 0.01 0.00 0.00

LP Flare FS-702 Continuous 460353 6241838 563 21.0 1.8 0.4 1273 0.03 0.00 0.00 0.00 0.00

Line Heater H-702 460401 6241713 563 12.0 0.5 2.6 416 0.00 0.01 0.00 0.00 0.00

Steam Generator B-201A 460379 6241764 563 12.0 0.9 9.3 416 0.00 0.10 0.05 0.00 0.00

Hangingstone Phase 1

Steam Generator B-201B 460377 6241755 563 12.0 0.9 9.3 416 0.00 0.10 0.05 0.00 0.00

Hangingstone Phase 2 Steam Generator B-510 460798 6241556 567 30.0 1.4 20.8 475 0.00 0.22 0.16 0.01 0.01 HP Flare 801 Continuous 460787 6241403 567 21.4 2.0 3.1 1273 0.60 0.01 0.05 0.01 0.00 LP Flare 804 Continuous 460787 6241402 567 20.1 2.0 0.9 1273 0.02 0.00 0.02 0.00 0.00 Hangingstone Phase 2+3 Glycol Heater H-755 460765 6241530 567 9.0 0.4 17.6 578 0.00 0.01 0.01 0.00 0.00

Hangingstone Phase 3 Steam Generator B-520 460813 6241556 567 30.0 1.4 20.8 475 0.00 0.22 0.16 0.01 0.01 Japan Canada Oil Sands Emission Totals used for the Baseline and Project Scenarios 0.81 0.68 0.52 0.03 0.02


December 2009

Page B2-29

Table B2-18: Summary of JACOS Existing and Proposed Air Emissions Used for the Planned Development Scenario Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s)

Exit Temp

(K) SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC(t/d)

PM2.5 (t/d)

Glycol Heater H-701 460340 6241771 563 9.0 0.5 4.5 416 0.00 0.01 0.01 0.00 0.00 HP Flare FS-701N Continuous 460367 6241846 563 27.4 2.0 0.6 1273 0.16 0.00 0.01 0.00 0.00

LP Flare FS-702 Continuous 460353 6241838 563 21.0 1.8 0.4 1273 0.03 0.00 0.00 0.00 0.00

Line Heater H-702 460401 6241713 563 12.0 0.5 2.6 416 0.00 0.01 0.00 0.00 0.00

Steam Generator B-201A 460379 6241764 563 12.0 0.9 9.3 416 0.00 0.10 0.05 0.00 0.00

Hangingstone Phase 1

Steam Generator B-201B 460377 6241755 563 12.0 0.9 9.3 416 0.00 0.10 0.05 0.00 0.00 Hangingstone Phase 2 Steam Generator B-510 460798 6241556 567 30.0 1.4 20.8 475 0.00 0.22 0.16 0.01 0.01

HP Flare 801 Continuous 460787 6241403 567 21.4 2.0 3.1 1273 0.60 0.01 0.05 0.01 0.00 LP Flare 804 Continuous 460787 6241402 567 20.1 2.0 0.9 1273 0.02 0.00 0.02 0.00 0.00 Hangingstone Phase 2+3

Glycol Heater H-755 460765 6241530 567 9.0 0.4 17.6 578 0.00 0.01 0.01 0.00 0.00 Hangingstone Phase 3 Steam Generator B-520 460813 6241556 567 30.0 1.4 20.8 475 0.00 0.22 0.16 0.01 0.01

Cogen/HRSG GT-500/B-505 459789 6239133 580 24.5 5.2 20.5 419 0.85 1.59 0.83 0.46 0.11 Cogen/HRSG GT-510/B-515 459758 6239133 580 24.5 5.2 20.5 419 0.85 1.59 0.83 0.46 0.11

Dehy. Incinerator I-270 459555 6239059 580 10.7 1.2 7.9 1088 0.05 0.02 0.01 0.00 0.00

HP Flare/FL800c Cont. purge & pilot 459382 6239123 580 43.3 3.7 0.2 1273 0.00 0.00 0.01 0.00 0.00

LP Flare/FL801 Cont. purge & pilot 459382 6239123 580 42.7 2.0 0.2 1273 0.00 0.00 0.00 0.00 0.00

Heat Medium Heater H902A 459537 6239060 580 5.9 0.6 10.7 482 0.00 0.01 0.02 0.00 0.00

Heat Medium Heater H902B 459531 6239060 580 5.9 0.6 10.7 482 0.00 0.01 0.02 0.00 0.00

OTSG B-520 459735 6239089 580 29.7 1.5 18.2 475 0.46 0.22 0.84 0.01 0.01

OTSG B-530 459717 6239090 580 29.7 1.5 18.2 475 0.46 0.22 0.84 0.01 0.01

Hangingstone Commercial

OTSG B-540 459701 6239089 580 29.7 1.5 18.2 475 0.46 0.22 0.84 0.01 0.01 Japan Canada Oil Sands Emission Totals for Planned Development Scenario 3.94 4.56 4.76 0.98 0.27


December 2009

Page B2-30

Table B2-19: Summary of MEG Existing and Approved Air Emissions Used for the Baseline and Project Scenarios Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s)

Exit Temp

(K)

SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC(t/d)

PM2.5 (t/d)

Steam Generator 517796 6168843 579 30.00 1.38 20.70 445 0.00 0.20 0.18 0.01 0.02 Glycol Heater 517826 6168816 579 7.50 0.51 4.50 434 0.00 0.01 0.01 0.00 0.00 LP Flare 517870 6168764 579 13.16 2.40 0.20 1273 0.00 0.00 0.01 0.00 0.00 HP Flare 517850 6168732 579 31.46 2.88 0.10 1273 0.00 0.00 0.01 0.00 0.00

Pilot/Phase 1

SRU Incinerator 517929 6168916 579 45.70 0.61 6.90 873 1.00 0.00 0.00 0.00 0.00 Steam Generator 517772 6168836 579 30.00 1.68 19.70 445 0.00 0.28 0.25 0.02 0.02 Cogeneration 517704 6168835 579 24.00 5.18 21.40 437 0.01 2.45 1.43 0.05 0.12 Glycol Heater 517816 6168886 579 5.00 1.02 5.80 434 0.00 0.02 0.03 0.00 0.00 Slop Treater 1 517867 6168901 579 9.00 0.61 5.30 533 0.00 0.00 0.01 0.00 0.00 Slop Treater 2 517867 6168900 579 9.00 0.61 5.30 533 0.00 0.00 0.01 0.00 0.00 Flare 517874 6169058 579 55.17 5.75 0.00 1273 0.00 0.00 0.01 0.00 0.00

Phase 2

SRU Incinerator 517950 6168923 579 80.00 0.41 18.30 873 0.84 0.00 0.00 0.00 0.00 Steam Generator 1 517373 6169140 579 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 2 517378 6169122 579 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 3 517383 6169105 579 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Cogeneration 517632 6168815 579 24.00 5.18 21.40 437 0.01 2.45 1.43 0.05 0.12 Glycol Heater 517639 6169235 579 15.00 1.52 9.50 618 0.00 0.05 0.07 0.01 0.01 Amine Preheater 517917 6168990 579 15.00 0.31 76.30 533 0.00 0.02 0.03 0.00 0.00

Phase 2B

Flare 517860 6168109 579 55.18 7.19 0.00 1273 0.00 0.00 0.01 0.00 0.00 MEG Energy Emission Totals used for the Baseline and Project Scenarios 1.87 6.48 4.33 0.21 0.37


December 2009

Page B2-31

Table B2-20: Summary of MEG Existing, Approved and Proposed Air Emissions Used for the Planned Development Scenario Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s)

Exit Temp

(K)

SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC(t/d)

PM2.5 (t/d)

Steam Generator 517796 6168843 579 30.00 1.38 20.70 445 0.00 0.20 0.18 0.01 0.02 Glycol Heater 517826 6168816 579 7.50 0.51 4.50 434 0.00 0.01 0.01 0.00 0.00 LP Flare 517870 6168764 579 13.16 2.40 0.20 1273 0.00 0.00 0.01 0.00 0.00 HP Flare 517850 6168732 579 31.46 2.88 0.10 1273 0.00 0.00 0.01 0.00 0.00

Pilot/Phase 1

SRU Incinerator 517929 6168916 579 45.70 0.61 6.90 873 1.00 0.00 0.00 0.00 0.00 Steam Generator 517772 6168836 579 30.00 1.68 19.70 445 0.00 0.28 0.25 0.02 0.02 Cogeneration 517704 6168835 579 24.00 5.18 21.40 437 0.01 2.45 1.43 0.05 0.12 Glycol Heater 517816 6168886 579 5.00 1.02 5.80 434 0.00 0.02 0.03 0.00 0.00 Slop Treater 1 517867 6168901 579 9.00 0.61 5.30 533 0.00 0.00 0.01 0.00 0.00 Slop Treater 2 517867 6168900 579 9.00 0.61 5.30 533 0.00 0.00 0.01 0.00 0.00 Flare 517874 6169058 579 55.17 5.75 0.00 1273 0.00 0.00 0.01 0.00 0.00

Phase 2

SRU Incinerator 517950 6168923 579 80.00 0.41 18.30 873 0.84 0.00 0.00 0.00 0.00 Steam Generator 1 517373 6169140 579 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 2 517378 6169122 579 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 3 517383 6169105 579 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Cogeneration 517632 6168815 579 24.00 5.18 21.40 437 0.01 2.45 1.43 0.05 0.12 Glycol Heater 517639 6169235 579 15.00 1.52 9.50 618 0.00 0.05 0.07 0.01 0.01 Amine Preheater 517917 6168990 579 15.00 0.31 76.30 533 0.00 0.02 0.03 0.00 0.00

Phase 2B

Flare 517860 6168109 579 55.18 7.19 0.00 1273 0.00 0.00 0.01 0.00 0.00 Steam Generator 1 525543 6162802 607 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 2 525543 6162785 607 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 3 525543 6162767 607 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 4 525543 6162750 608 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 5 525543 6162732 608 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 6 525543 6162714 608 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 7 525543 6162696 608 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 8 525542 6162595 609 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 9 525543 6162578 609 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 10 525543 6162560 609 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 11 525543 6162542 609 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 12 525543 6162525 609 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 13 525542 6162507 610 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 14 525542 6162489 610 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Glycol Heater 1 525800 6162663 610 15.00 1.52 10.20 618 0.00 0.06 0.08 0.01 0.01 Glycol Heater 2 525801 6162627 610 15.00 1.52 10.20 618 0.00 0.06 0.08 0.01 0.01 Slop Treater 1A 526028 6162662 608 15.00 0.61 5.70 533 0.00 0.00 0.01 0.00 0.00

Phase 3A

Slop Treater 1B 526028 6162661 608 15.00 0.61 5.70 533 0.00 0.00 0.01 0.00 0.00


December 2009

Page B2-32

Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s)

Exit Temp

(K)

SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC(t/d)

PM2.5 (t/d)

Slop Treater 2A 526097 6162662 607 15.00 0.61 5.70 533 0.00 0.00 0.01 0.00 0.00 Slop Treater 2B 526097 6162661 607 15.00 0.61 5.70 533 0.00 0.00 0.01 0.00 0.00 Amine Preheater 1 525844 6162684 609 15.00 0.31 29.80 533 0.00 0.01 0.02 0.00 0.00 Amine Preheater 2 525843 6162609 610 15.00 0.31 29.80 533 0.00 0.01 0.02 0.00 0.00 Flare 1 526002 6162859 607 55.22 7.19 0.00 1273 0.00 0.00 0.01 0.00 0.00

Phase 3A (cont)

Flare 2 526002 6162432 609 55.22 7.19 0.00 1273 0.00 0.00 0.01 0.00 0.00 Steam Generator 1 506443 6174903 602 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 2 506443 6174885 602 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 3 506443 6174867 602 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 4 506443 6174850 602 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 5 506443 6174832 602 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 6 506443 6174814 602 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 7 506443 6174796 602 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 8 506442 6174695 601 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 9 506442 6174678 601 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 10 506442 6174660 601 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 11 506443 6174642 601 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 12 506443 6174625 601 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 13 506443 6174607 601 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Steam Generator 14 506442 6174589 600 30.00 1.96 17.00 444 0.00 0.33 0.29 0.02 0.03 Glycol Heater 1 506700 6174763 603 15.00 1.52 10.20 618 0.00 0.06 0.08 0.01 0.01 Glycol Heater 2 506701 6174727 603 15.00 1.52 10.20 618 0.00 0.06 0.08 0.01 0.01 Slop Treater 1A 506928 6174762 605 15.00 0.61 5.70 533 0.00 0.00 0.01 0.00 0.00 Slop Treater 1B 506928 6174761 605 15.00 0.61 5.70 533 0.00 0.00 0.01 0.00 0.00 Slop Treater 2A 506997 6174762 605 15.00 0.61 5.70 533 0.00 0.00 0.01 0.00 0.00 Slop Treater 2B 506997 6174761 605 15.00 0.61 5.70 533 0.00 0.00 0.01 0.00 0.00 Amine Preheater 1 506745 6174783 604 15.00 0.31 29.80 533 0.00 0.01 0.02 0.00 0.00 Amine Preheater 2 506745 6174708 603 15.00 0.31 29.80 533 0.00 0.01 0.02 0.00 0.00 Flare 1 506902 6174959 606 55.22 7.19 0.00 1273 0.00 0.00 0.01 0.00 0.00 Flare 2 506902 6174532 602 55.22 7.19 0.00 1273 0.00 0.00 0.01 0.00 0.00

Phase 3B

SRU Incinerator 517967 6168927 579 80.00 0.41 18.30 873 0.84 0.00 0.00 0.00 0.00 MEG Energy Emission Totals used for the Planned Development Scenario 2.80 16.09 12.99 0.77 1.16


December 2009

Page B2-33

Table B2-21: Summary of Northlands Forest Products Existing Air Emissions Included in the Baseline, Project and Planned Development Scenarios

Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s)

Exit Temp

(K)

SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Fort McMurray Sawmill Beehive Burner 473110 6303164 249 24.0 11.0 3.0 773 0.02 0.19 25.00 1.71 0.19

Northlands Forest Products Air Emission Totals for the Baseline, Project and Planned Development Scenarios 0.02 0.19 25.00 1.71 0.19


December 2009

Page B2-34

2.14 OPTI Canada/Nexen Canada Limited Emissions Included in the Baseline and Project Scenarios Joint-venture partners OPTI Canada and Nexen Canada received regulatory approval for the Long Lake Project during the fall of 2003. It includes a bitumen SAGD recovery unit and upgrading facility located approximately 40 km southeast of Fort McMurray. The Long Lake Project is designed to support approximately 70 000 b/d bitumen production and 140 000 b/d of upgrading capacity. Table B2-22 provides a summary of the emissions that were included in the baseline and project scenarios. Emissions Included in the Planned Development Scenario The proposed Long Lake South Project (to be developed in two phases) will be located approximately 11 km south of the Long Lake Project, and is targeted to produce an additional 70 000 b/d of bitumen. The Long Lake South Project will consist of horizontal well pairs, related processing facilities and cogen facilities. Table B2-23 provides a summary of the emissions that were included in the Planned Development scenario. 2.15 Petro-Canada Emissions Included in the Baseline and Project Scenarios

• MacKay River Emissions – The MacKay River SAGD Project is designed with a production capacity of 30 000 b/d and is currently operating. The facility is located approximately 17 km west of the Syncrude Mildred Lake plant.

• Meadow Creek Emissions – The Meadow Creek SAGD Project is an approved project that is 45 km south of Fort McMurray. The project is expected to produce 80 000 b/d of bitumen.

• Petro-Canada/UTS Fort Hills – The Fort Hills Project is an approved project that is 90 km north of Fort McMurray. The project is expected to produce 190 000 b/d of bitumen.

Table B2-24 provides a summary of the emissions that were included in the baseline and project scenarios. Emissions Included in the Planned Development Scenario • MacKay River Expansion Emissions – Petro-Canada has submitted a project for

MacKay River Expansion. This will allow the expanded MacKay River development to produce 73 000 b/d of bitumen.

• Lewis Emissions – Petro-Canada has proposed to develop the Lewis Project 34 km southeast of the Syncrude Mildred Lake plant. Lewis is expected to produce 60 000 b/d of bitumen.

Table B2-25 provides a summary of the emissions included in the Planned Development scenario.


December 2009

Page B2-35

Table B2-22: Summary of OPTI/Nexen Approved Air Emissions Included in the Baseline and Project Scenarios Point Sources

Facility Emissions Source UTM E (m)

UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s)

Exit Temp

(K)

SO2 (t/d)

NOx (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Cogen Unit 1 503159 6251532 504 30.0 5.18 18.2 433 0.590 2.420 1.830 0.080 0.130 Cogen Unit 2 503193 6251498 504 30.0 5.18 18.2 433 0.590 2.420 1.830 0.080 0.130 Steam Generator 1 503237 6251626 504 30.0 1.68 18.8 464 0.090 0.320 0.280 0.020 0.030 Steam Generator 2 503248 6251616 504 30.0 1.68 18.8 464 0.090 0.320 0.280 0.020 0.030 Steam Generator 3 503258 6251605 504 30.0 1.68 18.8 464 0.090 0.320 0.280 0.020 0.030 Steam Generator 4 503270 6251593 504 30.0 1.68 18.8 464 0.090 0.320 0.280 0.020 0.030 Steam Generator 5 502738 6251665 501 30.0 1.68 18.8 464 0.090 0.320 0.280 0.020 0.030 Steam Generator 6 502750 6251654 501 30.0 1.68 18.8 464 0.090 0.320 0.280 0.020 0.030 Steam Generator 7 502761 6251643 501 30.0 1.68 18.8 464 0.090 0.320 0.280 0.020 0.030 Glycol Heater 503164 6251722 495 30.0 1.8 6.0 422 0.000 0.120 0.100 0.010 0.010 Glycol Reboiler 502803 6251623 499 5.0 0.22 6.0 422 0.000 0.000 0.000 0.000 0.000 Vacuum Tower Heater 1 503468 6251604 501 40.6 2.84 6.0 628 0.060 0.190 0.170 0.010 0.020 Vacuum Tower Heater 2 503477 6251596 501 40.6 2.84 6.0 628 0.060 0.190 0.170 0.010 0.020 Vacuum Tower Heater 3 503871 6251113 497 40.6 2.84 6.0 628 0.060 0.190 0.170 0.010 0.020 Vacuum Tower Heater 4 503862 6251105 497 40.6 2.84 6.0 628 0.060 0.190 0.170 0.010 0.020 Primary Thermal Cracker Heater 1 503497 6251579 497 37.7 2.36 8.9 422 0.050 0.170 0.150 0.010 0.010 Primary Thermal Cracker Heater 2 503506 6251570 497 37.7 2.36 8.9 422 0.050 0.170 0.150 0.010 0.010 Primary Thermal Cracker Heater 3 503846 6251086 497 37.7 2.36 8.9 422 0.050 0.170 0.150 0.010 0.010 Primary Thermal Cracker Heater 4 503836 6251077 497 37.7 2.36 8.9 422 0.050 0.170 0.150 0.010 0.010 Thermal Oil Heater 1 503567 6251482 502 44.2 1.47 7.4 611 0.020 0.050 0.060 0.000 0.010 Thermal Oil Heater 2 503719 6251037 497 44.2 1.47 7.4 611 0.020 0.050 0.060 0.000 0.010 Hydrocracker Heater 1 503478 6251249 497 30.0 1.82 6.0 582 0.020 0.060 0.070 0.000 0.010 Hydrocracker Heater 2 503946 6251042 497 30.0 1.82 6.0 582 0.020 0.060 0.070 0.000 0.010 Utility Boiler 1 503307 6251379 505 30.0 1.51 29.5 416 0.120 0.450 0.360 0.020 0.030 Utility Boiler 2 503295 6251391 505 30.0 1.51 29.5 416 0.120 0.450 0.360 0.020 0.030 Utility Boiler 3 504012 6250876 494 30.0 1.51 29.5 416 0.120 0.450 0.360 0.020 0.030 Utility Boiler 4 504024 6250887 494 30.0 1.51 29.5 416 0.120 0.450 0.360 0.020 0.030 Steam Superheater 1 503336 6251343 505 51.4 1.89 6.5 578 0.030 0.060 0.070 0.000 0.010 Steam Superheater 2 503984 6250844 494 51.4 1.89 6.5 578 0.030 0.060 0.070 0.000 0.010 Steam Superheater 3 503578 6251492 502 34.7 1.02 6.2 523 0.010 0.020 0.020 0.000 0.000 Steam Superheater 4 503729 6251027 497 34.7 1.02 6.2 523 0.010 0.020 0.020 0.000 0.000 Sulphur Recovery Unit Incinerator 1 503410 6251145 499 115 1.52 30.0 811 7.760 0.040 0.030 0.000 0.000 Sulphur Recovery Unit Incinerator 2 503732 6250845 494 115 1.52 30.0 811 7.760 0.040 0.030 0.000 0.000 HP Flare 503801 6251754 500 28.7 3.85 0.02 1273 0.000 0.000 0.000 0.000 0.000 LP Flare 504016 6251410 495 38 3.85 0.02 1273 0.000 0.000 0.000 0.000 0.000

Long Lake Project

Sour Gas Flare 504016 6251331 495 115.5 3.85 0.02 1273 0.000 0.000 0.000 0.000 0.000 OPTI Canada/Nexen Air Emission Totals for the Baseline and Project Scenarios 18.41 10.9 8.94 0.47 0.78


December 2009

Page B2-36

Table B2-23: Summary of OPTI/Nexen Existing, Approved and Proposed Air Emissions Included in the Planned Development Scenario Point Sources


UTM N (m)

Elevation (m)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s)

Exit Temp

(K) SO2 (t/d)

NOx (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Cogen Unit 1 503159 6251532 504 30.0 5.18 18.2 433 0.590 2.420 1.830 0.080 0.130 Cogen Unit 2 503193 6251498 504 30.0 5.18 18.2 433 0.590 2.420 1.830 0.080 0.130 Steam Generator 1 503237 6251626 504 30.0 1.68 18.8 464 0.090 0.320 0.280 0.020 0.030 Steam Generator 2 503248 6251616 504 30.0 1.68 18.8 464 0.090 0.320 0.280 0.020 0.030 Steam Generator 3 503258 6251605 504 30.0 1.68 18.8 464 0.090 0.320 0.280 0.020 0.030 Steam Generator 4 503270 6251593 504 30.0 1.68 18.8 464 0.090 0.320 0.280 0.020 0.030 Steam Generator 5 502738 6251665 501 30.0 1.68 18.8 464 0.090 0.320 0.280 0.020 0.030 Steam Generator 6 502750 6251654 501 30.0 1.68 18.8 464 0.090 0.320 0.280 0.020 0.030 Steam Generator 7 502761 6251643 501 30.0 1.68 18.8 464 0.090 0.320 0.280 0.020 0.030 Glycol Heater 503164 6251722 495 30.0 1.8 6.0 422 0.000 0.120 0.100 0.010 0.010 Glycol Reboiler 502803 6251623 499 5.0 0.22 6.0 422 0.000 0.000 0.000 0.000 0.000 Vacuum Tower Heater 1 503468 6251604 501 40.6 2.84 6.0 628 0.060 0.190 0.170 0.010 0.020 Vacuum Tower Heater 2 503477 6251596 501 40.6 2.84 6.0 628 0.060 0.190 0.170 0.010 0.020 Vacuum Tower Heater 3 503871 6251113 497 40.6 2.84 6.0 628 0.060 0.190 0.170 0.010 0.020 Vacuum Tower Heater 4 503862 6251105 497 40.6 2.84 6.0 628 0.060 0.190 0.170 0.010 0.020 Primary Thermal Cracker Heater 1 503497 6251579 497 37.7 2.36 8.9 422 0.050 0.170 0.150 0.010 0.010 Primary Thermal Cracker Heater 2 503506 6251570 497 37.7 2.36 8.9 422 0.050 0.170 0.150 0.010 0.010 Primary Thermal Cracker Heater 3 503846 6251086 497 37.7 2.36 8.9 422 0.050 0.170 0.150 0.010 0.010 Primary Thermal Cracker Heater 4 503836 6251077 497 37.7 2.36 8.9 422 0.050 0.170 0.150 0.010 0.010 Thermal Oil Heater 1 503567 6251482 502 44.2 1.47 7.4 611 0.020 0.050 0.060 0.000 0.010 Thermal Oil Heater 2 503719 6251037 497 44.2 1.47 7.4 611 0.020 0.050 0.060 0.000 0.010 Hydrocracker Heater 1 503478 6251249 497 30.0 1.82 6.0 582 0.020 0.060 0.070 0.000 0.010 Hydrocracker Heater 2 503946 6251042 497 30.0 1.82 6.0 582 0.020 0.060 0.070 0.000 0.010 Utility Boiler 1 503307 6251379 505 30.0 1.51 29.5 416 0.120 0.450 0.360 0.020 0.030 Utility Boiler 2 503295 6251391 505 30.0 1.51 29.5 416 0.120 0.450 0.360 0.020 0.030 Utility Boiler 3 504012 6250876 494 30.0 1.51 29.5 416 0.120 0.450 0.360 0.020 0.030 Utility Boiler 4 504024 6250887 494 30.0 1.51 29.5 416 0.120 0.450 0.360 0.020 0.030 Steam Superheater 1 503336 6251343 505 51.4 1.89 6.5 578 0.030 0.060 0.070 0.000 0.010 Steam Superheater 2 503984 6250844 494 51.4 1.89 6.5 578 0.030 0.060 0.070 0.000 0.010 Steam Superheater 3 503578 6251492 502 34.7 1.02 6.2 523 0.010 0.020 0.020 0.000 0.000 Steam Superheater 4 503729 6251027 497 34.7 1.02 6.2 523 0.010 0.020 0.020 0.000 0.000 Sulphur Recovery Unit Incinerator 1 503410 6251145 499 115 1.52 30.0 811 7.760 0.040 0.030 0.000 0.000 Sulphur Recovery Unit Incinerator 2 503732 6250845 494 115 1.52 30.0 811 7.760 0.040 0.030 0.000 0.000 HP Flare 503801 6251754 500 28.7 3.85 0.02 1273 0.000 0.000 0.000 0.000 0.000 LP Flare 504016 6251410 495 38 3.85 0.02 1273 0.000 0.000 0.000 0.000 0.000

Long Lake Project

Sour Gas Flare 504016 6251331 495 115.5 3.85 0.02 1273 0.000 0.000 0.000 0.000 0.000


December 2009

Page B2-37

Point Sources


UTM N (m)

Elevation (m)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s)

Exit Temp

(K)

SO2 (t/d)

NOx (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Steam Generator 1 500521 6239541 522 30.0 1.68 18.8 464 0.094 0.318 0.282 0.017 0.026 Steam Generator 2 500539 6239530 522 30.0 1.68 18.8 464 0.094 0.318 0.282 0.017 0.026 Steam Generator 3 500557 6239520 522 30.0 1.68 18.8 464 0.094 0.318 0.282 0.017 0.026 Steam Generator 4 500575 6239509 522 30.0 1.68 18.8 464 0.094 0.318 0.282 0.017 0.026 Steam Generator 5 500593 6239499 522 30.0 1.68 18.8 464 0.094 0.318 0.282 0.017 0.026 Steam Generator 6 500554 6239619 522 30.0 1.68 18.8 464 0.094 0.318 0.282 0.017 0.026 Steam Generator 7 500572 6239608 522 30.0 1.68 18.8 464 0.094 0.318 0.282 0.017 0.026 Steam Generator 8 500590 6239598 522 30.0 1.68 18.8 464 0.094 0.318 0.282 0.017 0.026 Steam Generator 9 500606 6239588 522 30.0 1.68 18.8 464 0.094 0.318 0.282 0.017 0.026 Steam Generator 10 500624 6239578 522 30.0 1.68 18.8 464 0.094 0.318 0.282 0.017 0.026 Steam Generator 11 500642 6239568 522 30.0 1.68 18.8 464 0.094 0.318 0.282 0.017 0.026 Cogen Unit 500465 6239611 522 30.0 5.18 18.2 433 0.590 2.436 1.834 0.081 0.127 Glycol Trim Heater 500689 6239602 522 30.0 1.8 6.0 422 0.001 0.117 0.104 0.006 0.009 Line Heater 1 500941 6240033 517 7.4 0.51 1.4 477 0.000 0.002 0.002 0.000 0.000 Line Heater 2 504806 6246080 452 7.4 0.51 1.4 477 0.000 0.002 0.002 0.000 0.000

Long Lake South Phase 1

Continuous Flare 501160 6239853 513 37.5 3.85 0.02 1273 0.000 0.000 0.001 0.001 0.000 Steam Generator 1 501084 6240393 519 30.0 1.68 18.8 464 0.094 0.318 0.282 0.017 0.026 Steam Generator 2 501102 6240383 519 30.0 1.68 18.8 464 0.094 0.318 0.282 0.017 0.026 Steam Generator 3 501120 6240372 519 30.0 1.68 18.8 464 0.094 0.318 0.282 0.017 0.026 Steam Generator 4 501117 6240471 519 30.0 1.68 18.8 464 0.094 0.318 0.282 0.017 0.026 Steam Generator 5 501134 6240462 519 30.0 1.68 18.8 464 0.094 0.318 0.282 0.017 0.026 Steam Generator 6 501152 6240451 519 30.0 1.68 18.8 464 0.094 0.318 0.282 0.017 0.026 Steam Generator 7 501170 6240441 519 30.0 1.68 18.8 464 0.094 0.318 0.282 0.017 0.026 Cogen Unit 1 500993 6240485 519 30.0 5.18 18.2 433 0.59 2.436 1.834 0.081 0.127 Cogen Unit 2 501033 6240460 519 30.0 5.18 18.2 433 0.59 2.436 1.834 0.081 0.127 Glycol Trim Heater 501217 6240475 519 30.0 1.8 6.0 422 0.001 0.117 0.104 0.006 0.009 Line Heater 501474 6240603 505 7.4 0.51 1.4 477 0 0.002 0.002 0.000 0.000

Long Lake South Phase 2

Continuous Flare 501688 6240726 508 47.2 3.73 0.02 1273 0.000 0.000 0.001 0.001 0.000 OPTI Canada/Nexen Air Emission Totals for the Planned Development Scenario 21.87 24.17 19.73 1.03 1.65


December 2009

Page B2-38

Table B2-24: Summary of Petro-Canada Existing and Approved Air Emissions Used for the Baseline and Project Scenarios Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s) Exit

Temp (K) SO2 (t/d) NOx (t/d) CO (t/d) VOC (t/d) PM2.5

(t/d)

Steam Generator 1 445136 6322011 429 27 1.34 27.5 553 0.10 0.23 0.11 0.01 0.01 Steam Generator 2 445136 6322021 429 27 1.34 27.5 553 0.10 0.23 0.11 0.01 0.01 Steam Generator 3 445136 6322031 429 27 1.34 27.5 553 0.10 0.23 0.11 0.01 0.01 Steam Generator 4 445136 6322041 429 27 1.34 27.5 553 0.10 0.23 0.11 0.01 0.01 Steam Generator 5 445136 6322051 429 27 1.34 27.5 553 0.10 0.23 0.11 0.01 0.01 Steam Generator 6 445136 6322061 429 27 1.34 27.5 553 0.10 0.23 0.11 0.01 0.01 Main Glycol Heater 444925 6322092 429 8.5 0.81 1.0 589 0.00 0.04 0.03 0.00 0.00 Glycol Trim Heater 444942 6322074 429 9.2 0.3 2.1 589 0.00 0.00 0.00 0.00 0.00 TransCanada Cogeneration 445067 6322175 429 26.2 6.31 20.0 452 0.00 3.60 3.72 0.09 0.16 Pilot Flare 1 445144 6321899 429 24.4 0.61 0.0 1273 0.00 0.00 0.00 0.00 0.00

MacKay River

Pilot Flare 2 444940 6321798 429 24.4 0.61 0.0 1273 0.00 0.00 0.00 0.00 0.00 Cogenerator 1 482144 6242326 723 30.5 6.1 23.6 478 0.35 2.98 2.14 0.08 0.18 Cogenerator 2 482144 6242261 723 30.5 6.1 23.6 478 0.35 2.98 2.14 0.08 0.18 Glycol Heater 1 481869 6242361 730 8.1 0.7 20.6 478 0.03 0.03 0.05 0.00 0.00 Glycol Heater 2 481869 6242354 730 8.1 0.7 20.6 478 0.03 0.03 0.05 0.00 0.00 Glycol Trim Heater 481880 6242339 730 7.8 0.3 10.5 478 0.00 0.00 0.00 0.00 0.00 Steam Generator 1 482251 6242013 722 27 1.76 20.6 478 0.18 0.29 0.31 0.02 0.03 Steam Generator 2 482251 6242025 722 27 1.76 20.6 478 0.18 0.29 0.31 0.02 0.03 Steam Generator 3 482162 6242013 722 27 1.76 20.6 478 0.18 0.29 0.31 0.02 0.03

Meadow Creek

Steam Generator 4 482162 6242025 722 27 1.76 20.6 478 0.18 0.29 0.31 0.02 0.03 Gas Turbine 462000 6360000 291 38.00 4.00 31.40 486 0.00 2.36 0.13 0.00 0.07 Gas Turbine 462500 6360100 291 38.00 4.00 31.40 486 0.00 2.36 0.13 0.00 0.07 Aux. Boiler 462200 6360100 291 38.00 2.00 28.90 486 0.00 0.19 0.04 0.00 0

Fort Hills

Aux. Boiler 462100 6360200 291 38.00 2.00 28.90 486 0.00 0.19 0.04 0.00 0 Area Sources


NW UTM N

NE UTM E

NE UTM N

SE UTM E

SE UTM N

SWUTM E

SW UTM N

Area (m2)

Eleva-tion

(masl) SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

North Mine 461050 6360450 463050 6360450 463050 6358450 461050 6358450 4000000 2971 0.84 10.70 2.40 0.52 0.27 South Mine 461550 6357700 464800 6357700 464800 6355200 461550 6355200 8125000 2921 0.84 10.70 2.40 0.52 0.27 Fort Hills

Tailings Pond 466550 6362000 467550 6362000 467550 6361000 466550 6361000 1000000 347 0.00 0.00 0.00 14.20 0.00 Petro-Canada Mackay River/Meadow Creek/Fort Hills Air Emission Totals for Baseline and Project Scenarios 3.76 28.7 15.17 15.63 1.38


December 2009

Page B2-39

Table B2-25: Summary of Petro-Canada Existing, Approved and Proposed Air Emissions Used for the Planned Development Scenario Point Sources

Facility Emission Source UTM E UTM N Elevation (masl)

Stack Height (m)

Stack Diameter (m)

Exit Velocity (m/s)

Exit Temp (K)

SO2 (t/d)

NOx (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Steam Generator 1 445136 6322011 429 27 1.34 27.5 553 0.10 0.23 0.11 0.01 0.01 Steam Generator 2 445136 6322021 429 27 1.34 27.5 553 0.10 0.23 0.11 0.01 0.01 Steam Generator 3 445136 6322031 429 27 1.34 27.5 553 0.10 0.23 0.11 0.01 0.01 Steam Generator 4 445136 6322041 429 27 1.34 27.5 553 0.10 0.23 0.11 0.01 0.01 Steam Generator 5 445136 6322051 429 27 1.34 27.5 553 0.10 0.23 0.11 0.01 0.01 Steam Generator 6 445136 6322061 429 27 1.34 27.5 553 0.10 0.23 0.11 0.01 0.01 Main Glycol Heater 444925 6322092 429 8.5 0.81 1.0 589 0.00 0.04 0.03 0.00 0.00 Glycol Trim Heater 444942 6322074 429 9.2 0.3 2.1 589 0.00 0.00 0.00 0.00 0.00 TransCanada Cogeneration 445067 6322175 429 26.2 6.31 20.0 452 0.00 3.60 3.72 0.09 0.16 Pilot Flare 1 445144 6321899 429 24.4 0.61 0.0 1273 0.00 0.00 0.00 0.00 0.00

MacKay River

Pilot Flare 2 444940 6321798 429 24.4 0.61 0.0 1273 0.00 0.00 0.00 0.00 0.00 Steam Generator 1 445167 6322830 433 27 1.68 18.7 444 0.12 0.23 0.13 0.01 0.03 Steam Generator 2 445167 6322758 433 27 1.68 18.7 444 0.12 0.23 0.13 0.01 0.03 Glycol Trim Heater 444900 6322816 433 5.8 0.91 8.2 589 0.00 0.02 0.04 0.00 0.00 TransCanada Cogen 1 445083 6322944 433 27 5.49 32.5 460 0.19 1.98 0.62 0.05 0.09

MacKay River Expansion

TransCanada Cogen 2 445083 6322890 433 27 5.49 32.5 460 0.19 1.98 0.62 0.05 0.09 Cogenerator 1 482144 6242326 723 30.5 6.1 23.6 478 0.35 2.98 2.14 0.08 0.18 Cogenerator 2 482144 6242261 723 30.5 6.1 23.6 478 0.35 2.98 2.14 0.08 0.18 Glycol Heater 1 481869 6242361 730 8.1 0.7 20.6 478 0.03 0.03 0.05 0.00 0.00 Glycol Heater 2 481869 6242354 730 8.1 0.7 20.6 478 0.03 0.03 0.05 0.00 0.00 Glycol Trim Heater 481880 6242339 730 7.8 0.3 10.5 478 0.00 0.00 0.00 0.00 0.00 Steam Generator 1 482251 6242013 722 27 1.76 20.6 478 0.18 0.29 0.31 0.02 0.03 Steam Generator 2 482251 6242025 722 27 1.76 20.6 478 0.18 0.29 0.31 0.02 0.03 Steam Generator 3 482162 6242013 722 27 1.76 20.6 478 0.18 0.29 0.31 0.02 0.03

Meadow Creek

Steam Generator 4 482162 6242025 722 27 1.76 20.6 478 0.18 0.29 0.31 0.02 0.03 Cogenerator 1 494816 6305173 466 30.5 6.1 24.8 478 0.62 2.99 2.14 0.08 0.18 Cogenerator 2 495049 6305173 466 30.5 6.1 24.8 478 0.62 2.99 2.14 0.08 0.18 Glycol Heater 1 494675 6305264 466 8.1 0.9 21.6 478 0.03 0.07 0.07 0.00 0.01 Glycol Heater 2 494675 6305271 466 8.1 0.9 21.6 478 0.03 0.07 0.07 0.00 0.01 Glycol Trim Heater 494695 6305250 466 7.8 0.3 11.0 478 0.00 0.00 0.00 0.00 0.00 HP Flare Stack 495052 6304877 466 39.6 0.6 0.4 323 0.00 0.01 0.05 0.00 0.00 LP flare stack 494747 6304774 466 24.4 0.4 0.4 323 0.00 0.01 0.02 0.00 0.00 Steam Generator 1 495045 6304972 466 27 1.76 21.6 478 0.11 0.29 0.30 0.02 0.03 Steam Generator 2 495045 6304961 466 27 1.76 21.6 478 0.11 0.29 0.30 0.02 0.03

Lewis

Steam Generator 3 495045 6304950 466 27 1.76 21.6 478 0.11 0.29 0.30 0.02 0.03


December 2009

Page B2-40

Point Sources


Stack Height (m)

Stack Diameter (m)

Exit Velocity (m/s)

Exit Temp (K)

SO2 (t/d)

NOx (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Gas Turbine 462000 6360000 291 38.00 4.00 31.40 486 0.00 2.36 0.13 0.00 0.07 Gas Turbine 462500 6360100 291 38.00 4.00 31.40 486 0.00 2.36 0.13 0.00 0.07 Aux. Boiler 462200 6360100 291 38.00 2.00 28.90 486 0.00 0.19 0.04 0.00 0

Fort Hills

Aux. Boiler 462100 6360200 291 38.00 2.00 28.90 486 0.00 0.19 0.04 0.00 0 Area Sources


NW UTM N

NE UTM E

NE UTM N

SE UTM E

SE UTM N

SW UTM E

SW UTM N

Area(m2)

Elevation(masl)

SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

North Mine 461050 6360450 463050 6360450 463050 6358450 461050 6358450 4000000 2971 0.84 10.70 2.40 0.52 0.27 South Mine 461550 6357700 464800 6357700 464800 6355200 461550 6355200 8125000 2921 0.84 10.70 2.40 0.52 0.27 Fort Hills

Tailings Pond 466550 6362000 467550 6362000 467550 6361000 466550 6361000 1000000 347 0.00 0.00 0.00 14.20 0.00 Petro-Canada Mackay River/Meadow Creek/Lewis/Fort Hills Air Emission Totals for Planned Development Scenario 6.01 50.15 22.10 15.97 2.09


December 2009

Page B2-41

2.16 Shell Canada Limited

Emissions Included in the Baseline and Project Scenarios Shell Canada Limited (Shell), with joint venture partners Chevron Texaco and Western Oil Sands, received a conditional approval for the Jackpine Mine Phase 1 development in February 2004. Jackpine Mine Phase 1 is a stand-alone mining and extraction facility, which will recover approximately 200 000 b/d of bitumen. Table B2-26 provides a summary of the emissions that were included in the baseline and project scenarios.

Emissions Included in the Planned Development Scenario A Jackpine Mine Phase 2 development will further expand production with additional 100 000 b/d by late 2014. Table B2-27 provides a summary of the emissions that were included in the Planned Development scenario.

2.17 Statoil Canada Ltd.

Emissions Included in the Baseline and Project Scenarios Statoil Canada Limited (Statoil), operates Leismer Pilot project as part of the Kai Kos Dehseh development located south of Fort McMurray. The Leismer pilot is a 10 000 b/d facility. Table B2-28 provides a summary of the emissions that were included in the baseline and project scenarios.

Emissions Included in the Planned Development Scenario Future phase of the Kai Kos Dehseh project have been announced, including the Commercial Leismer project, Leismer Expansion, Leismer Northwest, Leismer South, Thornbury 1, Thornbury 2, Thornbury Expansion, Corner 1, Corner 2, Corner Expansion, Corner Expansion West and Hangingstone. Table B2-29 provides a summary of the emissions that were included in the Planned Development scenario.


December 2009

Page B2-42

Table B2-26: Summary of Shell Approved Air Emissions Used for the Baseline and Project Scenarios Point Sources


UTM N (m)

Elevation (masl)

Stack Height (m)

Stack Diameter (m)

Exit Velocity (m/s)

Exit Temp (K)

SO2 (t/d)

NOX (t/d))

CO (t/d)

VOC(t/d)

PM2.5 (t/d)

Co-generator 1 477158 6344508 324 30.0 5.5 15.0 393 0.02 3.38 1.96 0.08 0.16

Boiler 1 477174 6344545 324 25.0 4.5 15.0 453 0.01 1.73 1.47 0.10 0.13 Jackpine Phase 1

Boiler 2 477174 6344530 324 25.0 4.5 15.0 453 0.01 1.73 1.47 0.10 0.13

Area Sources


NW UTM N

NE UTM E

NE UTM N

SE UTM E

SE UTM N

SW UTM E

SW UTM N

Area (m2)

Elevation(masl)

SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC(t/d)

PM2.5 (t/d)

Mine Fleet/Fugitives 1 477783 6348249 480595 6348249 480595 6343561 477783 6343561 13182656 3271 0.29 11.20 6.97 7.76 0.40

Space Heating 476515 6344675 476737 6344675 476737 6344435 476515 6344435 53280 318 0.003 0.23 0.36 0.02 0.03 Jackpine Phase 1

Tailings Pond 477783 6343187 480595 6343187 480595 6340749 477783 6340749 6855656 323 0.00 0.00 0.00 9.92 0.00

Shell Air Emission Totals used for the Baseline and Project Scenarios 0.33 18.28 12.23 17.98 0.85



December 2009

Page B2-43

Table B2-27: Summary of Shell Approved and Proposed Air Emissions Used for the Planned Development Scenario Point Sources


Stack Height (m)

Stack Diameter (m)

Exit Velocity (m/s)

Exit Temp (K)

SO2 (t/d)

NOX (t/d))

CO (t/d)

VOC(t/d)

PM2.5 (t/d)

Co-generator 1 477158 6344508 324 30.0 5.5 15.0 393 0.02 3.38 1.96 0.08 0.16

Boiler 1 477174 6344545 324 25.0 4.5 15.0 453 0.01 1.73 1.47 0.10 0.13 Jackpine Phase 1

Boiler 2 477174 6344530 324 25.0 4.5 15.0 453 0.01 1.73 1.47 0.10 0.13

Co-generator 2 477058 6344508 324 30.0 3.9 15.0 393 0.01 1.69 0.98 0.04 0.08 Jackpine Phase 2 Boiler 3 485521 6356420 297 25.0 4.5 15.0 453 0.01 1.73 1.47 0.10 0.13

Area Sources


NW UTM N

NE UTM E

NE UTM N

SE UTM E

SE UTM N

SW UTM E

SW UTM N

Area (m2)

Elevation(masl)

SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC(t/d)

PM2.5 (t/d)

Mine Fleet/Fugitives 1 477783 6348249 480595 6348249 480595 6343561 477783 6343561 13182656 3271 0.29 11.20 6.97 7.76 0.40

Space Heating 476515 6344675 476737 6344675 476737 6344435 476515 6344435 53280 318 0.003 0.23 0.36 0.02 0.03 Jackpine Phase 1

Tailings Pond 477783 6343187 480595 6343187 480595 6340749 477783 6340749 6855656 323 0.00 0.00 0.00 9.92 0.00

Mine Fleet/Fugitives 2 484291 6359809 486867 6359809 486867 6357209 484291 6357209 6697600 2951 0.14 5.18 3.48 3.82 0.20 Jackpine Phase 2 Tailings Pond 2 482258 6358419 484109 6358419 484109 6356568 482258 6356568 3426201 295 0.00 0.00 0.00 4.96 0.00

Shell Air Emission Totals for Planned Development Scenario 0.50 26.87 18.16 26.90 1.26 1 Elevation sunken 50 m in modelling to compensate for the mine pit.


December 2009

Page B2-44

Table B2-28: Summary of Statoil Existing and Approved Air Emissions Used for the Baseline and Project Scenarios Point Sources


Stack Height (m)

Stack Diameter (m)

Exit Velocity (m/s)

Exit Temp (K)

SO2 (t/d)

NOx (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Steam Generator 1 471728 6185804 644 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03

Steam Generator 2 471728 6185792 644 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03

Steam Generator 3 471728 6185780 644 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03

Glycol Heater 471809 6185646 644 16.00 0.76 5.10 616 0.00 0.01 0.01 0.00 0.00

Slop Heater 472007 6185728 644 10.00 0.32 11.00 532 0.00 0.00 0.00 0.00 0.00

HP Flare 471946 6185545 644 32.40 3.78 0.01 1273 0.00 0.00 0.00 0.00 0.00

Leismer Pilot

LP Flare 471946 6185546 644 32.30 1.89 0.03 1273 0.00 0.00 0.00 0.00 0.00

Statoil Air Emission Totals for Planned Development Scenario 0.18 1.01 0.61 0.06 0.08


December 2009

Page B2-45

Table B2-29: Summary of Statoil Existing, Approved and Proposed Air Emissions Used for the Planned Development Scenario

Point Sources


Stack Height (m)

Stack Diameter (m)

Exit Velocity (m/s)

Exit Temp (K)

SO2 (t/d)

NOx (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Steam Generator 1 471728 6185804 644 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 2 471728 6185792 644 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 3 471728 6185780 644 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Glycol Heater 471809 6185646 644 16.00 0.76 5.10 616 0.00 0.01 0.01 0.00 0.00 Slop Heater 472007 6185728 644 10.00 0.32 11.00 532 0.00 0.00 0.00 0.00 0.00 HP Flare 471946 6185545 644 32.40 3.78 0.01 1273 0.00 0.00 0.00 0.00 0.00

Leismer Pilot

LP Flare 471946 6185546 644 32.30 1.89 0.03 1273 0.00 0.00 0.00 0.00 0.00 Steam Generator 4 471728 6185768 644 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 5 471826 6185804 644 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 6 471826 6185792 644 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 7 471827 6185780 644 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 8 471827 6185768 644 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03

Leismer Commercial

Sulphur Heater 471878 6185758 644 16.00 0.76 5.10 616 0.00 0.01 0.01 0.00 0.00 Glycol Heater 472609 6185646 660 16.00 0.73 5.10 616 0.00 0.01 0.01 0.00 0.00 Slop Treater 472807 6185728 660 10.00 0.32 11.00 532 0.00 0.00 0.00 0.00 0.00 HP Flare 472746 6185545 660 32.40 3.78 0.01 1273 0.00 0.00 0.00 0.00 0.00

Leismer Expansion

LP Flare 472746 6185546 660 32.30 1.89 0.03 1273 0.00 0.00 0.00 0.00 0.00 Steam Generator 1 467349 6189167 672 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 2 467349 6189155 672 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 3 467350 6189143 672 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 4 467350 6189131 672 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Glycol Heater 467333 6189009 672 16.00 0.73 5.10 616 0.00 0.01 0.01 0.00 0.00 Slop Treater 467530 6189091 672 10.00 0.32 11.00 532 0.00 0.00 0.00 0.00 0.00 HP Flare 467469 6188908 672 32.40 3.78 0.01 1273 0.00 0.00 0.00 0.00 0.00

Leismer Northwest


Leismer South

LP Flare 465944 6171653 674 32.30 1.89 0.03 1273 0.00 0.00 0.00 0.00 0.00


December 2009

Page B2-46

Point Sources


Stack Height (m)

Stack Diameter (m)

Exit Velocity (m/s)

Exit Temp (K)

SO2 (t/d)

NOx (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Steam Generator 1 455774 6194258 683 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 2 455786 6194257 683 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 3 455799 6194257 683 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 4 455810 6194258 683 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 5 455774 6194356 683 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 6 455786 6194356 683 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 7 455798 6194356 683 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 8 455810 6194356 683 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Glycol Heater 455932 6194339 683 16.00 0.73 5.10 616 0.00 0.01 0.01 0.00 0.00 Slop Treater 455850 6194536 683 10.00 0.32 11.00 532 0.00 0.00 0.00 0.00 0.00 Sulphur Heater 455821 6194408 683 16.00 0.76 5.10 616 0.00 0.01 0.01 0.00 0.00 HP Flare 456033 6194475 683 32.30 1.89 0.03 1273 0.00 0.00 0.00 0.00 0.00

Thornbury 1

LP Flare 456032 6194475 683 32.40 3.78 0.01 1273 0.00 0.00 0.00 0.00 0.00 Glycol Heater 455932 6195139 678 16.00 0.73 5.10 616 0.00 0.01 0.01 0.00 0.00 Slop Treater 455850 6195336 678 10.00 0.32 11.00 532 0.00 0.00 0.00 0.00 0.00 HP Flare 456033 6195275 678 32.30 1.89 0.03 1273 0.00 0.00 0.00 0.00 0.00

Thornbury 2


Thornbury Expansion

LP Flare 449007 6199223 704 32.30 1.89 0.03 1273 0.00 0.00 0.00 0.00 0.00 Steam Generator 1 484246 6203282 726 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 2 484245 6203270 726 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 3 484245 6203258 726 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 4 484246 6203246 726 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 5 484344 6203282 726 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 6 484344 6203270 726 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 7 484344 6203259 726 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 8 484344 6203246 726 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Glycol Heater 484327 6203124 726 16.00 0.73 5.10 616 0.00 0.01 0.01 0.00 0.00 Slop Treater 484524 6203207 726 10.00 0.32 11.00 532 0.00 0.00 0.00 0.00 0.00 Sulphur Heater 484396 6203236 726 16.00 0.76 5.10 616 0.00 0.01 0.01 0.00 0.00 HP Flare 484464 6203024 726 32.30 1.89 0.03 1273 0.00 0.00 0.00 0.00 0.00

Corner 1

LP Flare 484464 6203025 726 32.40 3.78 0.01 1273 0.00 0.00 0.00 0.00 0.00


December 2009

Page B2-47

Point Sources


Stack Height (m)

Stack Diameter (m)

Exit Velocity (m/s)

Exit Temp (K)

SO2 (t/d)

NOx (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Steam Generator 1 485144 6203282 728 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 2 485144 6203270 728 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 3 485144 6203259 728 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 4 485144 6203246 728 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Glycol Heater 485127 6203124 728 16.00 0.73 5.10 616 0.00 0.01 0.01 0.00 0.00 Slop Treater 485324 6203207 728 10.00 0.32 11.00 532 0.00 0.00 0.00 0.00 0.00 Sulphur Heater 485196 6203236 728 16.00 0.76 5.10 616 0.00 0.01 0.01 0.00 0.00 HP Flare 485364 6203024 728 32.40 3.78 0.01 1273 0.00 0.00 0.00 0.00 0.00

Corner 2

LP Flare 485264 6203025 728 32.30 1.89 0.03 1273 0.00 0.00 0.00 0.00 0.00 Glycol Heater 484077 6203674 731 10.00 0.32 11.00 532 0.00 0.00 0.00 0.00 0.00 Slop Treater 484274 6203757 731 16.00 0.76 5.10 616 0.00 0.01 0.01 0.00 0.00 HP Flare 484214 6203574 731 32.30 1.89 0.03 1273 0.00 0.00 0.00 0.00 0.00

Corner Expansion


Corner Expansion West

LP Flare 480446 6210218 705 32.30 1.89 0.03 1273 0.00 0.00 0.00 0.00 0.00 Steam Generator 1 475538 6226253 723 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 2 475538 6226241 723 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 3 457539 6226229 723 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Steam Generator 4 475539 6226217 723 27.00 1.68 16.70 444 0.06 0.33 0.20 0.02 0.03 Glycol Heater 457521 6226095 723 16.00 0.73 5.10 616 0.00 0.01 0.01 0.00 0.00 Slop Treater 475719 6226178 723 10.00 0.32 11.00 532 0.00 0.00 0.00 0.00 0.00 Sulphur Heater 475590 6226207 723 16.00 0.76 5.10 616 0.00 0.01 0.01 0.00 0.00 HP Flare 475658 6225995 723 32.40 3.78 0.01 1273 0.00 0.00 0.00 0.00 0.00

Hangingstone

LP Flare 475658 6225996 723 32.30 1.89 0.03 1273 0.00 0.00 0.00 0.00 0.00 Statoil Air Emission Totals for Planned Development Scenario 2.88 16.19 9.71 0.93 1.22


December 2009

Page B2-48

2.18 Suncor Energy Inc.

Emissions Included in the Planned Development Scenario Suncor has numerous emission sources at its base upgrader plant, reported on a source-grouping basis. In addition, Suncor operates the Firebag In-situ Project.

• Project Millennium Emissions – The Millennium oil sands expansion is operational and the targeted plant production is 225 000 b/d. The primary emission point sources at the upgrader base facility are the Flue Gas Desulphurization (FGD) stack, the main stack, the powerhouse stack and numerous secondary stacks.

• Voyageur Emissions – Suncor received the regulatory approval for Voyageur in October 2006. Voyageur is an expansion of Suncor’s oil sands mining and in-situ developments.

• Firebag Emissions – The Firebag In-situ Project is located approximately 40 km northeast of Suncor’s existing upgrader base plant. The first phase of Firebag and expanded upgrader are expected to bring Suncor's production capacity to 260 000 b/d in 2005.

Table B2-30 provides a summary of Suncor emissions included in the baseline and project scenarios.

Emissions Included in the Planned Development Scenario Phase 4 through 6 of the Voyager project have been announced but not yet approved so are included in the Planned Development scenario. Table B2-31 provides a summary of Suncor emissions included in the Planned Development scenario.


December 2009

Page B2-49

Table B2-30: Summary of Suncor Existing and Approved Air Emissions Used for the Baseline and Project Scenarios Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s) Exit Temp

(K) SO2

1

(t/d) NOX (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

FGD Stack 471043 6317825 251 137.2 7.01 13.1 322 18.749 31.971 0.781 0.172 4.053 Powerhouse Stack 471026 6317764 254 106.7 5.79 7 466 16.153 4.780 2.053 0.143 0.485 Gas Turbine Generator 470360 6318450 267 30.5 6.1 15.9 383 0.000 2.256 1.728 0.067 0.145 Gas Turbine Generator 470459 6318282 266 30.5 6.1 15.9 383 0.000 2.256 1.728 0.067 0.145 Sulphur Plant Incinerator 471003 6318016 248 106.7 1.98 22 673 12.417 0.113 0.027 0.002 0.002 Plant 5 Diluent Tower Feed Heater 470986 6317928 250 48.8 1.8 5.5 733 0.042 0.125 0.105 0.007 0.010 Plant 5 Diluent Heater 470989 6317924 250 48.8 1.8 5.5 733 0.042 0.125 0.105 0.007 0.010 Plant 5 Coker Feed Heater 471012 6317923 250 41.2 2.18 7.6 728 0.067 0.376 0.166 0.011 0.015 Plant 5 Coker Feed Heater 471025 6317903 250 41.2 2.18 7.6 728 0.067 0.376 0.166 0.011 0.015 Plant 5 Coker Feed Heater 471039 6317882 250 41.2 2.18 7.6 728 0.067 0.376 0.166 0.011 0.015 Plant 5 Diluent Tower Feed Heater 470999 6317900 251 50.3 1.78 11 644 0.059 0.331 0.146 0.010 0.013 Plant 5 Coker Feed Heater 471050 6317865 250 41.2 2.18 7.6 728 0.067 0.376 0.166 0.011 0.015 Plant 6 Hydrogen Reforming Furnace 470850 6317902 257 61 2.06 15.2 566 0.266 1.495 0.661 0.043 0.060 Plant 6 Hydrogen Plant Waste Gas 470874 6317926 255 15.2 1.37 6.1 561 0.014 0.041 0.034 0.002 0.003 Plant 7 Naphtha Charge Heater 470971 6317907 255 41.2 1.27 6.7 728 0.013 0.039 0.033 0.002 0.003 Plant 7 Naphtha Depropanizer Reboiler 470975 6317910 251 41.2 1.37 7.6 728 0.017 0.051 0.043 0.003 0.004 Plant 7 Kerosene Charge Heater 470975 6317899 251 41.2 1.26 7.6 728 0.014 0.041 0.034 0.002 0.003 Plant 7 Kerosene Stripper Reboiler 470993 6317878 251 45.7 1.5 6.7 728 0.017 0.051 0.043 0.003 0.004 Plant 7 Gas Oil Charge Heater 470998 6317862 251 41.2 1.27 9.1 733 0.025 0.073 0.061 0.004 0.006 Plant 7 Gas Oil Charge Heater 471002 6317865 252 41.2 1.27 9.1 733 0.025 0.073 0.061 0.004 0.006 Plant 7 Gas Oil Charge Heater 471007 6317868 251 41.2 1.27 9.1 733 0.025 0.073 0.061 0.004 0.006 Plant 25 Charge Heater 470750 6318076 251 67 1.49 9.1 486 0.043 0.127 0.106 0.007 0.010

Suncor Base Plant

Plant 25 Vacuum Heater 470737 6318091 247 80.8 2.21 9.1 489 0.092 0.519 0.229 0.015 0.021 Sulphur Plant Incinerator 470933 6318211 245 106.1 3.35 8.6 673 5.959 0.332 0.108 0.007 0.010 Plant 52 Diluent Tower Fired Heater 470804 6318588 244 54.9 2.97 7.6 489 0.042 0.074 0.105 0.007 0.010 Plant 52 Diluent Tower Fired Heater 470823 6318599 244 54.9 2.97 7.6 489 0.042 0.074 0.105 0.007 0.010 Plant 52 Coker Charge Heaters 470884 6318477 244 60.7 3.35 7.6 478 0.118 0.279 0.294 0.019 0.027 Plant 52 Coker Charge Heaters 470902 6318446 258 60.7 3.35 7.6 478 0.118 0.279 0.294 0.019 0.027 Plant 54 Reformer 470529 6318514 252 38.1 2.85 15.2 566 0.177 0.484 0.441 0.029 0.040 Plant 55 Fired Heater, Reactor #2 Charge Heater 470676 6318482 252 38.1 0.94 5.6 535 0.008 0.014 0.021 0.001 0.002 Plant 55 Fired Heater Combined Feed Heater 470637 6318600 253 38.1 1.22 7.6 533 0.018 0.027 0.044 0.003 0.004 Plant 55 Fired Heater Stripper Reboiler 470630 6318562 252 37.5 1.78 6.1 625 0.018 0.032 0.045 0.003 0.004 Plant 55 Fired Heater Combined Feed Heater 470710 6318421 247 38.1 1.16 6.1 535 0.016 0.025 0.040 0.003 0.004

Suncor Millennium

Plant 57 Diluent Tower Heater 470733 6318662 245 49.1 1.73 10.1 483 0.116 0.126 0.111 0.007 0.010


December 2009

Page B2-50

Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s)

Exit Temp (K)

SO21

(t/d) NOX (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Plant 57 Diluent Tower Heater 470748 6318761 245 49.1 1.73 10.1 483 0.116 0.126 0.111 0.007 0.010 Plant 57 Vacuum Tower Heater 470777 6318686 244 47.8 1.85 10.1 483 0.155 0.159 0.149 0.010 0.014 Plant 57 Vacuum Tower Heater 470789 6318691 247 47.8 1.85 10.1 483 0.155 0.159 0.149 0.010 0.014 Plant 52 Coker Charge Heaters 470912 6318381 245 60.7 3.28 7.6 487 0.317 0.340 0.305 0.020 0.028 Naphtha Hydrotreater #3 Reactor Charge Heater 470411 6318623 261 38.1 0.52 5.6 533 0.031 0.021 0.026 0.002 0.002

Suncor Millennium (cont)

Hydrogen Plant #3 470465 6318577 260 42.7 3.5 13.7 422 0.159 0.422 0.324 0.021 0.029 Sulphur Plant Incinerator 469120 6314086 321 89.9 4.17 15.2 673 7.074 0.362 0.104 0.007 0.009 Hydrogen Plant Train 1 469248 6314274 322 42.7 4.04 13.7 422 0.013 1.407 1.200 0.079 0.109 Hydrogen Plant Train 2 469332 6314233 323 42.7 3.3 13.7 422 0.008 0.939 0.801 0.052 0.072 Delayed Coker Unit 1 468914 6314251 319 39.6 4.31 7.6 444 0.390 0.525 0.465 0.030 0.042 Delayed Coker Unit 2 468934 6314241 319 39.6 4.31 7.6 444 0.390 0.525 0.465 0.030 0.042 Delayed Coker Unit 3 468956 6314230 319 39.6 4.31 7.6 444 0.390 0.525 0.465 0.030 0.042 Diesel Hydrotreater Unit 1 469012 6314457 320 39.6 1.5 7.6 478 0.048 0.043 0.057 0.004 0.005 Diesel Hydrotreater Unit 2 468976 6314380 320 45.7 2.46 7.6 444 0.127 0.174 0.152 0.010 0.014 Gas Oil Hydrotreater Unit 469141 6314343 321 39.6 1.51 7.6 478 0.048 0.042 0.057 0.004 0.005 Naphtha Hydrotreater Unit 468869 6314459 318 38.1 1.09 5.6 533 0.030 0.026 0.036 0.002 0.003 Boiler Package Heater 469205 6314572 322 38.1 3.22 7.6 478 0.219 0.295 0.261 0.017 0.024 Steam Superheater 469257 6314546 322 45.7 0.65 7.6 478 0.010 0.009 0.012 0.001 0.001 Fuel Gas Pipeline Heater 469404 6314474 324 45.7 0.69 7.6 478 0.010 0.009 0.012 0.001 0.001 Hot Bitumen Heating Furnace 468904 6314127 319 45.7 0.61 7.6 478 0.010 0.008 0.011 0.001 0.001 Vacuum Recovery Unit Combustion Unit 468786 6314288 318 45.7 1.34 7.6 478 0.048 0.042 0.057 0.004 0.005 Vacuum Tower Heater 1 468804 6314324 318 47.8 2.06 10.1 483 0.146 0.197 0.175 0.011 0.016 Vacuum Tower Heater 2 468769 6314250 318 47.8 2.06 10.1 483 0.146 0.197 0.175 0.011 0.016

Suncor Voyageur

Gasifier, High Pressure Boiler Package Heater 469230 6314560 322 38.1 0.76 7.6 478 0.017 0.014 0.020 0.001 0.002 Stage 1 - Steam Generator No. 1 508932 6343662 582 30 1.7 22.4 432 0.187 0.359 0.291 0.019 0.026 Stage 1 - Steam Generator No. 2 508956 6343662 582 30 1.7 19.4 420 0.128 0.402 0.114 0.005 0.075 Stage 1 - Steam Generator No. 3 508932 6343575 582 30 1.7 19.4 420 0.128 0.402 0.114 0.005 0.075 Stage 1 - Steam Generator No. 4 508956 6343575 582 30 1.7 19.4 420 0.128 0.402 0.114 0.005 0.075 Stage 2 - Steam Generator No. 1 509138 6343660 582 30 1.7 22.4 432 0.187 0.359 0.291 0.019 0.026 Stage 2 - Steam Generator No. 2 509162 6343660 582 30 1.7 19.4 420 0.128 0.402 0.114 0.005 0.075 Stage 2 - Steam Generator No. 3 509162 6343574 582 30 1.7 19.4 420 0.128 0.402 0.114 0.005 0.075 Stage 2 - Steam Generator No. 4 509138 6343573 582 30 1.7 19.4 420 0.128 0.402 0.114 0.005 0.075 Stage C & E - Cogeneration Unit 508875 6343657 582 27 5.49 16.8 439 0.380 1.846 1.199 0.047 0.101 Stage 3 - Cogeneration Unit No. 1 508890 6344358 583 27 5.49 16.8 439 0.262 1.846 1.199 0.047 0.101

Suncor Firebag SAGD

Stage 3 - Cogeneration Unit No. 2 508838 6344358 583 27 5.49 16.8 439 0.262 1.846 1.199 0.047 0.101 Stage 3 - Steam Generator No. 1 508799 6344506 583 33 1.66 22.2 398 0.151 0.290 0.235 0.015 0.021


December 2009

Page B2-51

Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s)

Exit Temp (K)

SO21

(t/d) NOX (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Stage 3 - Steam Generator No. 1 508799 6344506 583 33 1.66 22.2 398 0.151 0.290 0.235 0.015 0.021 Stage 3 - Steam Generator No. 2 508888 6344506 583 33 1.66 22.2 398 0.151 0.290 0.235 0.015 0.021 Stage 3 - Steam Generator No. 3 508888 6344494 583 33 1.66 22.2 398 0.151 0.290 0.235 0.015 0.021 Stage 3 - Steam Generator No. 4 508800 6344518 583 33 1.66 22.2 398 0.151 0.290 0.235 0.015 0.021 Stage 3 - Steam Generator No. 5 508800 6344494 583 33 1.66 22.2 398 0.151 0.290 0.235 0.015 0.021 Stage 3 - Diluent Stripper Unit 509056 6344341 583 33 1.09 11.1 398 0.166 0.319 0.259 0.017 0.023

Suncor Firebag SAGD (cont)

Stage 3 - SRU Vent Gas Incinerator 509052 6344840 583 5 0.24 5.14 750 0.000 0.001 0.001 0.000 0.000 ETS Pilot - Steam Generator No. 1 509627 6341492 579 3.8 0.15 79.5 813 0.002 0.096 0.022 0.008 0.003 ETS Pilot - Steam Generator No. 2 509622 6341479 579 3.8 0.15 79.5 813 0.002 0.096 0.022 0.008 0.003 ETS Pilot - Heater No. 1 509639 6341477 579 6.1 0.25 40 594 0.003 0.007 0.013 0.001 0.001

Suncor Firebag ETS

ETS Pilot - Heater No. 2 509637 6341463 579 6.1 0.1 40 589 0.001 0.003 0.002 0.000 0.000 Area Source


NW UTM N

NE UTM E

NE UTM N

SE UTM E

SE UTM N

SW UTM E

SW UTM N

Area (m2)

Elevation(masl)

SO21

(t/d) NOX (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Mine Area 1 474421 6311147 478254 6311147 478244 6306719 474431 6306719 16927841 327.92 0.030 5.330 5.719 2.260 0.280 Mine Area 2 478383 6311147 481401 6311147 481401 6307136 478373 6307116 12157244 353.42 0.022 3.828 4.107 1.623 0.201 Mine Area 3 477865 6314587 481033 6314560 481075 6311254 477865 6311254 10583788 355.42 0.019 3.332 3.576 1.413 0.175 Mine Area 4 473940 6315427 477810 6315427 477797 6311240 473954 6311254 16121151 329.72 0.029 5.076 5.447 2.152 0.266 Mine Area 5 473885 6316612 475317 6316584 475372 6315510 473885 6315510 1588191 317.62 0.003 0.500 0.537 0.212 0.026 Mine Area 6 472714 6317590 473348 6318251 474312 6317245 473706 6316667 1203634 275.82 0.002 0.379 0.407 0.161 0.020 Mine Area 7 471819 6319077 472480 6319546 473182 6318457 472590 6317920 1073979 264.62 0.002 0.338 0.363 0.143 0.018 Tailings Ponds 468233 6317061 469459 6317061 469459 6315759 468233 6315759 1595400 311.7 0.000 0.000 0.000 176.866 0.000 South Tailings Pond 478109 6305130 481783 6305130 481783 6301456 478109 6301456 13499746 357.1 0.000 0.000 0.000 4.536 0.000

Suncor Millennium

Plant Fugitives 470238 6318402 470728 6318693 471443 6317492 470953 6317203 795855 255.9 0.000 0.000 0.000 16.982 0.000 Coke Handling Fleet 468667 6313491 469044 6314095 470775 6312095 469325 6311351 2696581 317.7 0.009 0.771 0.478 0.107 0.027 Plant Fugitives 468970 6314830 469922 6314350 469599 6313701 468647 6314184 772176 322.4 0.000 0.000 0.000 0.609 0.000 Suncor Voyageur Tank Farm Fugitives 471088 6313692 471678 6313692 471678 6312961 471088 6312961 431354 321.1 0.000 0.000 0.000 0.261 0.000 Mine Area 1 474503 6320144 475436 6321077 477273 6319240 476341 6318310 3423903 336.3 0.041 7.199 7.725 3.052 0.378 Mine Area 2 477771 6318332 479603 6318332 479603 6316809 477635 6316955 2759239 341.4 0.033 5.802 6.225 2.460 0.304 North Steepbank

Extension Mine Area 3 475241 6318058 475672 6318712 477685 6317490 477361 6316846 1800591 338.1 0.022 3.786 4.062 1.605 0.199

Suncor Firebag Plant Fugitives 508630 6344914 509611 6344910 509260 6343024 508630 6343016 1523598 582.4 0.0 0.0 0.0 0.058 0.0 Suncor Air Emission Totals for the Baseline and Project Scenarios 72.375 112.116 69.056 216.367 9.226

1 Sulphur Dioxide emission rates are based on Calendar Day. 2 Elevation sunken 50 m in modelling to compensate for the mine pit.


December 2009

Page B2-52

Table B2-31: Summary of Suncor Existing and Approved Air Emissions Used for the Planned Development Scenarios Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s) Exit Temp

(K) SO2

1

(t/d) NOX (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

FGD Stack 471043 6317825 251 137.2 7.01 13.1 322 18.749 31.971 0.781 0.172 4.053 Powerhouse Stack 471026 6317764 254 106.7 5.79 7 466 16.153 4.780 2.053 0.143 0.485 Gas Turbine Generator 470360 6318450 267 30.5 6.1 15.9 383 0.000 2.256 1.728 0.067 0.145 Gas Turbine Generator 470459 6318282 266 30.5 6.1 15.9 383 0.000 2.256 1.728 0.067 0.145 Sulphur Plant Incinerator 471003 6318016 248 106.7 1.98 22 673 12.417 0.113 0.027 0.002 0.002 Plant 5 Diluent Tower Feed Heater 470986 6317928 250 48.8 1.8 5.5 733 0.042 0.125 0.105 0.007 0.010 Plant 5 Diluent Heater 470989 6317924 250 48.8 1.8 5.5 733 0.042 0.125 0.105 0.007 0.010 Plant 5 Coker Feed Heater 471012 6317923 250 41.2 2.18 7.6 728 0.067 0.376 0.166 0.011 0.015 Plant 5 Coker Feed Heater 471025 6317903 250 41.2 2.18 7.6 728 0.067 0.376 0.166 0.011 0.015 Plant 5 Coker Feed Heater 471039 6317882 250 41.2 2.18 7.6 728 0.067 0.376 0.166 0.011 0.015 Plant 5 Diluent Tower Feed Heater 470999 6317900 251 50.3 1.78 11 644 0.059 0.331 0.146 0.010 0.013 Plant 5 Coker Feed Heater 471050 6317865 250 41.2 2.18 7.6 728 0.067 0.376 0.166 0.011 0.015 Plant 6 Hydrogen Reforming Furnace 470850 6317902 257 61 2.06 15.2 566 0.266 1.495 0.661 0.043 0.060 Plant 6 Hydrogen Plant Waste Gas 470874 6317926 255 15.2 1.37 6.1 561 0.014 0.041 0.034 0.002 0.003 Plant 7 Naphtha Charge Heater 470971 6317907 255 41.2 1.27 6.7 728 0.013 0.039 0.033 0.002 0.003 Plant 7 Naphtha Depropanizer Reboiler 470975 6317910 251 41.2 1.37 7.6 728 0.017 0.051 0.043 0.003 0.004 Plant 7 Kerosene Charge Heater 470975 6317899 251 41.2 1.26 7.6 728 0.014 0.041 0.034 0.002 0.003 Plant 7 Kerosene Stripper Reboiler 470993 6317878 251 45.7 1.5 6.7 728 0.017 0.051 0.043 0.003 0.004 Plant 7 Gas Oil Charge Heater 470998 6317862 251 41.2 1.27 9.1 733 0.025 0.073 0.061 0.004 0.006 Plant 7 Gas Oil Charge Heater 471002 6317865 252 41.2 1.27 9.1 733 0.025 0.073 0.061 0.004 0.006 Plant 7 Gas Oil Charge Heater 471007 6317868 251 41.2 1.27 9.1 733 0.025 0.073 0.061 0.004 0.006 Plant 25 Charge Heater 470750 6318076 251 67 1.49 9.1 486 0.043 0.127 0.106 0.007 0.010

Suncor Base Plant

Plant 25 Vacuum Heater 470737 6318091 247 80.8 2.21 9.1 489 0.092 0.519 0.229 0.015 0.021 Sulphur Plant Incinerator 470933 6318211 245 106.1 3.35 8.6 673 5.959 0.332 0.108 0.007 0.010 Plant 52 Diluent Tower Fired Heater 470804 6318588 244 54.9 2.97 7.6 489 0.042 0.074 0.105 0.007 0.010 Plant 52 Diluent Tower Fired Heater 470823 6318599 244 54.9 2.97 7.6 489 0.042 0.074 0.105 0.007 0.010 Plant 52 Coker Charge Heaters 470884 6318477 244 60.7 3.35 7.6 478 0.118 0.279 0.294 0.019 0.027 Plant 52 Coker Charge Heaters 470902 6318446 258 60.7 3.35 7.6 478 0.118 0.279 0.294 0.019 0.027 Plant 54 Reformer 470529 6318514 252 38.1 2.85 15.2 566 0.177 0.484 0.441 0.029 0.040 Plant 55 Fired Heater, Reactor #2 Charge Heater 470676 6318482 252 38.1 0.94 5.6 535 0.008 0.014 0.021 0.001 0.002 Plant 55 Fired Heater Combined Feed Heater 470637 6318600 253 38.1 1.22 7.6 533 0.018 0.027 0.044 0.003 0.004 Plant 55 Fired Heater Stripper Reboiler 470630 6318562 252 37.5 1.78 6.1 625 0.018 0.032 0.045 0.003 0.004 Plant 55 Fired Heater Combined Feed Heater 470710 6318421 247 38.1 1.16 6.1 535 0.016 0.025 0.040 0.003 0.004

Suncor Millennium

Plant 57 Diluent Tower Heater 470733 6318662 245 49.1 1.73 10.1 483 0.116 0.126 0.111 0.007 0.010


December 2009

Page B2-53

Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s) Exit Temp

(K) SO2

1

(t/d) NOX (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Plant 57 Diluent Tower Heater 470748 6318761 245 49.1 1.73 10.1 483 0.116 0.126 0.111 0.007 0.010 Plant 57 Vacuum Tower Heater 470777 6318686 244 47.8 1.85 10.1 483 0.155 0.159 0.149 0.010 0.014 Plant 57 Vacuum Tower Heater 470789 6318691 247 47.8 1.85 10.1 483 0.155 0.159 0.149 0.010 0.014 Plant 52 Coker Charge Heaters 470912 6318381 245 60.7 3.28 7.6 487 0.317 0.340 0.305 0.020 0.028 Naphtha Hydrotreater #3 Reactor Charge Heater 470411 6318623 261 38.1 0.52 5.6 533 0.031 0.021 0.026 0.002 0.002

Suncor Millennium (cont)

Hydrogen Plant #3 470465 6318577 260 42.7 3.5 13.7 422 0.159 0.422 0.324 0.021 0.029 Sulphur Plant Incinerator 469120 6314086 321 89.9 4.17 15.2 673 7.074 0.362 0.104 0.007 0.009 Hydrogen Plant Train 1 469248 6314274 322 42.7 4.04 13.7 422 0.013 1.407 1.200 0.079 0.109 Hydrogen Plant Train 2 469332 6314233 323 42.7 3.3 13.7 422 0.008 0.939 0.801 0.052 0.072 Delayed Coker Unit 1 468914 6314251 319 39.6 4.31 7.6 444 0.390 0.525 0.465 0.030 0.042 Delayed Coker Unit 2 468934 6314241 319 39.6 4.31 7.6 444 0.390 0.525 0.465 0.030 0.042 Delayed Coker Unit 3 468956 6314230 319 39.6 4.31 7.6 444 0.390 0.525 0.465 0.030 0.042 Diesel Hydrotreater Unit 1 469012 6314457 320 39.6 1.5 7.6 478 0.048 0.043 0.057 0.004 0.005 Diesel Hydrotreater Unit 2 468976 6314380 320 45.7 2.46 7.6 444 0.127 0.174 0.152 0.010 0.014 Gas Oil Hydrotreater Unit 469141 6314343 321 39.6 1.51 7.6 478 0.048 0.042 0.057 0.004 0.005 Naphtha Hydrotreater Unit 468869 6314459 318 38.1 1.09 5.6 533 0.030 0.026 0.036 0.002 0.003 Boiler Package Heater 469205 6314572 322 38.1 3.22 7.6 478 0.219 0.295 0.261 0.017 0.024 Steam Superheater 469257 6314546 322 45.7 0.65 7.6 478 0.010 0.009 0.012 0.001 0.001 Fuel Gas Pipeline Heater 469404 6314474 324 45.7 0.69 7.6 478 0.010 0.009 0.012 0.001 0.001 Hot Bitumen Heating Furnace 468904 6314127 319 45.7 0.61 7.6 478 0.010 0.008 0.011 0.001 0.001 Vacuum Recovery Unit Combustion Unit 468786 6314288 318 45.7 1.34 7.6 478 0.048 0.042 0.057 0.004 0.005 Vacuum Tower Heater 1 468804 6314324 318 47.8 2.06 10.1 483 0.146 0.197 0.175 0.011 0.016 Vacuum Tower Heater 2 468769 6314250 318 47.8 2.06 10.1 483 0.146 0.197 0.175 0.011 0.016

Suncor Voyageur

Gasifier, High Pressure Boiler Package Heater 469230 6314560 322 38.1 0.76 7.6 478 0.017 0.014 0.020 0.001 0.002 Stage 1 - Steam Generator No. 1 508932 6343662 582 30 1.7 22.4 432 0.187 0.359 0.291 0.019 0.026 Stage 1 - Steam Generator No. 2 508956 6343662 582 30 1.7 19.4 420 0.128 0.402 0.114 0.005 0.075 Stage 1 - Steam Generator No. 3 508932 6343575 582 30 1.7 19.4 420 0.128 0.402 0.114 0.005 0.075 Stage 1 - Steam Generator No. 4 508956 6343575 582 30 1.7 19.4 420 0.128 0.402 0.114 0.005 0.075 Stage 2 - Steam Generator No. 1 509138 6343660 582 30 1.7 22.4 432 0.187 0.359 0.291 0.019 0.026 Stage 2 - Steam Generator No. 2 509162 6343660 582 30 1.7 19.4 420 0.128 0.402 0.114 0.005 0.075 Stage 2 - Steam Generator No. 3 509162 6343574 582 30 1.7 19.4 420 0.128 0.402 0.114 0.005 0.075 Stage 2 - Steam Generator No. 4 509138 6343573 582 30 1.7 19.4 420 0.128 0.402 0.114 0.005 0.075 Stage C & E - Cogeneration Unit 508875 6343657 582 27 5.49 16.8 439 0.380 1.846 1.199 0.047 0.101 Stage 3 - Cogeneration Unit No. 1 508890 6344358 583 27 5.49 16.8 439 0.262 1.846 1.199 0.047 0.101

Suncor Firebag SAGD

Stage 3 - Cogeneration Unit No. 2 508838 6344358 583 27 5.49 16.8 439 0.262 1.846 1.199 0.047 0.101


December 2009

Page B2-54

Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s) Exit Temp

(K) SO2

1

(t/d) NOX (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Stage 3 - Steam Generator No. 1 508799 6344506 583 33 1.66 22.2 398 0.151 0.290 0.235 0.015 0.021 Stage 3 - Steam Generator No. 2 508888 6344506 583 33 1.66 22.2 398 0.151 0.290 0.235 0.015 0.021 Stage 3 - Steam Generator No. 3 508888 6344494 583 33 1.66 22.2 398 0.151 0.290 0.235 0.015 0.021 Stage 3 - Steam Generator No. 4 508800 6344518 583 33 1.66 22.2 398 0.151 0.290 0.235 0.015 0.021 Stage 3 - Steam Generator No. 5 508800 6344494 583 33 1.66 22.2 398 0.151 0.290 0.235 0.015 0.021 Stage 3 - Diluent Stripper Unit 509056 6344341 583 33 1.09 11.1 398 0.166 0.319 0.259 0.017 0.023 Stage 3 - SRU Vent Gas Incinerator 509052 6344840 583 5 0.24 5.14 750 0.000 0.001 0.001 0.000 0.000 Stage 4 - Steam Generator No. 1 508799 6344639 583 33 1.66 22.2 398 0.147 0.282 0.229 0.015 0.021 Stage 4 - Steam Generator No. 2 508799 6344627 583 33 1.66 22.2 398 0.147 0.282 0.229 0.015 0.021 Stage 4 - Steam Generator No. 3 508799 6344616 583 33 1.66 22.2 398 0.147 0.282 0.229 0.015 0.021 Stage 4 - Steam Generator No. 4 508800 6344603 583 33 1.66 22.2 398 0.147 0.282 0.229 0.015 0.021 Stage 4 - Steam Generator No. 5 508799 6344591 583 33 1.66 22.2 398 0.147 0.282 0.229 0.015 0.021 Stage 4 - Steam Generator No. 6 508889 6344639 583 33 1.66 22.2 398 0.147 0.282 0.229 0.015 0.021 Stage 4 - Steam Generator No. 7 508888 6344627 583 33 1.66 22.2 398 0.147 0.282 0.229 0.015 0.021 Stage 4 - Steam Generator No. 8 508888 6344615 583 33 1.66 22.2 398 0.147 0.282 0.229 0.015 0.021 Stage 4 - Steam Generator No. 9 508889 6344603 583 33 1.66 22.2 398 0.147 0.282 0.229 0.015 0.021 Stage 4 - Steam Generator No. 10 508888 6344591 583 33 1.66 22.2 398 0.147 0.282 0.229 0.015 0.021 Stage 5 - Cogeneration Unit 508756 6344358 583 27 5.49 16.8 439 0.262 1.846 1.199 0.047 0.101 Stage 5 - Steam Generator No. 1 508672 6344530 583 33 1.66 22.2 398 0.147 0.282 0.229 0.015 0.021 Stage 5 - Steam Generator No. 2 508671 6344518 583 33 1.66 22.2 398 0.147 0.282 0.229 0.015 0.021 Stage 5 - Steam Generator No. 3 508671 6344506 583 33 1.66 22.2 398 0.147 0.282 0.229 0.015 0.021 Stage 5 - Steam Generator No. 4 508671 6344494 583 33 1.66 22.2 398 0.147 0.282 0.229 0.015 0.021 Stage 5 - Steam Generator No. 5 508761 6344518 583 33 1.66 22.2 398 0.147 0.282 0.229 0.015 0.021 Stage 5 - Steam Generator No. 6 508760 6344505 583 33 1.66 22.2 398 0.147 0.282 0.229 0.015 0.021 Stage 5 - Steam Generator No. 7 508761 6344494 583 33 1.66 22.2 398 0.147 0.282 0.229 0.015 0.021 Stage 5 - Diluent Stripper Unit 509213 6344342 583 33 1.09 11.1 398 0.166 0.319 0.259 0.017 0.023 Stage 6 - Cogeneration Unit 508704 6344358 583 27 5.49 16.8 439 0.262 1.846 1.199 0.047 0.101 Stage 6 - Steam Generator No. 1 508671 6344639 584 33 1.66 22.2 398 0.147 0.282 0.229 0.015 0.021 Stage 6 - Steam Generator No. 2 508671 6344627 584 33 1.66 22.2 398 0.147 0.282 0.229 0.015 0.021 Stage 6 - Steam Generator No. 3 508671 6344615 584 33 1.66 22.2 398 0.147 0.282 0.229 0.015 0.021 Stage 6 - Steam Generator No. 4 508761 6344639 583 33 1.66 22.2 398 0.147 0.282 0.229 0.015 0.021 Stage 6 - Steam Generator No. 5 508761 6344627 583 33 1.66 22.2 398 0.147 0.282 0.229 0.015 0.021 Stage 6 - Steam Generator No. 6 508761 6344615 583 33 1.66 22.2 398 0.147 0.282 0.229 0.015 0.021

Suncor Firebag SAGD (cont)

Stage 6 - Steam Generator No. 7 508761 6344603 583 33 1.66 22.2 398 0.147 0.282 0.229 0.015 0.021


December 2009

Page B2-55

Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s) Exit Temp

(K) SO2

1

(t/d) NOX (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

ETS Pilot - Steam Generator No. 1 509627 6341492 579 3.8 0.15 79.5 813 0.002 0.096 0.022 0.008 0.003 ETS Pilot - Steam Generator No. 2 509622 6341479 579 3.8 0.15 79.5 813 0.002 0.096 0.022 0.008 0.003 ETS Pilot - Heater No. 1 509639 6341477 579 6.1 0.25 40 594 0.003 0.007 0.013 0.001 0.001

Suncor Firebag ETS

ETS Pilot - Heater No. 2 509637 6341463 579 6.1 0.1 40 589 0.001 0.003 0.002 0.000 0.000 Area Source


NW UTM N

NE UTM E

NE UTM N

SE UTM E

SE UTM N

SW UTM E

SW UTM N

Area (m2)

Elevation(masl)

SO21

(t/d) NOX (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Mine Area 1 474421 6311147 478254 6311147 478244 6306719 474431 6306719 16927841 327.92 0.030 5.330 5.719 2.260 0.280 Mine Area 2 478383 6311147 481401 6311147 481401 6307136 478373 6307116 12157244 353.42 0.022 3.828 4.107 1.623 0.201 Mine Area 3 477865 6314587 481033 6314560 481075 6311254 477865 6311254 10583788 355.42 0.019 3.332 3.576 1.413 0.175 Mine Area 4 473940 6315427 477810 6315427 477797 6311240 473954 6311254 16121151 329.72 0.029 5.076 5.447 2.152 0.266 Mine Area 5 473885 6316612 475317 6316584 475372 6315510 473885 6315510 1588191 317.62 0.003 0.500 0.537 0.212 0.026 Mine Area 6 472714 6317590 473348 6318251 474312 6317245 473706 6316667 1203634 275.82 0.002 0.379 0.407 0.161 0.020 Mine Area 7 471819 6319077 472480 6319546 473182 6318457 472590 6317920 1073979 264.62 0.002 0.338 0.363 0.143 0.018 Tailings Ponds 468233 6317061 469459 6317061 469459 6315759 468233 6315759 1595400 311.7 0.000 0.000 0.000 176.866 0.000 South Tailings Pond 478109 6305130 481783 6305130 481783 6301456 478109 6301456 13499746 357.1 0.000 0.000 0.000 4.536 0.000

Suncor Millennium

Plant Fugitives 470238 6318402 470728 6318693 471443 6317492 470953 6317203 795855 255.9 0.000 0.000 0.000 16.982 0.000 Coke Handling Fleet 468667 6313491 469044 6314095 470775 6312095 469325 6311351 2696581 317.7 0.009 0.771 0.478 0.107 0.027 Plant Fugitives 468970 6314830 469922 6314350 469599 6313701 468647 6314184 772176 322.4 0.000 0.000 0.000 0.609 0.000 Suncor Voyageur Tank Farm Fugitives 471088 6313692 471678 6313692 471678 6312961 471088 6312961 431354 321.1 0.000 0.000 0.000 0.261 0.000 Mine Area 1 474503 6320144 475436 6321077 477273 6319240 476341 6318310 3423903 336.3 0.041 7.199 7.725 3.052 0.378 Mine Area 2 477771 6318332 479603 6318332 479603 6316809 477635 6316955 2759239 341.4 0.033 5.802 6.225 2.460 0.304

North Steepbank Extension

Mine Area 3 475241 6318058 475672 6318712 477685 6317490 477361 6316846 1800591 338.1 0.022 3.786 4.062 1.605 0.199 Suncor Firebag Plant Fugitives 508630 6344914 509611 6344910 509260 6343024 508630 6343016 1523598 582.4 0.0 0.0 0.0 0.058 0.0 Suncor Air Emission Totals for the Planned Development Scenario 72.375 112.116 69.056 216.367 9.226

1 Sulphur Dioxide emission rates are based on Calendar Day. 2 Elevation sunken 50 m in modelling to compensate for the mine pit.


December 2009

Page B2-56

2.19 Syncrude Canada Ltd.

Emissions Included in the Baseline, Project and Planned Development Scenarios The Syncrude Canada Ltd. industrial activities include the following approved facilities: the expanded Mildred Lake Upgrader facility (including the North Mine), the Aurora North Mine and the Aurora South Mine. The Mildred Lake facility will produce approximately 480 000 b/d of synthetic crude oil. The North Mine production is about 160 000 b/d of bitumen. The Aurora North Mine target production is approximately 215 000 b/d of bitumen. The Aurora North facility is located 35 km northeast of the Mildred Lake facility. The Aurora South Mine will be located east of the Albian Sands Lease 13, and immediately to the west of the Husky Sunrise Project. The Aurora South Mine production capacity is expected to be 215 000 b/d of bitumen. In November 2004, Syncrude received regulatory approval for the Syncrude Emissions Reduction (SER) Project at the Mildred Lake facility. The project involves the retrofit of a flue gas scrubbing system into the operation of Syncrude’s two existing cokers. In combination with sulphur dioxide emission reduction technology also being incorporated into a third coker now under construction, the project will reduce stack emissions of SO2 by 60% from current approved levels of 245 t/d. The reduction will be gradually achieved over the course of a two-year period after start-up in 2009. A 50% reduction in emissions of PM2.5 will also be achieved. The main point emission sources at the Mildred Lake Plant are the Main Stack, FGD stack and numerous secondary stacks. Area emission sources include the mine fleets, mine faces, and tailings disposal areas and ponds. Table B2-32 provides a summary of emissions from existing and approved Syncrude facilities that were included in the baseline, project and planned development scenarios on a facility and a source-grouping basis.


December 2009

Page B2-57

Table B2-32: Summary of Syncrude Air Emissions Used for the Baseline, Project and Planned Development Scenarios

Point Sources


UTM N (m)

Elevation (masl)

Stack Height (m)

Stack Diameter (m)

Exit Velocity (m/s)

Exit Temp (K)

SO2 (t/d)

NOX(t/d)

CO(t/d)

VOC(t/d)

PM2.5 (t/d)

FGD stack 8-3 462807 6322880 308 76.2 6.6 10.5 348 15.00 3.50 13.50 0.00 2.10

Gas Turbine 201 462693 6322003 305 45.7 3.3 15.8 423 0.00 2.28 0.36 0.01 0.10

Gas Turbine 202 462721 6322012 305 45.7 3.3 15.8 423 0.00 2.28 0.36 0.01 0.10

Bitumen Column Feed Heater 71F1A 462596 6322427 308 51.8 3.2 5.7 422 0.00 0.43 0.12 0.004 0.037

Bitumen Column Feed Heater 71F1B 462617 6322434 308 51.8 3.2 5.7 422 0.00 0.43 0.12 0.004 0.037







Steam Super Heater 81F6A 462662 6322261 308 39.6 2.1 5.2 616 0.00 0.08 0.03 0.002 0.011

Steam Super Heater 81F6B 462683 6322268 308 44.7 1.1 6.1 616 0.00 0.03 0.01 0.001 0.004





Reformer Furnace 91F1 463084 6322453 308 23.5 4.1 11.6 540 0.00 2.10 0.32 0.011 0.10





Diluent Reboiler 14F1 462647 6322475 308 30.5 1.1 7.8 618 0.00 0.15 0.01 0.001 0.004

Hydrogen Heater 151F1 462879 6322400 312 41.8 1.7 7.7 426 0.00 0.15 0.04 0.003 0.015


Mildred Lake



December 2009

Page B2-58

Point Sources


UTM N (m)

Elevation (masl)

Stack Height (m)

Stack Diameter (m)

Exit Velocity (m/s)

Exit Temp (K)

SO2 (t/d)

NOX(t/d)

CO(t/d)

VOC(t/d)

PM2.5 (t/d)






Fractionator Reboiler 151F2 462820 6322545 312 45.7 1.9 8.0 653 0.00 0.13 0.03 0.003 0.013






Bitumen Feed 221F1 463038 6322626 312 45.7 1.7 8.2 652 0.00 0.09 0.03 0.002 0.01

Bitumen Heater 21F7 462865 6323038 308 6.1 0.3 29.0 839 0.00 0.03 0.007 0.001 0.003

Bitumen Heater 21F8 462898 6323049 308 6.1 0.3 29.0 839 0.00 0.03 0.007 0.001 0.003

Bitumen Heater 21F9 462933 6322830 308 6.1 0.3 29.0 839 0.00 0.03 0.007 0.001 0.003

Bitumen Heater 21F10 462966 6322841 308 6.1 0.3 29.0 839 0.00 0.03 0.007 0.001 0.003

Bitumen Heater 21F50 463964 6322778 312 7.6 0.3 29.0 839 0.00 0.03 0.007 0.001 0.003

Bitumen Heater 21F51 464025 6322590 312 7.6 0.3 29.0 839 0.00 0.03 0.007 0.001 0.003

Bitumen Heater 21F52 464062 6322477 312 7.6 0.3 29.0 839 0.00 0.03 0.007 0.001 0.003

Bitumen Heater 21F53 463997 6322675 312 7.6 0.3 29.0 839 0.00 0.03 0.007 0.001 0.003

Sulfreen Regeneration 120F10 462741 6322333 308 15.4 0.5 37.2 616 0.00 0.06 0.01 0.001 0.004

VDU Bitumen Feed Heater 371F1A 462578 6322525 308 54.3 3.3 4.0 435 0.00 0.20 0.10 0.003 0.02

VDU Bitumen Feed Heater 371F1B 462607 6322535 308 54.3 3.3 4.0 435 0.00 0.20 0.10 0.003 0.02

Mildred Lake (cont)

Main stack 462632 6322111 308 183.0 7.9 28.8 513 81.00 14.80 45.00 0.00 1.60 Steam Generator 469402 6350746 302 25.0 3.3 33.9 460 0.00 0.62 0.14 0.01 0.06 Steam Generator 469402 6350779 302 25.0 3.3 33.9 460 0.00 0.62 0.14 0.01 0.06 Boiler 469370 6350733 302 25.0 2.7 37.7 455 0.00 0.57 0.13 0.01 0.05

Aurora North

Boiler 469390 6350733 302 25.0 2.7 37.7 455 0.00 0.57 0.13 0.01 0.05


December 2009

Page B2-59

Point Sources


UTM N (m)

Elevation (masl)

Stack Height (m)

Stack Diameter (m)

Exit Velocity (m/s)

Exit Temp (K)

SO2 (t/d)

NOX(t/d)

CO(t/d)

VOC(t/d)

PM2.5 (t/d)

Steam Generator 484164 6342667 334 25.0 3.3 33.9 460 0.00 0.62 0.14 0.01 0.06

Steam Generator 484164 6342700 334 25.0 3.3 33.9 460 0.00 0.62 0.14 0.01 0.06

Boiler 484151 6342653 334 25.0 2.7 37.7 455 0.00 0.57 0.13 0.01 0.05

Aurora South

Boiler 484131 6342653 334 25.0 2.7 37.7 455 0.00 0.57 0.13 0.01 0.05

Area Sources


NW UTM N

NE UTM E

NE UTM N

SE UTM E

SE UTM N

SW UTM E

SW UTM N

Area (m2)

Elevation(masl)

SO2 (t/d)

NOX(t/d)

CO(t/d)

VOC(t/d)

PM2.5 (t/d)

Effluent Tailings Pond 462004 6322243 462254 6322243 462254 6321843 462004 6321843 100000 296 0.00 0.00 0.00 4.98 0.00

North Mine face 455832 6323363 459532 6323363 459532 6321163 455832 6321163 8100000 271 0.00 0.00 0.00 6.18 0.00

North Mine Fleet 455832 6323363 459532 6323363 459532 6321163 455832 6321163 8100000 2711 0.85 17.20 4.50 0.77 0.41

Tailings Pond – Settling Basin Beach 459340 6327610 463640 6327610 463640 6323310 459340 6323310 18490000 304 0.00 0.00 0.00 0.31 0.00

Tailings Pond – Settling Basin Water 460470 6327060 463870 6327060 463870 6323660 460470 6323660 11560000 302 0.00 0.00 0.00 33.20 0.00

Tailings – East In-Pit 464150 6320450 467350 6320450 467350 6317250 464150 6317250 10240000 309 0.00 0.00 0.00 0.71 0.00

Tailings – SW Sand Storage Beach 452650 6319190 457450 6319190 457450 6314390 452650 6314390 23040000 357 0.00 0.00 0.00 7.50 0.00

Tailings – SW Sand Storage Water 452780 6316480 454180 6316480 454180 6315080 452780 6315080 1960000 374 0.00 0.00 0.00 0.65 0.00

Tailings – West In-Pit 461460 6319930 464010 6319930 464010 6317380 461460 6317380 6500000 308 0.00 0.00 0.00 0.46 0.00

West Mine face 458794 6318621 460394 6318621 460394 6316321 458794 6316321 3700000 3111 0.00 0.00 0.00 0.80 0.00

Mildred Lake

West Mine Fleet 458794 6318621 460394 6318621 460394 6316321 458794 6316321 3700000 311 0.10 2.00 0.50 0.09 0.05

Mine Fugitives 466965 6354537 468965 6354537 468965 6351537 466965 6351537 6000000 304 0.00 0.00 0.00 6.21 0.00

Mine Fleet 466965 6354537 468965 6354537 468965 6351537 466965 6351537 6000000 3041 0.59 13.10 3.20 0.54 0.29 Aurora North

Tailings Pond 472990 6352490 474890 6352490 474890 6350590 472990 6350590 3610000 286 0.00 0.00 0.00 1.12 0.00

Mine Fugitives 482935 6347587 484935 6347587 484935 6344587 482935 6344587 6000000 331 0.00 0.00 0.00 6.21 0.00

Mine Fleet 482935 6347587 484935 6347587 484935 6344587 482935 6344587 6000000 3311 0.45 9.90 2.40 0.41 0.22 Aurora South

Tailings Pond 486630 6340330 488530 6340330 488530 6338430 486630 6338430 3610000 381 0.00 0.00 0.00 1.12 0.00

Syncrude Air Emission Totals for Baseline, Project and Planned Development Scenarios 97.99 91.78 77.62 71.54 6.75 1 Elevation sunken 50 m in modelling to compensate for the mine pit.


December 2009

Page B2-60

2.20 Whitesands Insitu Partnership

Emissions Included in the Baseline, Project and Planned Development Scenarios Whitesands Insitu Partnership operates the Whitesands Pilot Project, located west of Conklin. Table B2-33 provides a summary of the emissions included in the baseline, project and planned development scenarios.

2.21 Williams Energy Canada

Emissions Included in the Baseline, Project and Planned Development Scenarios Williams Energy operates a liquid/olefin extraction plant located immediately south of the Suncor processing plant facilities. Olefin is a constituent in the gaseous streams from the Suncor oil sands upgrading process. Table B2-34 provides a summary of the emissions included in the baseline, project and planned development scenarios.

3.0 PROJECT EMISSIONS

Table B2-35 provides a summary of the emissions from the BlackGold facility included in the project and planned development scenarios.

4.0 SMALL GAS PRODUCTION AND PROCESSING FACILITIES

The emissions from several gas compression and processing facilities located within the AQRSA are included in all three of the emission scenarios. Table B2-36 presents a summary of the emissions included in the baseline, project and planned development scenarios.


December 2009

Page B2-61

Table B2-33: Summary of Whitesands Insitu Partnership Air Emissions Included in the Baseline, Project and Planned Development Scenarios

Point Sources


UTM N (m)

Elevation (masl)

Stack Height (m)

Stack Diameter (m)

Exit Velocity (m/s)

Exit Temp (K)

SO2 (t/d)

NOX (t/d))

CO (t/d)

VOC(t/d)

PM2.5 (t/d)

Flare 483752 6168334 613 13.00 0.20 0.30 1273 0.00 0.00 0.00 0.00 0.00

Vent 483910 6168229 612 35.00 0.20 111.00 323 0.08 0.00 9.17 0.00 0.00 Pilot

Steam Generator 483885 6168281 612 12.30 1.50 5.10 477 0.00 0.04 0.06 0.00 0.00

Whitesands Air Emission Totals used for the Baseline, Project and Planned Development Scenarios 0.08 0.04 9.23 0.00 0.00


December 2009

Page B2-62

Table B2-34: Summary of Williams Energy Existing Air Emissions Included in the Baseline, Project and Planned Development Scenarios

Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s)

Exit Temp

(K) SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Fort McMurray Chemical Plant Heat Medium Heater 471754 6314125 325 32.4 1.4 6.2 553 0.013 0.02 0.02 0.26 0.008

Williams Energy Air Emission Totals for the Baseline, Project and Planned Development Scenarios 0.013 0.02 0.02 0.26 0.008


December 2009

Page B2-63

Table B2-35: Summary Project Air Emissions Included in the Project and Planned Development Scenarios Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diameter

(m)

Exit Velocity

(m/s)

Exit Temp

(K)

SO2 (t/d)

NOX (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Steam Generator 500996 6159358 606 30.0 1.50 27.0 483 0.21 0.30 0.22 0.02 0.03 Steam Generator 501006 6159358 606 30.0 1.50 27.0 483 0.21 0.30 0.22 0.02 0.03 BlackGold Glycol Heater 501056 6159357 606 15.0 0.40 27.0 466 0.00 0.02 0.01 0.00 0.00 Steam Generator 30.0 1.50 27.0 483 0.21 0.30 0.22 0.02 0.03 Steam Generator 30.0 1.50 27.0 483 0.21 0.30 0.22 0.02 0.03 Glycol Heater 15.0 0.40 27.0 466 0.00 0.02 0.01 0.00 0.00 HP Flare 500830 6159314 611 36.0 0.40 27.0 813 0.00 0.00 0.00 0.00 0.00

Expansion

LP Flare 500830 6159314 611 36.0 0.40 27.0 813 0.00 0.00 0.00 0.00 0.00 KNOC BlackGold Air Emission Totals for the Baseline, Project and Planned Development Scenarios 0.84 1.24 0.91 0.10 0.13


December 2009

Page B2-64

Table B2-36: Summary of Gas Production and Processing Facility Emissions Included in the Baseline, Project and Planned Development Scenarios

Point Sources

Operator Facility Emissions Source UTM E (m)

UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diamete

r (m)

Exit Velocity

(m/s)

Exit Temp

(K) SO2 (t/d)

NOx (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Compressor 428498 6192584 708 10 0.50 12 773 0 0.26 0.04 0 0 Compressor 424212 6204393 579 10 0.50 12 773 0 0.19 0.04 0 0 Compressor 435630 6205421 677 10 0.50 6 773 0 0.12 0.02 0 0 Compressor 435630 6205421 677 10 0.50 10 773 0 0.38 0.03 0 0

Compressor Station

Compressor 449199 6216577 742 10 0.50 6 773 0 0.24 0.02 0 0 Wauk. L7042GSI 437521 6192311 696 10 0.50 48 773 0 0.64 0.15 0 0 Thornbury South

Compressor Station Wauk F3521GL 437521 6192311 696 10 0.50 24 773 0 0.03 0.08 0 0 Wauk L7042 GSI 529516 6179016 570 10 0.50 40 773 0 0.53 0.13 0 0 Cat G3516 TA 529516 6179016 570 10 0.50 41 773 0 0.54 0.13 0 0

AltaGas Services Inc.

Winefred North Sweet Cat G3304 NA 529516 6179016 570 10 0.50 3 773 0 0.04 0.01 0 0 Wauk L7042 GSI 440647 5999476 649 10 0.50 39 773 0 0.52 0.12 0 0 Anadarko Vilna Sweet Comp Wauk L7042 GSI 440647 5999476 649 10 0.50 39 773 0 0.52 0.12 0 0 Wauk F3521 486436 6032400 573 10 0.50 23 773 0 0.3 0.07 0 0 ARC Resources Cessford 3-6 Comp. Cat G3306 TA 486436 6032400 573 10 0.50 6 773 0 0.11 0.02 0 0 Compressor Engine 483400 6174232 582 10 0.50 15 773 0 0.2 0.05 0 0 MEP 12 Cyl 483400 6174232 582 12 0.66 34 672 0 1.47 0.01 0 0 MEP 12 Cyl 483400 6174232 582 12 0.66 34 672 0 1.47 0.01 0 0 MEP 12 Cyl 483400 6174232 582 15 0.61 40 672 0 0.73 0.01 0 0

Amoco Sweet Compressor Station

Superior 16SGTB 483400 6174232 582 12 0.46 44 691 0 0.09 0.01 0 0 Compressor Engine 492746 6170164 561 10 0.50 6 773 0 0.1 0.02 0 0 Compressor Engine 487456 6170984 563 10 0.50 26 773 0 0.05 0.08 0 0 Compressor Engine 493153 6170971 554 10 0.50 6 773 0 0.12 0.02 0 0 Compressor Engine 478121 6175059 602 10 0.50 13 773 0 0.19 0.04 0 0

Compressor Station

Compressor Engine 509104 6145080 641 10 0.50 18 773 0 0.01 0.06 0 0 Superior 16SGT 523574 6134466 674 10 0.50 85 773 0 1.14 0.27 0 0 Wauk L7044 GSI 523574 6134466 674 10 0.50 54 773 0 0.05 0.17 0 0 Wauk F3521G 523574 6134466 674 10 0.50 14 773 0 0.18 0.04 0 0 Wauk F3521G 523574 6134466 674 10 0.50 14 773 0 0.18 0.04 0 0 Wauk F3521G 523574 6134466 674 10 0.50 14 773 0 0.18 0.04 0 0 Superior 16SGT 523574 6134466 674 10 0.50 85 773 0 1.14 0.27 0 0 Solar Centaur Type H 523574 6134466 674 10 0.50 178 773 0 0.23 0.57 0 0

Kirby Sweet South Compressor Station

Superior 16SGT 523574 6134466 674 10 0.50 85 773 0 1.14 0.27 0 0 Wauk L5790GL 516021 6139028 635 9 0.30 50 644 0 0.13 0.12 0 0 Wauk L5790GL 516021 6139028 635 9 0.30 50 644 0 0.13 0.12 0 0

BP Canada Energy Co.

Primrose/Kirby Sweet Wauk L5790GL 516021 6139028 635 9 0.30 50 644 0 0.13 0.12 0 0


December 2009

Page B2-65

Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diamete

r (m)

Exit Velocity

(m/s)

Exit Temp

(K) SO2 (t/d)

NOx (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Superior 8g-825 486624 6032149 571 14 0.25 34 793 0 0.28 0.08 0 0 Wauk L7042 GSI 486624 6032149 571 14 0.25 56 862 0 0.53 0.13 0 0 Wauk F18 GL 486624 6032149 571 6 0.25 55 720 0 0.02 0.04 0 0 Wauk F3521 GL 486624 6032149 571 7 0.31 40 683 0 0.02 0.06 0 0

BP Canada Energy Co. (cont) St. Lina North Sweet Comp.

Wauk L7042 GL 486624 6032149 571 9 0.33 48 978 0 0.05 0.15 0 0 Canadian Abraxis Bellis Sweet Comp Wauk F3521 GSI 414534 5995975 596 7 0.20 51 886 0 0.32 0.08 0 0

Wauk. L5790GSI 419323 6240371 533 10 0.50 41 773 0 0.21 0.13 0 0 Algar Lake Cat 3412 TA 419323 6240371 533 10 0.50 19 773 0 0.27 0.06 0 0 Wauk. 3521GL 511175 6195915 491 10 0.50 24 773 0 0.03 0.08 0 0 Wauk 7042GSI 511175 6195915 491 10 0.50 40 773 0 0.21 0.13 0 0 Wauk 7042GSI 511175 6195915 491 10 0.50 40 773 0 0.21 0.13 0 0 Wauk 7042GSI 511175 6195915 491 10 0.50 40 773 0 0.21 0.13 0 0 Wauk 7042GSI 511175 6195915 491 10 0.50 40 773 0 0.21 0.13 0 0

Chard Sweet Comp. Station

Compressor 455056 6194251 690 10 0.50 24 773 0 0.3 0.08 0 0

House Algar White 16G-825

405535 6216353 535 10 0.50 51 773 0 0.57 0.16 0 0

Edwand Comp. CAT G3512 TA 410788 6013035 697 9 0.20 83 726 0 0.04 0.1 0 0 Hylo Comp. Superior 8GT-825 427310 6066914 583 10 0.50 35 773 0 0.4 0.11 0 0

Wauk .F11GL 520417 6228335 481 6 0.50 3 773 0 0.04 0.01 0 0 Wauk .F11GL 520417 6228335 481 6 0.50 3 773 0 0.04 0.01 0 0 Wauk .F11GL 520417 6228335 481 6 0.50 3 773 0 0.04 0.01 0 0 Wauk. L7042GSI 520417 6228335 481 9 0.50 45 773 0 0.05 0.14 0 0 Wauk. L7042GSI 520417 6228335 481 9 0.50 45 773 0 0.05 0.14 0 0 Wauk. L7042GSI 520417 6228335 481 9 0.50 45 773 0 0.05 0.14 0 0

Newby Sour Gas Plant

Wauk. L7042GSI 520417 6228335 481 9 0.50 45 773 0 0.05 0.14 0 0 Compressor 421287 6225510 547 10 0.50 6 773 0 0.11 0.02 0 0 Compressor 505480 6240981 494 10 0.50 6 773 0 0.11 0.02 0 0

CNRL

Rio Alto Comp. Station Compressor 525427 6244291 459 10 0.50 47 773 0 0.05 0.15 0 0

Delek Resources Compressor Compressor 417048 6122787 593 10 0.50 7 773 0 0.02 0.02 0 0 Chard 11-02 CAT 3406 Turbo 501285 6176231 555 10 0.50 10 773 0 0.17 0.03 0 0 Chard Sweet CAT 3406 Turbo 508197 6175417 613 10 0.50 11 773 0 0.23 0.03 0 0 Compressor Cat 3306TA 487543 6235738 757 10 0.50 7 773 0 0.09 0.02 0 0 Hangingstone 05-13 Cat 3306TA 462278 6237500 618 10 0.50 7 773 0 0.09 0.02 0 0 Hangingstone 06-29 Cat 3306TA 475691 6230930 713 10 0.50 7 773 0 0.09 0.02 0 0 Hangingstone 11-19 Cat 3306TA 474109 6239435 674 10 0.50 7 773 0 0.09 0.02 0 0

Wauk. L7042GSI 469198 6236234 656 12 0.31 37 862 0 0.52 0.12 0 0 Wauk. L7042GSI 469198 6236234 656 12 0.31 37 862 0 0.52 0.12 0 0

Devon ARL

Hangingstone Sweet Comp.

Cat G3412 469198 6236234 656 7 0.20 73 772 0 0.03 0.07 0 0


December 2009

Page B2-66

Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diamete

r (m)

Exit Velocity

(m/s)

Exit Temp

(K) SO2 (t/d)

NOx (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Cat G3412 469198 6236234 656 7 0.20 73 772 0 0.03 0.07 0 0 Wauk. L7042GSI 469198 6236234 656 12 0.31 37 862 0 0.05 0.12 0 0

Kirby N. 11-03 Booster CAT 3412 Turbo 509457 6156810 590 10 0.50 20 773 0 0.32 0.06 0 0 Kirby N. Sweet Comp. Wauk 7042 GSI 505784 6157210 603 10 0.50 44 773 0 0.04 0.14 0 0 Kirby S. 07-02A CAT 3406 Turbo 511525 6146696 654 10 0.50 11 773 0 0.08 0.03 0 0 Kirby S. 07-09 Wauk 3521 GSI Turbo 518064 6148339 629 10 0.50 19 773 0 0.26 0.06 0 0 Kirby S. 16-25 Wauk H24GL 523720 6144328 619 10 0.50 17 773 0 0.03 0.05 0 0

Wauk 3521 GSI Turbo 517473 6147380 641 11 0.25 35 878 0 0.32 0.08 0 0 Wauk 3521 GSI Turbo 517473 6147380 641 11 0.25 35 878 0 0.32 0.08 0 0 Wauk 3521 GSI Turbo 517473 6147380 641 11 0.25 41 683 0 0.03 0.08 0 0

Kirby Sweet Comp.

Wauk 9390 GL Turbo 517473 6147380 641 11 0.34 58 679 0 0.07 0.2 0 0 MEP 10 NA 494777 6167326 566 14 0.59 36 644 0 0.6 0.23 0 0 MEP 10 NA 494777 6167326 566 14 0.59 36 644 0 0.6 0.23 0 0 MEP 10 Turbo 494777 6167326 566 14 0.59 34 644 0 0.13 0.28 0 0 MEP 10 Turbo 494777 6167326 566 14 0.59 34 644 0 0.13 0.28 0 0 Wauk F2895 GU 494777 6167326 566 6 0.20 26 861 0 0.16 0 0 0 Wauk F2895 GU 494777 6167326 566 6 0.20 26 861 0 0.16 0 0 0 Wauk F2895 GU 494777 6167326 566 6 0.20 26 861 0 0.16 0 0 0 Heat Med. Boiler 494777 6167326 566 6 0.38 33 728 0 0.01 0 0 0

Leismer East Sweet Comp.

Heat Med. Boiler 494777 6167326 566 6 0.38 33 728 0 0.01 0 0 0 Leismer Stn 4 Wauk L5790 GL 496406 6169752 555 10 0.50 32 773 0 0.04 0.1 0 0 Leismer Stn 8 Wauk L5790 GL 511453 6174214 571 10 0.50 32 773 0 0.04 0.1 0 0

Cat G3516TA 491392 6198887 645 10 0.50 35 773 0 0.04 0.11 0 0 Pony Creek Sweet Cat G3516TA 491392 6198887 645 10 0.50 35 773 0 0.04 0.11 0 0

W. Surmont 06-09 Cat G3406TA 497517 6216281 736 10 0.50 7 773 0 0.09 0.02 0 0 W. Surmont 06-27 Cat G3306TA 489408 6221146 744 10 0.50 7 773 0 0.09 0.02 0 0

Wauk. L7042GSI 486562 6218730 739 10 0.50 40 773 0 0.3 0.13 0 0 Wauk. L7042GSI 486562 6218730 739 10 0.50 40 773 0 0.3 0.13 0 0 Wauk. L7042GSI 486562 6218730 739 10 0.50 40 773 0 0.3 0.13 0 0

Devon ARL (cont)

W. Surmont Sweet

Wauk. L7042GSI 486562 6218730 739 10 0.50 40 773 0 0.3 0.13 0 0 Superior 2408G 526843 6099985 677 9 0.41 31 632 0 0.03 0.13 0 0 Superior 2412G 526855 6099971 677 9 0.51 30 632 0 0.05 0.19 0.01 0 Superior 2408G 526828 6099952 678 9 0.41 31 632 0 0.03 0.13 0 0 Superior 2412G 526804 6099934 678 9 0.51 30 632 0 0.05 0.19 0.01 0 Superior 2408G 526816 6099943 678 9 0.41 31 632 0 0.03 0.13 0 0 Superior 2408G 526867 6099979 677 9 0.41 31 632 0 0.03 0.13 0 0 Superior 2408G 526841 6099959 678 9 0.41 31 632 0 0.03 0.13 0 0

EnCana

Caribou North Compressor Station

Superior 2408G 526790 6099922 677 9 0.41 31 632 0 0.03 0.13 0 0


December 2009

Page B2-67

Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diamete

r (m)

Exit Velocity

(m/s)

Exit Temp

(K) SO2 (t/d)

NOx (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

CAT G3408 526774 6099932 678 7 0.15 40 763 0 0.21 0.02 0 0 Superior 2406G 526855 6099995 677 7 0.31 10 632 0 0.03 0.1 0 0 CAT 3612 TAW 526881 6099989 677 6 0.61 36 728 0 0.06 0.2 0.01 0 CAT 3612 TAW 526866 6100006 677 6 0.61 36 728 0 0.06 0.2 0.01 0 CAT G3606 526874 6099915 677 6 0.61 36 728 0 0.06 0.1 0 0 CAT G3606 526891 6099927 678 6 0.61 36 728 0 0.06 0.2 0 0 CAT G3608 526887 6099902 677 9 0.51 35 728 0 0.04 0.13 0 0 CAT G3608 526901 6099915 677 9 0.51 35 728 0 0.04 0.13 0 0 Wauk L7042 GSI 524250 6089030 701 11 0.36 35 1400 0 0.07 0.12 0 0 CAT G3612 TAW 524275 6089050 699 7 0.61 36 508 0 0.06 0.2 0.01 0 Wauk L7044 GSI 524300 6089040 698 5 0.36 38 895 0 0.04 0.13 0 0 CAT G3408 524300 6089030 697 5 0.20 18 740 0 0.02 0.03 0 0 Superior 2408G 524275 6089020 699 9 0.41 34 630 0 0.03 0.13 0 0 Superior 2412G 524250 6089040 701 9 0.51 33 630 0 0.05 0.19 0.01 0 European Gas Tornado 524250 6089020 700 12 1.52 32 733 0 0.35 0.68 0 0 Superior 2408G 524250 6089050 701 9 0.41 34 630 0 0.03 0.13 0 0

Utilities 524275 6089030 699 6 0.41 4 672 0 0.01 0 0 0 Compressor Engine 506695 6128893 701 10 0.50 7 773 0 0.11 0.02 0 0 Compressor Engine 508322 6129299 680 10 0.50 7 773 0 0.11 0.02 0 0 Compressor Station Compressor Engine 411786 6343518 561 10 0.50 9 773 0 0.26 0.03 0 0 Compressor Engine 512802 6127692 702 10 0.50 20 773 0 0.43 0.06 0 0 CAT G3516 TA 512802 6127692 702 10 0.50 41 773 0 0.06 0.13 0 0 Solar Saturn CSI-SB 512802 6127692 702 10 0.50 36 773 0 0.03 0.12 0 0 Solar Saturn CSI-SB 512802 6127692 702 10 0.50 36 773 0 0.03 0.12 0 0 Superior 12SGTB-825 512802 6127692 702 10 0.50 64 773 0 0.05 0.21 0 0 Superior 12SGTB-825 512802 6127692 702 10 0.50 64 773 0 0.05 0.21 0 0 Superior 12SGTB-825 512802 6127692 702 10 0.50 64 773 0 0.05 0.21 0 0 Superior 8GTL-825 512802 6127692 702 10 0.50 35 773 0 0.11 0.11 0 0 Wauk F2895 G 512802 6127692 702 10 0.50 20 773 0 0.1 0.06 0 0 Superior 8GTL-825 512802 6127692 702 10 0.50 35 773 0 0.11 0.11 0 0 Superior 2408 512802 6127692 702 10 0.50 51 773 0 0.04 0.16 0 0

N. Primrose Comp.

CAT G3516 TA 512802 6127692 702 10 0.50 41 773 0 0.06 0.13 0 0 Superior 12GT-825 448366 6079601 599 11 0.31 36 862 0 0.41 0.12 0 0 Tweedie Sweet Comp. Wauk L5108 GU 448366 6079601 599 9 0.20 52 862 0 0.23 0.06 0 0

EnCana (cont)

Compressor Compressor 411786 6343518 562 10 0.50 9 773 0 0.26 0.03 0 0


December 2009

Page B2-68

Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diamete

r (m)

Exit Velocity

(m/s)

Exit Temp

(K) SO2 (t/d)

NOx (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Compressor 448802 6217386 733 10 0.50 38 773 0 0.06 0.12 0 0 Compressor Station Compressor 433820 6220022 584 10 0.50 20 773 0 0.12 0.06 0 0 Wauk F3521 GL 401360 6029415 692 10 0.50 20 773 0 0.02 0.06 0 0

Husky Figure Lake Sweet

Wauk F3521 GSI 401360 6029415 692 10 0.50 20 773 0 0.15 0.06 0 0 Wauk L7042 GSI 447588 6083650 601 10 0.50 35 773 0 0.48 0.11 0 0 ICG Resources Tweedie Sweet Comp Wauk L7042 GSI 447588 6083650 601 10 0.50 35 773 0 0.48 0.11 0 0

Ish Energy Comp. Station Compressor Engine 485989 6143073 673 10 0.50 17 773 0 0.27 0.05 0 0 Compressor 491392 6198887 645 10 0.50 38 773 0 0.17 0.12 0 0 Compressor 486562 6218730 739 10 0.50 38 773 0 0.16 0.12 0 0 Compressor 487543 6235738 757 10 0.50 6 773 0 0.11 0.02 0 0

Northstar Compressor Station

Compressor 486562 6218730 739 10 0.50 38 773 0 0.24 0.12 0 0 Solar Saturn T1302 414519 5995172 602 11 2.65 54 752 0 0.04 0.13 0 0 CAT G3408 414519 5995172 602 3 0.20 43 790 0 0.11 0.05 0 0 Solar Saturn T1302 414519 5995172 602 11 2.65 54 752 0 0.04 0.13 0 0 Solar Saturn T1302 414519 5995172 602 11 2.65 54 752 0 0.04 0.13 0 0 Solar Mars T12600 414519 5995172 602 11 2.65 54 752 0 0.64 1.27 0.01 0 Rolls Royce Avon 1535E-161G

414519 5995172 602 16 2.96 23 714 0 0.56 1.85 0.01 0

CAT G3412 414519 5995172 602 7 0.20 27 823 0 0.15 0.07 0 0 Raypack Thermonics 3690 WTD

414519 5995172 602 7 0.74 2 473 0 0.01 0 0 0

NOVA Gas Transmission

Smoky Lake Sweet Gas Compressor Station

Saskatoon Boiler FWG70 414519 5995172 602 7 0.33 2 473 0 0.01 0 0 0 Compressor 477480 6189226 682 10 0.50 35 773 0 0.35 0.11 0 0 Compressor 477480 6189226 682 10 0.50 51 773 0 0.2 0.16 0.01 0 Compressor 471359 6190475 674 10 0.50 48 773 0 0.06 0.15 0 0 Compressor 477974 6205816 699 10 0.50 62 773 0 0.37 0.2 0.01 0 Compressor 467424 6210328 703 10 0.50 10 773 0 0.15 0.03 0 0 Compressor 470268 6209906 703 10 0.50 7 773 0 0.12 0.02 0 0 Compressor 472762 6218386 714 10 0.50 13 773 0 0.19 0.04 0 0

Paramount Compressor Station

Compressor 473593 6221618 717 10 0.50 13 773 0 0.19 0.04 0 0 Wauk L7042 GSI 507406 5997602 595 11 0.30 21 928 0 0.48 0.01 0 0 Seagull Energy

Canada Kehiwin Sweet Comp. Dehy 507406 5997602 595 7 0.18 1 503 0 0.11 0 0 0


December 2009

Page B2-69

Point Sources


UTM N (m)

Elevation (masl)

Stack Height

(m)

Stack Diamete

r (m)

Exit Velocity

(m/s)

Exit Temp

(K) SO2 (t/d)

NOx (t/d)

CO (t/d)

VOC (t/d)

PM2.5 (t/d)

Wauk L7042 GU 507406 5997602 595 7 0.18 1 503 0 0.32 0.08 0 0 Wauk L7042 GU 507406 5997602 595 7 0.18 1 503 0 0.32 0.08 0 0 Portage Sweet Comp. CAT G3408 507406 5997602 595 7 0.18 1 503 0 0.17 0.04 0 0 Wauk L7042 GU 507406 5997602 595 7 0.18 1 503 0 0.3 0.07 0 0 Wauk L7042 GU 507406 5997602 595 7 0.18 1 503 0 0.3 0.07 0 0 Wauk L7042 GU 507406 5997602 595 7 0.18 1 503 0 0.3 0.07 0 0 Superior 8G-825 507406 5997602 595 7 0.18 1 503 0 0.3 0.07 0 0

Suncor Energy Inc.

Tweedie Sweet Comp.

Superior 8G-825 507406 5997602 595 7 0.18 1 503 0 0.3 0.07 0 0 Superior 8G-825 421997 6002314 673 8 0.20 20 643 0 0.28 0.08 0 0 Bellis 2 Sweet Comp. Superior 8G-825 421997 6002314 673 8 0.20 20 643 0 0.28 0.08 0 0 Superior 8G-825 427745 6005454 680 18 0.27 37 726 0 0.28 0.08 0 0 Superior 8G-825 427745 6005454 680 18 0.27 37 726 0 0.28 0.08 0 0 Bellis Non-Unit Sweet Comp. Superior 8G-825 427745 6005454 680 18 0.27 37 726 0 0.28 0.08 0 0 Superior 8GTL-825 420261 6155353 841 10 0.50 35 773 0 0.4 0.11 0 0 CAT G3512 420261 6155353 841 10 0.50 26 773 0 0.04 0.08 0 0 Lyle Lake Sweet Comp. Superior 8GT-825 420261 6155353 841 10 0.50 35 773 0 0.44 0.11 0 0 Compressor Engine 465471 6103472 646 10 0.50 4 773 0 0.17 0.01 0 0 Compressor Engine 424694 6140860 705 10 0.50 10 773 0 0.01 0.03 0 0 Compressor Station Compressor Engine 420951 6159939 706 10 0.50 5 773 0 0 0.02 0 0 Superior 8GT-825 409422 6118341 598 8 0.31 41 705 0 0.44 0.11 0 0 Wandering River 1 Sweet

Comp Superior 8GT-825 409422 6118341 598 8 0.31 41 705 0 0.44 0.11 0 0 Superior 8GTL-825 410775 6144224 650 8 0.31 41 727 0 0.44 0.11 0 0 Superior 8GTLE 410775 6144224 650 9 0.31 46 693 0 0.05 0.11 0 0 Wandering River 2 Sweet

Comp Centaco Reboiler 410775 6144224 650 5 0.25 39 553 0 0 0 0 0 Superior 8GTL-825 427489 6125290 608 10 0.50 35 773 0 0.12 0.11 0 0 Wauk L3711 427489 6125290 608 10 0.50 11 773 0 0.18 0.04 0 0

Talisman Energy Inc.

Wandering River Sweet Comp

Wauk L3711 427489 6125290 608 10 0.50 11 773 0 0.18 0.04 0 0 Wauk L7042 GSI 518199 6166002 570 23 0.30 46 880 0 0.64 0.15 0 0 Wauk L7042 GSI 518199 6166002 570 15 0.30 43 874 0 0.53 0.13 0 0 CAT G3306 NA 518199 6166002 570 3 0.10 47 839 0 0.05 0.01 0 0

Transwest Energy Winefred South Comp.

CAT G3306 NA 518199 6166002 570 3 0.10 47 839 0 0.05 0.01 0 0 Chard Sweet Comp. Compressor Engine 442716 6101653 592 10 0.50 26 773 0 0.29 0.08 0 0

Compressor Engine 442716 6101653 592 10 0.50 38 773 0 0.33 0.12 0 0 Compressor Engine 456033 6101653 601 10 0.50 13 773 0 0.18 0.04 0 0

Viking Energy Viking Comp.

Compressor Engine 451854 6101653 663 10 0.50 40 773 0 0.36 0.13 0 0 Total Gas Plant Emissions for Baseline, Project and Planned Development Scenarios 0.00 43.98 23.03 0.10 0.00


December 2009

Page B2-70

5.0 COMMUNITIES AND HIGHWAYS

The emissions from communities and highways located within the AQRSA are included in each of the emission scenarios. Tables B2-37 and B2-38 present a summary of the emission data.

Table B2-37: Summary of Community and Highway Emissions Included in the Baseline and Project Scenarios

Source SO2 (t/d)

NOX (t/d)

CO (t/d)

PM2.5 (t/d)

Anzac 0.003 0.024 0.114 0.02 Fort McKay 0.002 0.016 0.077 0.013 Fort McMurray 0.287 2.07 9.913 1.711 Janvier/Chard 0.003 0.02 0.096 0.017 Fort Chipewyan 0.005 0.033 0.159 0.028 HWY 63a 0.05 1.653 10.78 0.54 HWY 63b 0.02 0.827 5.48 0.25 HWY 69 0.004 0.07 0.55 0.02 HWY 881 0.019 0.33 1.43 0.15 Total 0.39 5.04 28.60 2.75

Table B2-38: Summary of Community and Highway Emissions Included in the Planned Development Scenario

Source SO2 (t/d)

NOX (t/d)

CO (t/d)

PM2.5 (t/d)

Anzac 0.007 0.050 0.239 0.041 Fort McKay 0.005 0.034 0.162 0.028 Fort McMurray 0.558 4.024 19.27 3.328 Janvier/Chard 0.006 0.042 0.202 0.035 Fort Chipewyan 0.01 0.07 0.334 0.058 HWY 63a 0.105 3.461 22.571 1.131 HWY 63b 0.042 1.732 11.474 0.523 HWY 69 0.008 0.147 1.152 0.042 HWY 881 0.040 0.691 2.994 0.314 Total 0.78 10.25 58.40 5.50


December 2009

Page B2-71


Albian Sands Energy Inc. (Albian Sands). 2005. Application for Approval of the Muskeg River Mine Expansion Project. Air Section prepared by Golder Associates Ltd. Calgary, AB.

Birch Mountain Resources Ltd. (Birch Mountain). 2006. Hammerstone Project Application and Environmental Impact Assessment. Prepared by AMEC E&E. Calgary, AB.

Canadian Natural Resources Ltd. (CNRL). 2003. Horizon Oil Sands Project Update. Prepared by Golder Associates Ltd. Calgary, AB.

Canadian Natural Resources Ltd. (CNRL). 2007. Kirby In-Situ Oil Sands Project Environmental Impact Assessment. Prepared by Golder Associates Ltd. Calgary, AB.

ConocoPhilips Surmont (ConocoPhilips). 2006. ConocoPhilips Surmont Phase 2 Update. Air Quality Section Prepared by AMEC E&E. Calgary, AB.

Deer Creek Energy Limited (Deer Creek). 2007. Joslyn North Mine Project Updated Air Quality Assessment. Air Quality Section Prepared by AMEC E&E. Calgary, AB.

Devon Energy Corp. (Devon). 2006. Application for Approval of the Devon Jackfish 2 Project. Prepared by AMEC E&E. Calgary, AB

EnCana Corp. (EnCana). 2007. Borealis In-Situ Project Application & Environmental Impact Assessment. Air Quality Section Prepared by AMEC E&E. Calgary, AB.

Great Divide Oil Corporation (Great Divide). 2007. Air Quality Assessment of the Algar SAGD Project. Prepared by AMEC E&E. Calgary, AB.

Imperial Oil Resources. 2005. Kearl Oil Sands Project – Mine Development. Prepared by Golder Associates Ltd. Calgary, AB.

OPTI Nexen (OPTI). 2006. Long Lake South Project Application. Air Quality Section Prepared by RWDI. Calgary, AB.

Petro-Canada. 2005. Application to Alberta Energy and Utilities Board and Alberta Environment for the Approval of MacKay River Expansion. Prepared by Jacques Whitford Limited. Calgary, AB.

Value Creation Inc. 2006. High Creek SAGD Project Air Quality Assessment, Prepared by AMEC E&E. Calgary, AB.

Appendix B3

Air Quality and Meteorological Observations in the Regional Study Area


December 2009


APPENDIX B3: AIR QUALITY AND METEOROLOGICAL OBSERVATIONS IN THE REGIONAL STUDY AREA

TABLE OF CONTENTS

PAGE

1.0 INTRODUCTION......................................................................................................... B3-1 1.1 Objectives........................................................................................................ B3-1 1.2 Air Quality, Meteorology and Climate Data Sources ....................................... B3-1 1.3 Continuous Air Quality Monitoring Results ...................................................... B3-3

1.3.1 Sulphur Dioxide............................................................................... B3-3 1.3.2 Nitrogen Dioxide ............................................................................. B3-4 1.3.3 Particulate Matter Smaller than 2.5 µm – PM2.5 .............................. B3-4 1.3.4 Carbon Monoxide............................................................................ B3-5 1.3.5 Ozone ............................................................................................. B3-7 1.3.6 Hydrogen Sulphide ......................................................................... B3-9 1.3.7 Acid Deposition ............................................................................. B3-10 1.3.8 Nitrogen Deposition ...................................................................... B3-15 1.3.9 Volatile Organic Compounds (VOCs) and Polyaromatic

Hydrocarbons (PAHs) ................................................................... B3-16 1.4 Meteorology and Climatology measurements ............................................... B3-24

1.4.1 Winds ............................................................................................ B3-24 1.4.2 Ambient Temperature ................................................................... B3-25 1.4.3 Atmospheric Stability .................................................................... B3-25 1.4.4 Mixing Height ................................................................................ B3-26 1.4.5 Precipitation .................................................................................. B3-27 1.4.6 General Climate ............................................................................ B3-27 1.4.7 Climate Summary ......................................................................... B3-27



December 2009



LIST OF TABLES

Table B3-1: Summary of Continuous Ambient Air Quality Parameters Measured by the Wood Buffalo Environmental Association.................................................. B3-2

Table B3-2: Summary of the Alberta and Canadian Ambient Air Quality Objectives......... B3-2 Table B3-3: Summary of SO2 Concentrations (µg/m3) During 2004-2008 at WBEA

Stations ........................................................................................................... B3-3 Table B3-4: Summary of NO2 Concentrations (µg/m3) During 2004-2008 at WBEA

Stations ........................................................................................................... B3-4 Table B3-5: Summary of PM2.5 Concentrations (µg/m3) during 2004-2008 at WBEA

Stations ........................................................................................................... B3-5 Table B3-6: Observed CO Concentrations at Athabasca Valley Station, 2004-2008.......... B3-6 Table B3-7: Summary of O3 Concentrations (µg/m3) during 2004-2008 at WBEA

Stations ........................................................................................................... B3-9 Table B3-8: Summary of H2S Concentrations (µg/m3) during 2001-2006 at WBEA

Stations ......................................................................................................... B3-10 Table B3-9: Period Average Sulphur Dioxide Measurements and Sulphate Dry

Deposition Estimates..................................................................................... B3-11 Table B3-10: Period Average Nitrogen Dioxide and Nitrate Dry Deposition Estimates ...... B3-11 Table B3-11: Wet Deposition at Fort McKay, 2006-2008.................................................... B3-12 Table B3-12: Total Annual Wet Deposition Rates of Ions in Precipitation .......................... B3-13 Table B3-13: Wet Deposition Rates of Anions, 2006-2008................................................. B3-14 Table B3-14: Wet Deposition Rates of Cations, 2006-2008 ............................................... B3-14 Table B3-15: Average PAI Estimates from Measurements; 2002-2004 for Passive and

2004-2008 for Continuous Measurements. ................................................... B3-15 Table B3-16: Nitrogen Deposition Estimates ...................................................................... B3-15 Table B3-17: Summary of Critical Loads for Nitrogen Deposition (kg/ha/y) to

Freshwater and Terrestrial Ecosystems in Europe (WHO 2000) .................. B3-16 Table B3-18: 24-h VOC Concentrations in Fort McKay, 2002 to 2003 (μg/m3) .................. B3-17 Table B3-19: 24-h VOC Concentrations at Athabasca Valley, 2002 to 2003 (μg/m3)......... B3-18 Table B3-20: 24-h VOC Concentrations at Patricia McInnes, 2002 to 2003 (μg/m3) .......... B3-19 Table B3-21: 24-h VOC Concentrations at Millenium, 2002 to 2003 (μg/m3) ..................... B3-20 Table B3-22: 24-h VOC Concentrations at Syncrude UE1, 2002 to 2003 (μg/m3) ............. B3-21 Table B3-22: 24-h PAH Concentration Statistics at Fort McKay, 2004............................... B3-22 Table B3-24: 24-h PAH concentration statistics at Patricia McInnes, 2004........................ B3-22 Table B3-25: 24-h PAH Concentration Statistics at Athabasca Valley, 2004 ..................... B3-23 Table B3-26: Ambient Temperatures Measured at Fort Chipewyan, Fort McMurray

Airport and Mannix (75 m level) in 2002........................................................ B3-25 Table B3-27: Average Precipitation at the Project Pseudo-Station, 1980-2006 ................ B3-27


December 2009


LIST OF FIGURES

Figure B3-1: Frequency of Exceedence of AAAQOs for 1 hour and 24 hour SO2 Concentrations at WBEA Stations, 2001-2006

Figure B3-2: Seasonal Variation in SO2 Concentration at WBEA Stations 2004-2008 Figure B3-3: Diurnal Variation in SO2 Concentration at WBEA Stations 2004-2008 Figure B3-4: Seasonal Variation of NO2 for WBEA Stations 2004-2008 Figure B3-5: Diurnal Variation of NO2 Concentration for WBEA Stations 2004-2008 Figure B3-6: Seasonal Variation of PM2.5 Concentrations for WBEA Stations 2004-

2008 Figure B3-7: Diurnal Variation in PM2.5 Concentration for WBEA Stations 2004-2008 Figure B3-8: Seasonal (Top) and Diurnal (Bottom) Variation in 1-h Average CO

Concentration at Athabasca Valley, 2004-2008 Figure B3-9: Seasonal Variation of O3 Concentrations for WBEA Stations 2004-2008 Figure B3-10: Diurnal Variation in O3 Concentrations for WBEA Stations 2004-2008 Figure B3-11: Monthly Variation of H2S Concentrations for WBEA Stations 2004-2008 Figure B3-12: Diurnal Variation in H2S Concentrations for WBEA Stations 2004-2008 Figure B3-13: Wind Roses for 2002-2006 at the Fort McMurray Airport Figure B3-14: Seasonal Wind Roses for 2002-2006 at the Fort McMurray Airport Figure B3-15: Six-hour Wind Roses for 2002-2006 the Fort McMurray Airport Figure B3-16: Wind Rose for 2002-2006 at the Project Pseudo-Station Figure B3-17: Monthly Wind Roses for 2002-2006 at the Project Pseudo-Station Figure B3-18: Six-hour Wind Roses for 2002-2006 at the Project Pseudo-Station Figure B3-19: Annual Wind Roses for 2002-2006 at the Project Pseudo-Station Figure B3-19: Annual Wind Roses for 2002-2006 at the Project Pseudo-Station Figure B3-20: Wind Roses at other locations in the study area for 2002-2006 Figure B3-21: Diurnal (Top) and Monthly (Bottom) Variation in Hourly Temperature at

the Project Pseudo-Station Figure B3-22: Diurnal (Top) and Monthly (Bottom) Variation in Hourly Temperature at

the Fort McMurray Airport Figure B3-23: Diurnal (Top) and Monthly (Bottom) Variation in Hourly Temperature at

Fort Chipewyan Figure B3-25: Diurnal Variation in Mixing Heights at the Project Pseudo-Station Figure B3-26: Average Monthly Rainfall, Snowfall and Total Precipitation Values for

Fort McMurray Airport from 1980 through to 2008 Figure B3-27: Annual Relative Humidity at the Project Pseudo-Station S:\Project Ce\Ce03745\EIA\Vol 3\app b3-Volume 3-final EIA-ce03745-dec09-dr.doc


December 2009

Page B3-1

APPENDIX B3: AIR QUALITY AND METEOROLOGICAL OBSERVATIONS IN THE REGIONAL STUDY AREA

1.0 INTRODUCTION

1.1 Objectives

The following section provides a summary of baseline information on air quality for the project. This information forms the basis of comparison for the environmental impact assessment and cumulative environmental impact assessment to be completed as part of the project approval process. The baseline information is derived from representative monitoring programs in the region. The project will result in direct emissions to the atmosphere from fossil fuel combustion sources, as well as fugitive emissions (from a small amount of vehicle traffic and potentially from equipment leaks). While primary combustion products are CO2 and H2O, oxides of NOx, particulate matter with diameter less than 2.5 µm (PM2.5), CO and VOCs are also produced. In addition, if the fuel contains sulphur compounds (such as H2S), then trace amounts of SO2 emissions can occur. At sufficiently high concentrations, these air emissions can have direct and indirect effects on humans, animals, vegetation, soil and water. The information presented in this air quality baseline section reflects the current understanding of baseline conditions and is based on information available as of the end of 2008.

1.2 Air Quality, Meteorology and Climate Data Sources

The data consisted of hourly observations of meteorology and ambient air quality. This information was quality-checked and has been summarized in this report. The following are the major sources of air quality information used in the preparation of this document:

• The current regional data for air quality are available from CASA. Table B3-1 provides the locations of the air quality stations and the type of measurements made at each station. For the current study, five years of data from thirteen stations operated by WBEA has been assessed. This information was obtained from the CASA data warehouse (CASA 2009).

• The current regional data for meteorology are available from CASA. For the current study, meteorological data from the various air quality stations were obtained from the Environment Canada Website (EC 2009).

• The full meteorology data recorded at Fort McMurray airport, Fort Chipewyan, Patricia McInnes, Fort McKay and Mannix were used for modelling. Precipitation data, which is required for deposition modelling, was obtained from Environment Canada.

• MM5 model output data were used as a first guess wind field for dispersion modelling. Model output for 2002-2006 was obtained from AENV.

• The air quality observations can be compared to Alberta’s Ambient Air Quality Objectives and Guidelines (AENV 2009), which summarizes AENV limits for selected contaminants in Table B3-2.


December 2009

Page B3-2

Table B3-1: Summary of Continuous Ambient Air Quality Parameters Measured by the Wood Buffalo Environmental Association

Parameter

Alb

ian

Min

e

Anz

ac

Ath

abas

ca

Valle

y

Buf

falo

Vi

ewpo

int

Fort

C

hipe

wya

n

Fort

McK

ay

Hor

izon

Low

er

Cam

p

Man

nix

Mild

red

Lake

Mill

enni

um

Patr

icia

M

cInn

es

Sync

rude

U

E1

Wind speed √ √ √ √ √ √ √ √ √ √ √ √ √ Wind direction √ √ √ √ √ √ √ √ √ √ √ √ √ Air temperature √ √ √ √ √ √ √ √ √ √ √ √ √ Air temperature at 10 m √ √ Relative humidity √ √ √ √ Barometric Pressure Carbon Monoxide √ Ground-level ozone (O3) √ √ √ √ √ √ Total Hydrocarbons (THC) √ √ √ √ √ √ √ √ √ √ √ √ Hydrogen Sulphide (H2S) √ √ √ √ √ √ √ √ √ Nitrogen Oxides (NOx) √ √ √ √ √ √ √ √ √ Nitrogen Oxide (NO) √ √ √ √ √ √ √ √ √ Nitrogen dioxide (NO2) √ √ √ √ √ √ √ √ √ Particulates (PM2.5) √ √ √ √ √ √ √ √ √ Sulphur dioxide (SO2) √ √ √ √ √ √ √ √ √ √ √ √ √ Total Reduced Sulphur (TRS) √ √ √ √ √ √ √ √

Table B3-2: Summary of the Alberta and Canadian

Ambient Air Quality Objectives Alberta Objectives Canadian Objectives1

Period (µg/m3) (ppb)

Alberta Guideline

(µg/m3) Desirable

(µg/m3) Acceptable

(µg/m3) Tolerable (µg/m3)

CWS (µg/m3)

Annual 30 11 - 30 60 – – 24-h 150 57 - 150 300 800 –

SO2

1-h 450 170 - 450 900 – – Annual 60 32 - 60 100 – –

24-h 200 106 - – 200 300 – NO2

1-h 400 210 - – 400 1,000 – 8-h 6,000 5,000 - 6,000 15,000 20,000 – CO 1-h 15,000 13,000 - 15,000 35,000 – –

24-h – – - – – – 30 PM2.5 1-h – – 80 - - - - 1-h 14 10 - – – – – H2S

24-h 4 3 - - - - - Benzene 1-h 30 9 - - - - –

1 Maximum desirable: long-term goal for air quality, basis for an antidegradation policy, and supports continuing development of control technology. Maximum acceptable: provides adequate protection against adverse effects on soil, water, vegetation, materials, animals, visibility, and personal comfort and well being. Maximum tolerable: concentration of an air contaminant that requires abatement without delay to avoid air quality deterioration to a level that endangers lifestyle or to level that poses a substantial risk to public health.


December 2009

Page B3-3

1.3 Continuous Air Quality Monitoring Results

1.3.1 Sulphur Dioxide

Table B3-3 summarizes measured SO2 concentrations at selected stations during the 2004 to 2008 observational period. Exceedences of the AAAQO at individual WBEA monitoring stations are illustrated in Figure B3-1. Seasonal fluctuations in SO2 concentration based on 1-h measurements are shown in Figure B3-2, while diurnal trends are presented in Figure B3-3. Ambient SO2 is measured at the following WBEA air quality stations: Albian Mine, Anzac, Athabasca Valley, Buffalo Viewpoint, Fort Chipewyan, Fort McKay, Horizon, Lower Camp, Mannix, Mildred Lake, Millennium, Patricia McInnes and Syncrude UE1. The results indicate that:

• There were 37 exceedences of the AAAQO. These occurred at Buffalo Viewpoint, Fort McKay, Lower Camp, Mannix, Mildred Lake, Millennium and Syncrude UE1. The Mannix station showed the largest number of hourly and daily exceedences of the SO2 AAAQOs of all stations in the WBEA.

• The highest 1-h maximum SO2 concentration (1,847 µg/m3) was observed at the Mannix station. Other highest values included: Buffalo Viewpoint (658 µg/m3), Fort McKay (482 µg/m3), Lower Camp (587 µg/m3), Mildred Lake (626 µg/m3), Millennium (555 µg/m3) and Syncrude UE1 (765 µg/m3).

• All the 1-h 99.9th and 95th percentile values were below the AAAQO (450 µg/m3). See Table B3-3.

• The highest daily SO2 concentration (309 µg/m3) was observed at Mannix which exceeded the AENV 24-h objective (150 µg/m3).

• The period average SO2 concentrations recorded at the 12 stations ranged from 0.8 µg/m3 to 8.0 µg/m3, which are all below the annual AAAQO of 30 µg/m3.

• SO2 concentrations showed characteristic diurnal variations at all stations with peak concentrations in the afternoon and minimums after midnight.

• The Fort Chipewyan station had many hourly SO2 observations below the detection threshold.

Table B3-3: Summary of SO2 Concentrations (µg/m3)

During 2004-2008 at WBEA Stations

Alb

ian

Min

e

Anz

ac1

Ath

abas

ca

Valle

y

Buf

falo

Vi

ewpo

int

Fort

C

hipe

wya

n2

Fort

McK

ay

Hor

izon

3

Low

er

Cam

p

Man

nix

Mild

red

Lake

Mill

enni

um

Patr

icia

M

cInn

es

Sync

rude

U

E1

AA

AQ

O

1-h Maximum 488 97 202 658 52 482 217 587 1847 626 555 396 765 450 1-h 99.9th percentile 149 52 86 174 37 162 128 223 337 236 186 88 170 - 1-h 95th percentile 18 5 10 13 5 16 13 26 37 29 18 13 16 - 24-h Maximum 85 28 50 70 27 63 37 96 309 86 83 51 59 150 24-h 95th percentile 17 4 10 15 4 17 3 20 30 24 19 10 16 - Period Average 4 1 2 3 1 4 3 6 8 6 5 3 3 30 1 Anzac observational period was from January 2004 to December 2006. 2 > 80% of the SO2 concentrations below the detection limit. 3 Horizon observational period was from January 2004 to December 2004.


December 2009

Page B3-4

1.3.2 Nitrogen Dioxide

Table B3-4 summarizes the measured NO2 concentrations at selected stations for the 2004 to 2008 observational period. Ambient NO2 is measured at the following stations: Albian Mine, Anzac, Athabasca Valley, Fort Chipewyan, Fort McKay, Horizon, Millennium, Patricia McInnes and Syncrude UE1. The results indicate that:

• There was one exceedence of the hourly NO2 at the Albian Mine site (427 µg/m3). No other readings were within 94% of the AAAQO (400 µg/m3)

• The highest 99.9th and 95th percentile hourly average NO2 values were 154 µg/m3 (Albian Mine) and 70 µg/m3 (Millenium).

• There were no exceedences of the daily AAAQO for NO2 (200 µg/m3) at any of the seven stations.

• The average NO2 concentrations over the six-year period ranged from 2 to 27 µg/m3. All annual average values were below the AAAQO of 60 µg/m3.

• NO2 concentrations at all WBEA stations are at their lowest during the summer months and highest in the winter as shown in Figure B3-4.

• Diurnal variation of NO2 at all stations showed bimodal distributions typically with peaks in the mornings at around 07:00 hours and in the evenings around 19:00 hours as shown in Figure B3-5.

Table B3-4: Summary of NO2 Concentrations (µg/m3)

During 2004-2008 at WBEA Stations

Alb

ian

Min

e

Anz

ac1

Ath

abas

ca

Valle

y

Fort

C

hipe

wya

n

Fort

McK

ay

Hor

izon

2

Mill

enni

um

Patr

icia

M

cInn

es

Sync

rude

U

E1*

AA

AQ

O

1-h Maximum 427 158 344 58 100 94 316 85 326 400 1-h 99.9th percentile 154 66 100 43 73 81 119 68 68 - 1-h 95th percentile 60 21 51 9 43 43 70 36 38 - 24-h Maximum 156 36 78 41 64 57 105 44 56 200 24-h 95th percentile 47 14 40 7 35 16 57 27 29 - Period Average 20 6 18 2 11 11 27 11 10 60 1 Anzac observational period was from January 2004 to December 2006. 2 Horizon observational period was from January 2004 to December 2004.

1.3.3 Particulate Matter Smaller than 2.5 µm – PM2.5

Suspended particles less than 2.5 microns in diameter (PM2.5) are produced by a variety of sources including forest fires, agricultural activities, road dust, dust from industrial activity including mines, vehicle exhaust emissions and exhaust from industrial combustion processes. Forest fires as a source have been identified by Connor Pacific (2000) and Suncor (2000) in their respective reviews of 1998 emissions data from the oil sands region. Small particles like PM2.5, such as those produced by fires, can be transported for long distances causing haze and


December 2009

Page B3-5

reduced visibility, and they can be suspended in the air for an indefinite period of time. These fine particulates are of concern because they can be inhaled and are small enough to enter the lower respiratory tract including the alveoli of the lungs. Table B3-5 summarizes PM2.5 concentrations measured at the Albian Mine, Athabasca Valley, Fort McKay, Fort Chipewyan, Millennium, Patricia McInnes and Syncrude UE1 stations. Results indicate:

• The 98th percentile hourly PM2.5 values measured at all seven stations were below the AAAQO (80 µg/m3).

• The 98th percentile daily PM2.5 values measured at all seven stations were below the CWS (30 µg/m3).

• The maximum hourly concentrations ranged from 99 to 354 µg/m3 for all seven sites. The 24 hour 95th percentile values for all seven monitoring stations ranged between 6 and 14 µg/m3. Averages for the 2004-2008 period ranged from 2 to 7 µg/m3.

• Seasonal fluctuations in PM2.5 levels showed a peak in concentrations from June to August for all WBEA stations as shown in Figure B3-6. This correlates well with seasonal increases in forest fire activity and dry gravel road conditions.

• Diurnal variation in PM2.5 levels is bimodal with minor increases around 7:00 and 19:00 as shown in Figure B3-7.

Table B3-5: Summary of PM2.5 Concentrations (µg/m3)

during 2004-2008 at WBEA Stations

Alb

ian

Min

e

Anz

ac1

Ath

abas

ca

Valle

y

Fort

C

hipe

wya

n

Fort

McK

ay

Hor

izon

2

Mill

enni

um

Patr

icia

M

cInn

es

Sync

rude

U

E1*

AA

AQ

O /

CW

S

1-h Maximum 182 225 226 214 142 99 354 248 157 80

1-h 98th percentile 27 19 21 14 21 23 26 18 19 -

1-h 95th percentile 18 13 14 7 14 17 18 12 13 -

24-h Maximum 46 77 79 96 37 27 58 79 45 -

24-h 98th percentile 19 13 16 12 16 12 19 14 14 30

24-h 95th percentile 13 9 11 6 12 8 14 10 10 -

Period Average 5 5 5 2 4 7 6 4 4 - 1 Anzac observational period was from January 2004 to December 2006. 2 Horizon observational period was from January 2004 to December 2004.

1.3.4 Carbon Monoxide

Table B3-6 summarizes CO concentrations at the Athabasca Valley station in 2004 to 2008. The maximum 1-h concentration was 7 103 µg/m3 (January 2005) compared to an ambient objective of 15 000 µg/m3. Figure B3-8 shows seasonal and diurnal variations in the 1-h average CO concentration. Median values are similar in all months (and at all hours) but maximum values are higher in cold weather. Maximum concentrations are higher in afternoon and evening hours.


December 2009

Page B3-6

Table B3-6: Observed CO Concentrations at Athabasca Valley Station, 2004-2008

1-h (µg/m3) 8-h (µg/m3) 2004 Min 0 14 Median 229 229 Average 244 244 Max 2176 1474 99.9 Percentile 1603 1144 2005 Min 0 0 Median 229 229 Average 256 254 Max 7103 1375 99.9 Percentile 1572 1082 2006 Min 0 0 Median 229 245 Average 269 268 Max 2979 1260 99.9 Percentile 1915 1241 2007 Min 0 0 Median 229 245 Average 261 261 Max 2864 1160 99.9 Percentile 1341 1033 2008 Min 0 0 Median 229 229 Average 237 235 Max 1833 1246 99.9 Percentile 1489 1225 2004-2008 Min 0 0 Median 229 229 Average 254 252 Max 7103 1475 99.9 Percentile 1604 1216


December 2009

Page B3-7

1.3.5 Ozone

1.3.5.1 Ozone Formation

O3 is an important natural constituent of the atmosphere, an oxidizing agent, and its concentration is highly variable. Altshuller (1986) indicated ground level concentrations of O3 can be influenced by:

• downward transport of stratospheric O3; • photochemical formation within a pristine troposphere; and • photochemical formation within a polluted troposphere especially during passage of

warm high pressure systems; and O3 formation within plumes. Ground level O3 concentrations are determined by formation, destruction and transport processes. Lefohn et al. (1990) reported O3 values at relatively pristine locations.

1.3.5.2 Precursors

O3 is not directly emitted into the atmosphere from anthropogenic sources. Formation in the stratosphere and in the lower atmosphere is photochemical and occurs through a complex series of precursor compounds. Primary precursors that may be affected by industrial activity are NOx and VOCs. As discussed in Section 4.2 and summarized in Sandhu (1999), NO emissions are partially converted to NO2. O3 photolysis and reactions with water produce OH-. Reactions of O3 and OH- with NOx and VOCs produce HNO3 and HNO2, peroxyacetyl nitrate (PAN) and nitrates. NO2

photolysis and reactions with O2 produce O3. The presence of various species of VOCs greatly complicates the scenario and it is beyond the scope of this work to illustrate all of the possible reaction pathways.

1.3.5.3 Meteorological Considerations

Ground-level O3 concentrations are influenced by sunlight, temperature, wind speed, mixing, as well as scavenging.

• Solar radiation plays a key role in initiating the photochemical reactions that might lead to O3 formation, and varies with season and latitude. Daylight in the Fort McMurray region ranges from about 6 hours in winter to 18 hours in summer, and the diurnal nature of sunlight is important in understanding the diurnal variation in observed O3 concentrations for the region.

• Ground-level O3 formation is also a function of temperature. Episodes of high temperature have been linked to seasonally high O3 observations (US EPA 1996). This research indicates that O3 concentrations may vary widely at a given temperature but that maximum O3 concentrations typically increase with temperature. Temperature ranges at which O3 formation takes place are typically above 25 to 30°C; however, O3 has been observed to form at lower temperatures in the oil sands area (AMEC 2004).


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• Low wind speed increases O3 formation potential because lower wind speeds lead to reduced ventilation and the build-up of precursor concentrations. High temperatures are typically associated with low wind speeds, greater solar radiation, stagnant circulation and suppressed mixing.

Sandhu (1999) used the term ‘chemical air mass’ to identify a body of air that becomes stagnant over a source region, such as the oil sands, and subsequently takes on the characteristics of the region with respect to temperature, humidity, stability, and the accumulation of O3 and precursors. The chemical air mass in which high O3 values may be observed is likely to be a high pressure area with subsidence, an elevated inversion layer, lack of clouds, low winds and high temperatures.

1.3.5.4 Alberta Observations

O3 and precursor values are summarized in a large number of publications including AMEC (2004), Angle and Sandhu (1986 and 1989), Cheng et al. (1997), Conor Pacific (2000), Fanaki et al. (1979), Leahey and Hansen (1990), Legge and Krupa 1990, Legge et al. (1991), Myrick (1995, 1996a and 1996b), Myrick and Asquin (1992 and 1993), Myrick et al. (1994), Peake and Fong (1990), Peake and Sandhu (1983), Peake et al. (1983, 1985, 1986, 1988a and 1988b), as well as in recent EIAs in the oil sands area. The observations generally indicate:

• elevated stations have higher ground-level concentrations and show little diurnal variation (Angle and Sandhu 1986, Legge and Krupa 1990);

• urban areas generally show maximum values in May and minimum values in November (Myrick and Asqin 1992 and 1993, Myrick 1995, 1996a and 1996b);

• urban areas show much larger diurnal variation in summer than in winter, with the highest values in the afternoon and the lowest values just before sunrise (Angle and Sandhu 1989);

• urban areas are O3 sinks throughout the year and at least one measurement program indicates the sink can extend tens of kilometres downwind of the city (Angle and Sandhu 1989, Leahey and Hansen 1990);

• rural stations show diurnal variations between elevated and urban areas (Angle and Sandhu 1986, Sandhu 1999);

• trajectory analysis of surface observations in Fort McMurray and Fort McKay shows that oil sands sources can be identified upwind of monitoring locations on most days with the highest O3 concentrations (Davies and Fellin 1999); and

• O3 formation occurs in oil sands plumes in late morning and afternoon during summer at distances beyond about 20 km from the source while depletion occurs nearer the source (AMEC 2004; Fanaki et al. 1979).


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Page B3-9

Surface maximum 1-h values are highest in rural areas downwind of industrial facilities and lowest in urban centres and more remote rural areas (AMEC 2004). Ninety-ninth percentile values do not follow the same trend, suggesting conditions leading to the highest values do not occur frequently.

1.3.5.5 WBEA Ozone Observations

Table B3-7 summarizes O3 concentrations measured at the Athabasca Valley, Fort Chipewyan, Fort McKay, Patricia McInnes and Syncrude UE1 stations. Results indicate:

• The 1 hour maximum O3 values at 3 stations exceeded the AENV objective of 160 µg/m3 these stations were Athabasca Valley (171 µg/m3), Fort McKay (165 µg/m3) and Patricia McInnes (161 µg/m3).

• The CWS (CCME 1999) value of 128 μg/m3 (65 ppb), based on the 4th highest (99th percentile) 8-h average O3 concentration, was not exceeded at the five stations. The highest 8-h average concentrations (101 µg/m3) were at the Patricia McInnes and Fort Chipewyan stations.

Table B3-7: Summary of O3 Concentrations (µg/m3)

during 2004-2008 at WBEA Stations

Ath

abas

ca

Valle

y

Fort

C

hipe

wya

n

Fort

McK

ay

Patr

icia

M

cInn

es

Sync

rude

U

E1

AA

AQ

O

1-h Maximum 171 130 159 161 157 160

4th highest 8-h Average 109 107 117 105 111 128

Figures B3-9 and B3-10 present average seasonal and diurnal O3 variations. They indicate:

• Monthly O3 concentrations in the WBEA network have peaks in April at all stations, with monthly medians between 65 and 70 μg/m3. Stratospheric intrusions are more frequent in spring (April to early June) (Singh et al. 1980, Davis and Schuebath 1994) and are likely to be the key source of elevated O3 levels in the oil sands in spring.

• O3 concentrations at all stations peak in mid-afternoon (about 15:00). The lowest concentrations occur in early morning (about 06:00). These ground level O3 trends correlate well with the daily solar maximum which is responsible for initiating the photo-chemical reactions necessary to form O3.

1.3.6 Hydrogen Sulphide

Table B3-8 summarizes hydrogen sulphide H2S observations during the 2004 to 2008 period. Ambient H2S was measured at the following WBEA air quality stations: Buffalo Viewpoint, Lower Camp, Mannix, Mildred Lake, Millenium, Patricia McInnes and Syncrude UE1. The results indicate that maximum measured values were above AAAQOs at all stations. The highest maximum 1-h average hydrogen sulphide concentration of 127 µg/m3 was measured at Mildred


December 2009

Page B3-10

Lake, which is higher than the AAAQO of 14 µg/m3. The maximum daily H2S concentrations were highest at Mannix (20 µg/m3) and Mildred Lake (18 µg/m3) and exceeded the AAAQO of 4 µg/m3. It is expected that observed ambient concentrations for H2S may be influenced by fugitive and upset releases from oil sands operations within the region. There was a high frequency of zero readings in H2S measurements. It is expected the reason is because releases of H2S are infrequent and therefore are measured infrequently at monitoring stations.

Table B3-8: Summary of H2S Concentrations (µg/m3) during 2001-2006 at WBEA Stations

Buf

falo

Vi

ewpo

int

Low

er

Cam

p

Man

nix

Mild

red

La

ke

Mill

eniu

m1

Patr

icia

M

cInn

es2

Sync

rude

U

E13

AA

AQ

O

1-h Maximum 85 102 78 127 17 4 10 14

1-h 95th percentile 1 4 4 6 3 1 1 -

24-h Maximum 17 24 20 24 5 2 3 4

24-h 95th percentile 2 3 4 5 1 0 0 -

Period Average 0.4 1.1 1.2 1.4 0.7 0.2 0.3 -

1 Millenium observational period was from May 2004 to May 2005. 2 Patricia McInnes observational period was from March 2005 to July 2005. 3 Syncrude UE1 observational period was from March 2004 to August 2004.

1.3.7 Acid Deposition

1.3.7.1 Dry Deposition

Table B3-9 summarizes SO2 and SO4-2 deposition during 2004 to 2008 for continuous

measurements at the Athabasca Valley, Fort McKay and Patricia McInnes sites and passive measurements from 2002-2004. Calculations assume a deposition velocity of 0.58 cm/s based on average values in EPCM (2002) consistent with recent EIA’s (EnCana 2007). Co-located concentration measurements and deposition estimates using passive and continuous samples show good agreement overall.


December 2009

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Table B3-9: Period Average Sulphur Dioxide Measurements and Sulphate Dry Deposition Estimates

Location Measurement Type

SO2 Concentration

(µg/m3)

SO2 Deposition (kg/ha/y)

SO4-2

Deposition (kg/ha/y)

SO4-2 Equiv.

Deposition (keq/ha/y)

Fort McKay Passive 2.5 4.8 7 0.15 Patricia McInnes Passive 3.9 7.5 11 0.23 PetroCanada Mackay River Passive 0.5 1.0 1 0.03 Fort McKay Continuous 3.4 6.5 10 0.20 Patricia McInnes Continuous 2.5 4.8 7 0.15 Athabasca Valley Continuous 2.3 4.4 7 0.14 Table B3-10 summarizes NO2 and NO3

- deposition during 2004 to 2008 for continuous measurements and from 2002-2004 for passive measurements. The table is based on both passive and continuous measurements. Calculations assume a deposition velocity of 0.19 cm/s based on average values in EPCM (2002). Average concentrations based on continuous measurements are typically higher than passive concentrations.

Table B3-10: Period Average Nitrogen Dioxide and Nitrate Dry Deposition Estimates

Location Measurement Type

NO2 Concentration

(µg/m3)

NO2 Deposition (kg/ha/y)

NO3-


NO3- Equiv.


Fort McKay Passive 8.0 5.0 7 0.11 Patricia McInnses Passive 8.2 5.1 7 0.11 PetroCanada Mackay River Passive 1.1 0.7 1 0.02 Fort McKay Continuous 10.6 6.6 9 0.14 Patricia McInnes Continuous 9.9 6.2 8 0.13 Athabasca Valley Continuous 17.8 11.1 15 0.24

1.3.7.2 Wet Deposition

Precipitation chemistry measurements are compiled periodically throughout the year at Fort McKay. In 2006 to 2008, 38 samples were available. Wet deposition information from 2006 to 2008 at Fort McKay is provided in Table B3-11 and summarized in Table B3-12.


December 2009

Page B3-12

Table B3-11: Wet Deposition at Fort McKay, 2006-2008

Month CL (kg/ha/mo)

Nitrate (kg/ha/mo)

SO4 (kg/ha/mo)

Phosphate (kg/ha/mo)

Na (kg/ha/mo)

NH4 (kg/ha/mo)

K (kg/ha/mo)

Mg (kg/ha/mo)

Ca (kg/ha/mo) pH

2006 January 0.03 0.04 0.02 0.00 0.02 0.01 0.00 0.01 0.03 6.53 February 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 - March 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 - April 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 - May 0.07 0.10 0.25 0.00 0.04 0.02 0.02 0.04 0.21 6.51 June 0.07 0.26 0.70 0.00 0.04 0.05 0.06 0.04 0.22 5.85 July 0.15 0.37 0.81 0.00 0.12 0.00 0.13 0.05 0.28 5.46 August 0.02 0.16 0.17 0.00 0.00 0.04 0.03 0.01 0.06 5.34 September 0.07 0.13 0.23 0.00 0.05 0.08 0.04 0.01 0.09 5.72 October 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 - November 0.01 0.04 0.06 0.00 0.00 0.03 0.01 0.00 0.01 6.45 December 0.04 0.08 0.07 0.00 0.09 0.01 0.01 0.01 0.05 6.67 2007 January 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 - February 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 - March 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 - April 0.06 0.08 0.17 0.00 0.03 0.02 0.03 0.02 0.10 6.59 May 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 - June 0.04 0.32 0.62 0.00 0.02 0.19 0.03 0.00 0.19 5.68 July 0.04 0.21 0.48 0.00 0.02 0.10 0.03 0.00 0.09 5.08 August 0.04 0.30 0.63 0.00 0.01 0.20 0.04 0.03 0.14 5.33 September 0.01 0.09 0.26 0.00 0.01 0.04 0.02 0.01 0.07 5.04 October 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 - November 0.04 0.03 0.06 0.00 0.03 0.02 0.02 0.01 0.03 6.18 December 0.01 0.04 0.02 0.00 0.01 0.01 0.01 0.00 0.02 5.99 2008 January 0.12 0.03 0.05 0.00 0.08 0.01 0.01 0.01 0.07 7.26 February 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 - March 0.11 0.08 0.18 0.00 0.08 0.02 0.04 0.01 0.06 6.10 April 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 - May 0.09 0.11 0.20 0.00 0.06 0.11 0.06 0.02 0.09 6.97 June 0.02 0.11 0.21 0.00 0.02 0.05 0.02 0.01 0.05 5.49 July 0.00 0.01 0.05 0.00 0.00 0.01 0.00 0.00 0.01 6.18 August 0.01 0.07 0.30 0.00 0.01 0.03 0.01 0.01 0.12 6.06 September 0.13 0.19 0.52 0.01 0.16 0.12 0.06 0.02 0.10 6.14 October 0.11 0.05 0.06 0.00 0.08 0.02 0.05 0.00 0.03 6.24 November 0.35 0.06 0.10 0.00 0.17 0.01 0.02 0.04 0.09 6.53 December 0.15 0.04 0.04 0.00 0.09 0.01 0.00 0.01 0.04 6.44


December 2009

Page B3-13

Table B3-12: Total Annual Wet Deposition Rates of Ions in Precipitation

CL (kg/ha/y)

NO3 (kg/ha/y)

SO4 (kg/ha/y)

Phosphate (kg/ha/y)

Na (kg/ha/y)

NH4 (kg/ha/y)

K (kg/ha/y)

Mg (kg/ha/y)

Ca (kg/ha/y)

2006 0.44 1.19 2.32 0.00 0.36 0.24 0.28 0.16 0.95

2007 0.25 1.07 2.25 0.00 0.12 0.58 0.17 0.07 0.63

2008 1.10 0.77 1.73 0.01 0.74 0.40 0.27 0.14 0.66

Average 0.60 1.01 2.10 0.01 0.41 0.41 0.24 0.12 0.75


December 2009

Page B3-14

Table B3-13 summarizes anion wet deposition calculated as the sum of nitrate, sulphate and ammonium equivalent deposition rates. Concentration information was summarized by month and monthly precipitation rates were used to calculate wet anion deposition rates from 2006 to 2008 at the Fort McKay station.

Table B3-13: Wet Deposition Rates of Anions, 2006-2008

NO3 (keq/ha/y)

SO4 (keq/ha/y)

NH4 (keq/ha/y)

Total Anions (keq/ha/y)

2006 0.019 0.048 0.013 0.081 2007 0.017 0.047 0.032 0.096 2008 0.012 0.036 0.022 0.070 Average 0.016 0.044 0.023 0.083

1.3.7.3 Base Cation Deposition

Base cation deposition rates are listed in Table B3-14. Average cation deposition rates are about one third the continuous PAI deposition rates. Chemical composition information for wet cation deposition rates was summarized for the 2006 to 2008 period at the Fort McKay station.

Table B3-14: Wet Deposition Rates of Cations, 2006-2008

K (keq/ha/y)

Mg (keq/ha/y)

Ca (keq/ha/y)

Na (keq/ha/y)

Total Cations (keq/ha/y)

2006 0.007 0.013 0.048 0.016 0.084 2007 0.004 0.006 0.031 0.005 0.047 2008 0.007 0.011 0.033 0.032 0.084 Average 0.006 0.010 0.037 0.018 0.071

1.3.7.4 Potential Acid Input

PAI deposition rates as estimated from continuous WBEA measurements in 2004 to 2008 and from 2002-2004 for passive measurements are listed in Table B3-15. This table is based on information provided in Tables B3-9 to B3-14. Total PAI is calculated as NO2 + SO2 + wet anions – wet cations – dry cations. Dry cation deposition rates were calculated using Beaverlodge and Esther regressions presented in Chaikowsky (2001). The PAI estimates in Table B3-15 show substantial spatial variability with the smallest values based on passive measurements at Mackay River and the largest values in Fort McMurray (Athabasca Valley monitoring station).


December 2009

Page B3-15

Table B3-15: Average PAI Estimates from Measurements; 2002-2004 for Passive and 2004-2008 for Continuous Measurements.

NO2 SO2 Anions Cations Cations Total PAI

Location Meas. Type Dry Deposition (keq/ha/y)

Dry Deposition (keq/ha/y)

Wet Deposition (keq/ha/y)

Wet Deposition (keq/ha/y)

Dry Deposition (keq/ha/y)


Fort McKay Passive 0.09 0.18 0.08 0.07 0.031 0.26

Patricia McInnes Passive 0.11 0.23 0.08 0.07 0.031 0.31

PetroCanada Mackay River

Passive 0.04 0.10 0.08 0.07 0.031 0.12

Fort McKay Continuous 0.15 0.21 0.08 0.07 0.031 0.34

Patricia McInnes Continuous 0.15 0.16 0.08 0.07 0.031 0.29

Athabasca Valley Continuous 0.25 0.14 0.08 0.07 0.031 0.37

1.3.8 Nitrogen Deposition

The importance of atmospheric deposition on nutrient concentration in water is discussed in Paerl (1997). For the purpose of this assessment, nitrogen available for eutrophication was calculated from deposited nitrogen as follows:

NE = MWN/MWNO2 NO2 + MWN/MWNO3 NO3 (dry and wet) + MWN/ MWNH4 NH4 (wet)

where MWx is the molecular weights or substance x, and deposition rates are given in kg/ha/y. N deposition estimates from continuous WBEA measurements in 2004 to 2008 and from 2002-2004 for passive measurements are presented in Table B3-16 and benchmark criteria for European ecosystems are presented in Table B3-16. Deposition values in urban areas such as Athabasca Valley exceed the lowest critical load for the most sensitive ecosystems while estimates at other industrial locations are less than the lowest critical load.

Table B3-16: Nitrogen Deposition Estimates NO2 NO2 NO3

- NO3- NH4

+ N equivalent

Location Meas. Type Concentration (µg/m3)

Dry Deposition (kg/ha/y)

Dry Deposition (kg/ha/y)

Wet Deposition (kg/ha/y)

Wet Deposition (kg/ha/y)


Fort McKay Passive 6.9 4.3 5.8 1.0 0.4 3.2

Patricia McInnes Passive 7.8 4.9 6.6 1.0 0.4 3.5

PetroCanada Mackay River

Passive 2.6 1.6 2.2 1.0 0.4 1.5

Fort McKay Continuous 11.1 6.9 9.4 1.0 0.4 4.8

Patricia McInnes Continuous 10.8 6.7 9.0 1.0 0.4 4.6

Athabasca Valley Continuous 18.3 11.4 15.4 1.0 0.4 7.5


December 2009

Page B3-16

Table B3-17: Summary of Critical Loads for Nitrogen Deposition (kg/ha/y) to Freshwater and Terrestrial Ecosystems in Europe (WHO 2000)

Ecosystem Critical Load Indication Mesotrophic fens 20–35 Increase in tall graminoids; decline in diversity Ombrotrophic (raised) bogs 5–10 Decrease in Sphagnum and subordinate species;

increase in tall graminoids Coniferous forests (acidic, managed) 10–15 Tree health; nutrient imbalance (low nitrification rate) Coniferous forests (acidic, managed) 20–50 Tree health; nutrient imbalance (moderate to high

nitrification rate) Coniferous forests (acidic, managed) 15–20 Changes in ground flora Deciduous forests (acidic, managed) 15–20 Tree health; nutrient imbalance; shoot–root

1.3.9 Volatile Organic Compounds (VOCs) and Polyaromatic Hydrocarbons (PAHs)

WBEA has an extensive VOC monitoring program that monitors numerous VOCs at several sites. The compounds monitored by the WBEA VOC program generally follow the US EPA precursors of O3 (PAMS) procedures. VOCs are monitored using stainless steel electropolished (SUMMA) canisters. Air samples are collected by drawing air into the canister at a constant rate (10 to 15 mL/min) for a 24 hour period on the 6-day NAPS cycle. These air samples are analyzed by GC/FID and GC/MSD techniques. The SUMMA canisters are evacuated and cleaned prior to installation. Minimum detection limits are determined from replicate measurements of low-level standards and acceptance criteria are evaluated as specified in EPA Method TO-15. Tables B3-18 to B3-22 list 24-h VOC concentration statistics at Fort McKay, Athabasca Valley, Patricia McInnes, Millenium and Syncrude UE1 stations for measurements in 2002 to 2003. The tables also include 1-h ambient air quality objectives for reference where available (AENV 2009). All observations are well below objectives. Tables B3-23 to B3-25 list PAH concentrations at Fort McKay, Patricia McInnes and Athabasca Valley stations. PAHs are analyzed for in total suspended particulate samples collected with the high-volume sampler every sixth day in accordance with the NAPS monitoring schedule. The TSP samples undergo laboratory analysis using GC/MS. There are presently no established AAAQOs for PAHs.


December 2009

Page B3-17

Table B3-18: 24-h VOC Concentrations in Fort McKay, 2002 to 2003 (μg/m3)

# Name Min Median Average Max 95 Percentile

98 Percentile

99 Percentile

99.9 Percentile

1-h AAAQG

1 1,2,4-Trimethylbenzene 0.000 0.000 0.035 0.281 0.177 0.213 0.247 0.278 2 1,3,5-Trimethylbenzene 0.000 0.000 0.003 0.058 0.032 0.057 0.058 0.058 3 1-Butene/Isobutene 0.000 0.125 0.179 0.787 0.465 0.724 0.755 0.784 4 1-Pentene 0.000 0.000 0.008 0.099 0.050 0.056 0.077 0.097 5 2,2,4-Trimethylpentane 0.000 0.000 0.008 0.070 0.040 0.061 0.066 0.070 6 2,2-Dimethylbutane 0.000 0.000 0.047 0.343 0.195 0.272 0.307 0.339 7 2,3,4-Trimethylpentane 0.000 0.000 0.004 0.160 0.000 0.019 0.090 0.153 8 2,3-Dimethylbutane 0.000 0.000 0.062 0.333 0.204 0.331 0.332 0.333 9 2,3-Dimethylpentane 0.000 0.000 0.060 0.753 0.190 0.517 0.635 0.741

10 2,4-Dimethylpentane 0.000 0.000 0.004 0.050 0.040 0.050 0.050 0.050 11 2-Methyl-1-Butene 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 12 2-Methyl-1-Pentene 0.000 0.000 0.008 0.109 0.050 0.093 0.101 0.108 13 2-Methyl-2-Butene 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 14 2-Methylheptane 0.000 0.050 0.129 1.132 0.610 0.806 0.969 1.116 15 2-Methylhexane 0.000 0.000 0.056 1.325 0.142 0.433 0.879 1.280 16 2-Methylpentane 0.000 0.068 0.178 1.275 0.649 1.091 1.183 1.266 17 3-Methylheptane 0.000 0.000 0.051 0.446 0.240 0.298 0.372 0.439 18 3-Methylhexane 0.000 0.050 0.111 1.673 0.348 0.683 1.178 1.624 19 3-Methylpentane 0.000 0.076 0.127 0.771 0.388 0.681 0.726 0.767 20 4-Methyl-1-Pentene 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 21 alpha Pinene 0.000 0.050 0.082 0.698 0.339 0.412 0.555 0.684 22 B-Pinine 0.000 0.000 0.058 0.565 0.225 0.479 0.522 0.561 23 Benzene 0.000 0.140 0.159 0.535 0.421 0.479 0.507 0.532 30 24 Butane 0.000 0.438 0.669 2.155 1.876 1.959 2.057 2.145 25 Cis-2-Butene 0.000 0.000 0.009 0.234 0.040 0.072 0.153 0.226 26 Cis-2-Hexene 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 27 Cis-2-Pentene 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 28 Cyclohexane 0.000 0.040 0.068 0.402 0.218 0.369 0.385 0.400 29 Cyclopentane 0.000 0.000 0.085 0.485 0.352 0.423 0.454 0.482 30 Cyclopentene 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 31 Ethylbenzene 0.000 0.000 0.043 0.238 0.201 0.228 0.233 0.238 2000 32 Heptane 0.000 0.115 0.267 1.994 1.285 1.408 1.701 1.965 33 Hexane 0.000 0.110 0.167 0.805 0.659 0.732 0.768 0.801 21,000 34 Iso-Propylbenzene 0.000 0.000 0.001 0.060 0.000 0.007 0.034 0.057 35 Isobutane 0.220 0.615 0.688 1.516 1.222 1.336 1.426 1.507 36 Isopentane 0.000 0.264 0.392 2.753 1.520 2.300 2.526 2.730 37 Isoprene 0.000 0.000 0.325 5.918 1.392 2.506 4.212 5.747 38 m and p-Xylene 0.000 0.085 0.150 0.715 0.501 0.668 0.692 0.713 2300 39 Methylcyclohexane 0.000 0.050 0.115 1.097 0.442 0.615 0.856 1.073 40 Methylcyclopentane 0.000 0.000 0.073 0.409 0.226 0.354 0.382 0.406 41 n-Propylbenzene 0.000 0.000 0.006 0.132 0.030 0.051 0.092 0.128 42 Nonane 0.000 0.000 0.047 0.289 0.201 0.279 0.284 0.289 43 o-Xylene 0.000 0.040 0.058 0.299 0.206 0.266 0.283 0.297 2300 44 Octane 0.000 0.060 0.159 1.246 0.826 0.911 1.078 1.229 45 Pentane 0.000 0.290 0.504 3.516 1.825 2.757 3.137 3.478 46 Styrene 0.000 0.000 0.019 0.819 0.000 0.125 0.472 0.784 215 47 Toluene 0.000 0.224 0.321 1.610 1.207 1.397 1.504 1.599 1880 48 Trans-2-Butene 0.000 0.000 0.013 0.196 0.070 0.150 0.173 0.194 49 Trans-2-Hexene 0.000 0.000 0.001 0.050 0.000 0.006 0.028 0.048 50 Trans-2-Pentene 0.000 0.000 0.001 0.040 0.000 0.005 0.022 0.038


December 2009

Page B3-18

Table B3-19: 24-h VOC Concentrations at Athabasca Valley, 2002 to 2003 (μg/m3)


98 Percentile

99 Percentile

99.9 Percentile

1-h AAAQG




December 2009

Page B3-19

Table B3-20: 24-h VOC Concentrations at Patricia McInnes, 2002 to 2003 (μg/m3)


98 Percentile

99 Percentile

99.9 Percentile

1-h AAAQG




December 2009

Page B3-20

Table B3-21: 24-h VOC Concentrations at Millenium, 2002 to 2003 (μg/m3)


98 Percentile

99 Percentile

99.9 Percentile

1-h AAAQG




December 2009

Page B3-21

Table B3-22: 24-h VOC Concentrations at Syncrude UE1, 2002 to 2003 (μg/m3)


98 Percentile

99 Percentile

99.9 Percentile

1-h AAAQG




December 2009

Page B3-22

Table B3-22: 24-h PAH Concentration Statistics at Fort McKay, 2004

Min (µg/m3)

Median (µg/m3)

Average (µg/m3)

Max (µg/m3)

95 Percentile

(µg/m3)

98 Percentile

(µg/m3)

99 Percentile

(µg/m3)

99.9 Percentile

(µg/m3) Acenaphthene 0.0000 0.0005 0.0009 0.004 0.003 0.004 0.004 0.004 Acenaphthylene 0.0000 0.0005 0.0008 0.004 0.002 0.003 0.004 0.004 Acridine 0.0000 0.0048 0.0081 0.041 0.020 0.032 0.037 0.040 Anthracene 0.0000 0.0005 0.0008 0.004 0.002 0.003 0.004 0.004 Benzo[a]anthracene 0.0000 0.0005 0.0008 0.004 0.002 0.003 0.004 0.004 Benzo[a]pyrene 0.0000 0.0005 0.0008 0.004 0.002 0.003 0.004 0.004 Benzo[b&j]fluoranthene 0.0000 0.0005 0.0008 0.004 0.002 0.003 0.004 0.004 Benzo[c]phenanthrene 0.0000 0.0005 0.0008 0.004 0.002 0.003 0.004 0.004 Benzo[g,h,i]perylene 0.0000 0.0005 0.0008 0.004 0.002 0.003 0.004 0.004 Benzo[k]fluoranthene 0.0000 0.0005 0.0008 0.004 0.002 0.003 0.004 0.004 Chrysene 0.0000 0.0005 0.0008 0.004 0.002 0.003 0.004 0.004 Dibenzo[a,h]anthracene 0.0000 0.0005 0.0008 0.004 0.002 0.003 0.004 0.004 Dibenzo[a,h]pyrene 0.0000 0.0010 0.0016 0.008 0.004 0.006 0.007 0.008 Dibenzo[a,i]pyrene 0.0000 0.0010 0.0016 0.008 0.004 0.006 0.007 0.008 Dibenzo[a,l]pyrene 0.0000 0.0010 0.0016 0.008 0.004 0.006 0.007 0.008 Fluoranthene 0.0000 0.0005 0.0008 0.004 0.002 0.003 0.004 0.004 Fluorene 0.0000 0.0005 0.0008 0.004 0.002 0.003 0.004 0.004 Indeno[1,2,3-cd]pyrene 0.0000 0.0005 0.0008 0.004 0.002 0.003 0.004 0.004 Naphthalene 0.0000 0.0005 0.0008 0.004 0.002 0.003 0.004 0.004 Phenanthrene 0.0013 0.0039 0.0055 0.030 0.014 0.023 0.026 0.029 Pyrene 0.0014 0.0024 0.0035 0.019 0.008 0.015 0.017 0.019 3-Methylcholanthrene 0.0000 0.0005 0.0008 0.004 0.002 0.003 0.004 0.004 7,12-Dimethylbenz[a]anthracene 0.0000 0.0048 0.0081 0.041 0.020 0.032 0.037 0.040

Table B3-24: 24-h PAH concentration statistics at Patricia McInnes, 2004

Min (µg/m3)

Median (µg/m3)

Average (µg/m3)

Max (µg/m3)

95 Percentile

(µg/m3)

98 Percentile

(µg/m3)

99 Percentile

(µg/m3)

99.9 Percentile

(µg/m3) 3-Methylcholanthrene 0.0004 0.0008 0.0009 0.002 0.002 0.002 0.002 0.002 7,12-Dimethylbenz[a]anthracene 0.0043 0.0075 0.0089 0.018 0.017 0.018 0.018 0.018 Acenaphthene 0.0004 0.0008 0.0009 0.002 0.002 0.002 0.002 0.002 Acenaphthylene 0.0004 0.0008 0.0011 0.004 0.003 0.003 0.003 0.003 Acridine 0.0043 0.0075 0.0089 0.018 0.017 0.018 0.018 0.018 Anthracene 0.0004 0.0008 0.0009 0.002 0.002 0.002 0.002 0.002 Benzo[a]anthracene 0.0004 0.0008 0.0009 0.002 0.002 0.002 0.002 0.002 Benzo[a]pyrene 0.0004 0.0008 0.0009 0.002 0.002 0.002 0.002 0.002 Benzo[b&j]fluoranthene 0.0004 0.0008 0.0009 0.002 0.002 0.002 0.002 0.002 Benzo[c]phenanthrene 0.0004 0.0008 0.0009 0.002 0.002 0.002 0.002 0.002 Benzo[g,h,i]perylene 0.0004 0.0008 0.0009 0.002 0.002 0.002 0.002 0.002 Benzo[k]fluoranthene 0.0004 0.0008 0.0009 0.002 0.002 0.002 0.002 0.002 Chrysene 0.0004 0.0008 0.0009 0.002 0.002 0.002 0.002 0.002 Dibenzo[a,h]anthracene 0.0004 0.0008 0.0009 0.002 0.002 0.002 0.002 0.002 Dibenzo[a,h]pyrene 0.0009 0.0015 0.0018 0.004 0.003 0.004 0.004 0.004 Dibenzo[a,i]pyrene 0.0009 0.0015 0.0018 0.004 0.003 0.004 0.004 0.004 Dibenzo[a,l]pyrene 0.0009 0.0015 0.0018 0.004 0.003 0.004 0.004 0.004 Fluoranthene 0.0004 0.0008 0.0009 0.002 0.002 0.002 0.002 0.002 Fluorene 0.0004 0.0008 0.0009 0.002 0.002 0.002 0.002 0.002 Indeno[1,2,3-cd]pyrene 0.0004 0.0008 0.0009 0.002 0.002 0.002 0.002 0.002 Naphthalene 0.0004 0.0008 0.0009 0.002 0.002 0.002 0.002 0.002 Phenanthrene 0.0040 0.0073 0.0071 0.012 0.011 0.012 0.012 0.012 Pyrene 0.0019 0.0034 0.0035 0.007 0.006 0.006 0.006 0.007


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Page B3-23

Table B3-25: 24-h PAH Concentration Statistics at Athabasca Valley, 2004

Min (µg/m3)

Median (µg/m3)

Average (µg/m3)

Max (µg/m3)

95 Percentile

(µg/m3)

98 Percentile

(µg/m3)

99 Percentile

(µg/m3)

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(µg/m3) Naphthalene 0.0000 0.0003 0.0003 0.0006 0.0005 0.0005 0.0006 0.0006 Acenaphthylene 0.0000 0.0003 0.0003 0.0006 0.0005 0.0005 0.0006 0.0006 Acenaphthene 0.0000 0.0003 0.0003 0.0008 0.0007 0.0007 0.0008 0.0008 Fluorene 0.0000 0.0003 0.0003 0.0006 0.0005 0.0005 0.0006 0.0006 Phenanthrene 0.0019 0.0028 0.0031 0.0081 0.0053 0.0070 0.0075 0.0080 Anthracene 0.0000 0.0003 0.0003 0.0006 0.0005 0.0005 0.0006 0.0006 Acridine 0.0000 0.0028 0.0030 0.0057 0.0049 0.0054 0.0055 0.0057 Fluoranthene 0.0002 0.0003 0.0003 0.0006 0.0005 0.0005 0.0006 0.0006 Pyrene 0.0003 0.0008 0.0007 0.0015 0.0012 0.0014 0.0014 0.0015 Benzo[c]phenanthrene 0.0002 0.0004 0.0004 0.0006 0.0005 0.0005 0.0006 0.0006 Benzo[a]anthracene 0.0000 0.0003 0.0003 0.0006 0.0005 0.0005 0.0006 0.0006 Chrysene 0.0000 0.0003 0.0003 0.0006 0.0005 0.0005 0.0006 0.0006 7,12-Dimethylbenz[a]anthracene 0.0000 0.0028 0.0030 0.0057 0.0049 0.0054 0.0055 0.0057 Benzo[b&j]fluoranthene 0.0000 0.0003 0.0003 0.0006 0.0005 0.0005 0.0006 0.0006 Benzo[k]fluoranthene 0.0000 0.0003 0.0003 0.0006 0.0005 0.0005 0.0006 0.0006 3-Methylcholanthrene 0.0000 0.0003 0.0003 0.0006 0.0005 0.0005 0.0006 0.0006 Benzo[a]pyrene 0.0000 0.0003 0.0003 0.0006 0.0005 0.0005 0.0006 0.0006 Indeno[1,2,3-cd]pyrene 0.0000 0.0003 0.0003 0.0006 0.0005 0.0005 0.0006 0.0006 Dibenzo[a,h]anthracene 0.0000 0.0003 0.0003 0.0006 0.0005 0.0005 0.0006 0.0006 Benzo[g,h,i]perylene 0.0000 0.0003 0.0003 0.0006 0.0005 0.0005 0.0006 0.0006 Dibenzo[a,h]pyrene 0.0000 0.0006 0.0006 0.0011 0.0010 0.0010 0.0011 0.0011 Dibenzo[a,i]pyrene 0.0000 0.0006 0.0006 0.0011 0.0010 0.0010 0.0011 0.0011 Dibenzo[a,l]pyrene 0.0000 0.0006 0.0006 0.0011 0.0010 0.0010 0.0011 0.0011


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Page B3-24

1.4 Meteorology and Climatology measurements

The climate was inferred primarily from observations from Fort Chipewyan and Fort McMurray from 2002-2006, as well as CALMET extracted data for a ‘pseudo-station’ located at the project location.

1.4.1 Winds

Winds in the region are defined by the interaction between the large-scale flow and the local terrain. The latter makes wind conditions vary over parts of the domain. Meteorological data for the period 2002 to 2006 at the Fort McMurray airport were obtained from Environment Canada. This station is about 120 km from the project. Wind roses created from this record are shown in Figures B3-13 to B3-15. Figure B3-13 shows the annual wind rose, and indicates the dominance of easterly winds followed by westerlies, a pattern that is likely shaped by the topography. As shown in Figure B3-14, seasonal variation is marked by change in wind speed between winter (December to February) when mean winds are weakest, to spring (March to May) when winds are at their strongest. Easterly winds are also more pronounced during these two seasons compared to the rest of the year. Figure B3-15 shows diurnal variation in wind patterns. The high frequency of winds from the west between 13:00 to 18:00, particularly in the summer suggests upslope winds induced by solar heating. In absence of a station at the project site, processed data were extracted from the CALMET outputs to describe meteorological conditions at KNOC. Wind roses created from the CALMET extracts for 2002 to 2006 are presented in Figures B3-16 to B3-19. As shown in Figures B3-16 and B3-17, winds at KNOC appear to be mainly from the southwest, a condition that is most pronounced in winter, particularly in December. During spring there appears to be no dominant wind direction, and during the rest of the year the flow tends to be from the west-southwest sector. As noted earlier, winds at KNOC are different from those at other stations as a result of terrain influences. As shown in Figure B3-18, hourly variation is insignificant, other than a small increase in frequency of flow from the east and a slight rise in mean speed during daytime. A comparison of annual wind roses from 2002 to 2006 also indicates minor year-to-year variation as shown in Figure B3-19. Winds from the southwest remain dominant in all years, and those from the opposite direction are the most infrequent. The interannual variation in the mean wind speed is also minor, with only a 10 percent difference between the windiest year (3.3 m/s in 2002) and average of the succeeding years (3.0 m/s).


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Page B3-25

For comparison, wind roses from selected WBEA network stations in the domain, as well as from the project pseudo-station are shown in Figure B3-20. At Fort Chipewyan, which is at the flatter northern section of the domain, winds also exhibit the same dominance of winds from the east as in Fort McMurray. Winds are however very different at other stations in the Athabasca Valley. The Mannix station shows a dominance of south-southeasterly winds, while southerly and northerly winds prevail at Fort McKay. By contrast, there is no dominant wind direction at the Patricia McInnes station.

1.4.2 Ambient Temperature

Temperature measurements in the area surrounding the proposed project for 2002-2006 are presented in Table B3-26 and Figures B3-21 to B3-23. The temperatures range from -43.7 oC (January) to +36.4oC (June) at Fort McMurray, from -39.2 oC (January) to +32.1oC (August) at Fort McMurray and from –40.6 to +36.7 oC at the project pseudo-station. Average temperatures ranged from 0.2 to 1.3oC. Temperatures at Fort Chipewyan are not expected to be substantially different from those at the Mannix Station. The diurnal and monthly temperature variations are presented in Figures B3-14 B3-16. The results indicate the following:

• Monthly median temperatures range from about -17°C in January to +16°C in July.

• The median hourly temperatures recorded at these stations show that the temperatures were the highest from 14:00 to 16:00 as a result of solar heating.

• The lowest median temperatures occurred just before sunrise from 4:00 to 7:00.

Table B3-26: Ambient Temperatures Measured at Fort Chipewyan, Fort McMurray Airport and Mannix (75 m level) in 2002

Temperature (oC) Station

Min Median Average Max Fort Chipewyan -39.2 1.1 0.3 32.1

Fort McMurray -43.7 2.1 1.3 36.4

Project Pseudo-Station -40.6 1.3 0.7 36.7

1.4.3 Atmospheric Stability

While Pasquil-Gifford stability classifications are not directly used in CALPUFF modelling, they are useful to describe the amount of turbulence present in the atmosphere. These classes range from unstable (Classes A, B, C) through neutral (D) to stable (E, F). Unstable conditions are primarily associated with daytime heating conditions that result in enhanced turbulence. Stable conditions occur during night-time cooling and indicated suppressed turbulence. Neutral conditions occur in cloudy or windy conditions.


December 2009

Page B3-26

Stability class was derived following the approach of US EPA where the final stability class changes are limited to one category per hour. For this reason, the final PG stability classes can include a few hours with stable conditions occurring in daylight hours, and or unstable conditions in evening hours. Figure B3-24 presents diurnal trends in PG stability class seasonally for the project pseudo-station. The information indicates:

• neutral conditions (Stability Class D) can occur at any hour of the day and occur about 27% of the time;

• unstable stability classes (A, B, and C) are limited to daytime hours and occur about 30% of the time, while stable classes (E and F) occur during night-time hours (except as indicated above) and occur about 44% of the time; and

• spring and summer have the largest percentage of stability Class A (very unstable) that can occur up to 10% of daylight hours. Winter and fall have the least stability Class A values as this class is associated with strong daytime heating.

1.4.4 Mixing Height

A temperature increase with height is referred to as an inversion. The base of the temperature inversion may be ground-based or elevated. In the case of the latter, a two-layered atmosphere is created. The lower layer tends to be well mixed and is characterized by neutral or unstable conditions. The depth of this lower layer is referred to as the mixing height. The upper layer tends to be characterized by stable conditions. The vertical transfer of mass between these two layers is minimal. Mixing heights are not explicitly used as inputs to the CALPUFF model. However, an examination of them is useful from a climatological perspective. During the night, the mixing height is determined by the mechanical interaction of the wind with surface features. Maximum mixing layer depths tend to be a few hundred metres. The depth of the mechanical mixing layer can be estimated from the relationship:

Zm = 263 U

where U is the wind speed at 10 m (m/s) and is centre-averaged for a 3-h period (Benkley and Schulman 1979). The above relationship assumes a surface roughness length of 100 cm, a logarithmic wind profile, a von Karman constant of 0.4 and a Coriolis parameter of 1.2 × 10-4 s-1. The roughness length is likely nearer to 0.5 to 1 m in the oil sands area, which may slightly increase Zm compared to the above value (AMEC 2001, True North Energy 2001). After sunrise, the solar heating usually determines the depth of the mixing layer. Typical depths increase from the mechanical mixing height at sunrise to heights of up to a few thousand metres by mid-afternoon. Mean maximum afternoon mixing depths for the study area were obtained from a climatological summary of mixing heights prepared by Portelli (1977).


December 2009

Page B3-27

Figure B3-25 shows mixing heights for the entire year at the project and shows diurnal variation in mixing heights by season. Median mixing heights range from approximately 200 m in winter (regardless of the time of day) to approximately 1,450 m in summer afternoons.

1.4.5 Precipitation

Table B3-27 and Figure B3-26 show average monthly rainfall, snowfall and total precipitation at the Fort McMurray Airport from 1980 through 2008. Most of the 342 mm of precipitation occurs during the period May to September. Most of the 156 mm of snowfall occurs during the period November to March. The greatest total precipitation of about 81 mm/month occurred in July.

Table B3-27: Average Precipitation at the Project Pseudo-Station, 1980-2006

Rainfall (mm)

Snowfall (mm)

Total Precipitation

(mm)

Snow Depth (cm)

January 0.5 27.0 19.3 28 February 0.8 20.6 15.0 31 March 1.6 20.4 16.1 26 April 9.3 14.5 21.7 6 May 34.2 2.9 36.9 0 June 74.8 0.0 74.8 0 July 81.3 0.0 81.3 0 August 72.6 0.0 72.7 0 September 45.0 2.4 46.8 0 October 18.8 13.1 29.6 1 November 2.4 29.0 22.2 9 December 1.1 25.9 19.3 20 Total 342.2 155.8 455.5 10

1.4.6 General Climate

While not directly related to dispersion, common climatological variables such as relative humidity are often of interest. Figure B3-27 shows the diurnal variation in relative humidity for each month at the project. The highest relative humidity values tend to occur in the early morning hours in October and November. The lowest values tend to occur in the afternoon hours in May and June. Overall, the lower daytime values are associated with the warmer temperatures that occur during the day.

1.4.7 Climate Summary

The climate can be inferred from observations in the study area.. A review of observations indicates the following:

• prevailing winds in the area are likely oriented along the Athabasca River valley. Those in larger study areas are expected to be from the west to south-westerly quadrants;

• average wind speeds for the area are relatively light with winds below 4 m/s occurring 58% of the time. Winds greater than 6 m/s occur about 10% of the time. Greater wind speeds tend to occur during the day;


December 2009

Page B3-28

• median ambient temperatures range from a low of about –17ºC in January to a high of about 16ºC in July;

• median afternoon mixing heights range from approximately 200 metres in winter to about 1,450 m in summer. Night-time mixing heights are typically in the 200 to 400 m range;

• stability classes follow a diurnal cycle with stable conditions occurring during the night and unstable conditions occurring during the day. Unstable conditions occur more frequently during the spring and summer;

• most precipitation occurs during the May to September period; and • mean relative humidity varies from a minimum of about 52 percent during spring day-

time periods to a maximum of about 92 percent during fall night-time periods.


Alberta Environment. 2009. Alberta’s Ambient Air Quality Objectives. Available at:. http://environment.gov.ab.ca/info/library/5726.pdf Accessed: December 2009.

AMEC Earth & Environmental. 2001. True North Fort Hills Oil Sands Project Application. Volume 2. Environmental Baseline Study. Calgary, AB.

AMEC Earth & Environmental. 2004. Ambient SO2 and NO2 Concentrations Associated with the Operation of the Joslyn SAGD Project – Phase II. Calgary, AB.

Altshuller, A.P. 1986. The Role of Nitrogen Oxides in Non-urban Ozone Formation in the Planetary Boundary Layer over North America, Western Europe and Adjacent Areas of Ocean. Atmospheric Environment 20:245-268. United States.

Angle, R. P. and H. S. Sandhu. 1986. Urban and Rural Ozone Concentrations in Alberta, Canada. Atmospheric Environment 20, 1221-1228. United States.

Angle, R. P. and H. S. Sandhu. 1989. Urban and rural ozone concentrations in Alberta, Canada. Atmospheric Environment 23, 215-221. United States.

Benkley C.W. and L.L. Schulman 1979. Estimating hourly mixing depths from historical data. Journal of Applied Meteorology 18:772-780.

Chaikowsky, C.L.A. 2001. Base Cation Deposition in Western Canada, 1982-1998. Alberta Environment Pub. No. T/605. University of Alberta. Edmonton, AB.

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Clean Air Strategic Alliance (CASA) Data Warehouse. Available at: http://www.casadata.org/Reports/SelectCategory.asp. Accessed: September 2009.

Conor Pacific. 2000. Ambient Air Quality Levels in Fort McKay and Fort McMurray. Prepared for Wood Buffalo Environmental Association. Edmonton, AB.


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Davies, T.D. and E. Schuepbach. 1994. Episodes of High Ozone Concentrations at the Earth’s Surface Resulting from Transport Down from the Upper Troposphere/Lower Stratosphere: A Review and Case Studies. Atmospheric Environment. 28 53-68.

EnCana Corp. (EnCana). 2007. Borealis In-Situ Project Application & Environmental Impact Assessment. Air Quality Section Prepared by AMEC E&E. Calgary, AB

Environment Canada. 2009. National Climate Data. Available at: http://www.climate.weatheroffice.ec.gc.ca/Welcome_e.html. Accessed: July 2009

EPCM Associates Ltd. 2002. Estimation of Dry Acid Deposition at TEEM Passive Monitoring Sites. Prepared for WBEA TEEM Committee. Fort McMurray, AB.

Fanaki, F., R. Hoff, L. Barrie, R. Mickle, M. Lusis, K. Anlauf, A. Gallant, J. Kovalick, F. Froude, J. Markess, J. Arnold, S. Melnichuk, D. Brymer, A. Guadenzi, A. Mosler and D. Bagg. 1979. Air System Summer Field Study in the AOSERP Study Area, June 1977. AOSERP Report 68. Prepared for the Alberta Oil Sands Environmental Research Program by Environment Canada, Atmospheric Environment Service. Edmonton, AB.

Leahey, D.M. and M.C. Hansen. 1990. Observational Evidence of Ozone Depletion by Nitric Oxide at 40 km Downwind of a Medium-size City. Atmospheric Environment 24A: 2533-2540.

Leforn, A.S., S.V. Krupa and D. Winstanley, 1990. Surface Ozone Exposures Measured at Clean Locations Around the World. Environmental Pollution 63:189-224.

Legge, A.H. and S.V. Krupa (eds.). 1990. Acid Deposition: Sulphur and Nitrogen Oxides. The Alberta Government-Industry Acid Deposition Research Program (ADRO). Lewis Publishers. Ann Arbor, MI.

Legge, A.H., M. Nosal, G.E. McVehil and S.V. Krupa. 1991. Ozone and the Clean Troposphere: Ecological Implications. Environmental Pollution 70: 157-175.

Myrick, R.H. 1995. Air Quality Monitoring in Alberta: 1993 Summary, Detailed and Data Reports. Air Issues and Monitoring Branch, Chemicals Assessment and Management Division, Alberta Environmental Protection. Edmonton, AB.

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Myrick, R.H. and D.M. Asquin. 1992. Air Quality Monitoring in Alberta: 1990 Summary, Detailed and Data Reports. Air Issues and Monitoring Branch, Chemicals Assessment and Management Division, Alberta Environmental Protection. Edmonton, AB.


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Myrick, R.H. and D.M. Asquin. 1993. Air Quality Monitoring in Alberta: 1991 Summary, Detailed and Data Reports. Air Issues and Monitoring Branch, Chemicals Assessment and Management Division, Alberta Environmental Protection. Edmonton, AB.

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Peake, E., M.A. Maclean and H.S. Sandhu. 1983. Surface Ozone and Peroxyacetyl Nitrate (PAN) Observations at Rural Location in Alberta, Canada. Journal of Air Pollution Control Association 33:881-883.

Peake, E., M.A. Maclean and H.S. Sandhu, 1985. Total Inorganic Nitrate (Particulate Nitrate and Nitric Acid) Observations in Calgary, Alberta. Journal of Air Pollution Control Association 35: 250-253.

Peake, E., M.A. Maclean, P.F. Lester and H.S. Sandhu. 1986. Secondary Air Pollutants (Peroxyacetyl Nitrate, Nitric Acid, Particulate Nitrate and Ozone) in Alberta, Canada. In Proceedings of the Seventh World Clean Air Congress, Sydney, Australia, August 25-29, 1986. Clean Air Society of Australia & New Zealand. Sydney, Australia.

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World Health Organization (WHO). 2000. WHO Air Quality Guidelines. Chapter 14: Effects of airborne nitrogen pollutants on vegetation - critical loads. Available at: http://www.euro.who.int/air/activities/20050223_4.

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Month

SO2 (u

g/m

3 )

0

5

10

15

20

25

30 5% - 95%

25% - 75%

Syncrude UE1


December 2009

0

5

10

15

20

25

30

35

40

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

SO2 (

ug/m

3 )

0

5

10

15

20

25

30

35

40 5% - 95%

25% - 75%Albian Mine

0

5

10

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

SO2 (

ug/m

3 )

0

5

10 5% - 95%

25% - 75%Anzac

0

5

10

15

20

25

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

SO2 (

ug/m

3 )

0

5

10

15

20

25 5% - 95%

25% - 75%Athabasca Valley

0

5

10

15

20

25

30

35

40

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

SO2 (

ug/m

3 )

0

5

10

15

20

25

30

35

40 5% - 95%

25% - 75%Buffalo Viewpoint

0

5

10

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

SO2 (

ug/m

3 )

0

5

10 5% - 95%

25% - 75%

Fort Chipewyan

0

5

10

15

20

25

30

35

40

45

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

SO2 (

ug/m

3 )

0

5

10

15

20

25

30

35

40

45 5% - 95%

25% - 75%Fort McKay

0

5

10

15

20

25

30

35

40

45

50

55

60

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

SO2 (

ug/m

3 )

0

10

20

30

40

50

60 5% - 95%

25% - 75%Lower Camp

0

5

10

15

20

25

30

35

40

45

50

55

60

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

SO2 (

ug/m

3 )

0

10

20

30

40

50

60 5% - 95%

25% - 75%Mannix

Figure B3-3: Diurnal Variation in SO2 Concentration at

WBEA Stations 2004-2008.1

1Hour 2 measurements are generally absent due to calibration.

0

5

10

15

20

25

30

35

40

45

50

55

60

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

SO2 (

ug/m

3 )

0

10

20

30

40

50

60 5% - 95%

25% - 75%Mildred Lake

0

5

10

15

20

25

30

35

40

45

50

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

SO2 (

ug/m

3 )

0

5

10

15

20

25

30

35

40

45

50 5% - 95%

25% - 75%Millenium

0

5

10

15

20

25

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

SO2 (

ug/m

3 )

0

5

10

15

20

25 5% - 95%

25% - 75%

Patricia McInnes

0

5

10

15

20

25

30

35

40

45

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

SO2 (

ug/m

3 )

0

5

10

15

20

25

30

35

40

45 5% - 95%

25% - 75%

Syncrude UE1


December 2009

0

5

10

15

20

25

30

35

40

45

50

55

60

65

70

75

80

85

90

Janu

ary

Febr

uary

March

April

May

June July

Augu

st

Sept

embe

r

Octobe

r

Novem

ber

Decem

ber

Month

NO

x (ug

/m3 )

0

10

20

30

40

50

60

70

80

90 5% - 95%

25% - 75%

Albian Mine

0

5

10

15

20

25

30

35

Janu

ary

Febr

uary

March

April

May

June July

Augu

st

Sept

embe

r

Octobe

r

Novem

ber

Decem

ber

Month

NO

x (ug

/m3 )

0

5

10

15

20

25

30

35 5% - 95%

25% - 75%

Anzac

0

5

10

15

20

25

30

35

40

45

50

55

60

65

70

75

80

Janu

ary

Febr

uary

March

April

May

June July

Augu

st

Sept

embe

r

Octobe

r

Novem

ber

Decem

ber

Month

NO

x (ug

/m3 )

0

10

20

30

40

50

60

70

80 5% - 95%

25% - 75%

Athabasca Valley

0

5

10

15

20

Janu

ary

Febr

uary

March

April

May

June July

Augu

st

Sept

embe

r

Octobe

r

Novem

ber

Decem

ber

Month

NO

x (ug

/m3 )

0

5

10

15

20 5% - 95%

25% - 75%

Fort Chipewyan

0

5

10

15

20

25

30

35

40

45

50

55

60

65

70

Janu

ary

Febr

uary

March

April

May

June July

Augu

st

Sept

embe

r

Octobe

r

Novem

ber

Decem

ber

Month

NO

x (ug

/m3 )

0

10

20

30

40

50

60

70 5% - 95%

25% - 75%

Fort McKay

0

5

10

15

20

25

30

35

40

45

50

55

60

Janu

ary

Febr

uary

March

April

May

June July

Augu

st

Sept

embe

r

Octobe

r

Novem

ber

Decem

ber

Month

NO

x (ug

/m3 )

0

10

20

30

40

50

60 5% - 95%

25% - 75%

Patricia McInnes

Figure B3-4: Seasonal Variation of NO2 for WBEA Stations 2004-2008

0

5

10

15

20

25

30

35

40

45

50

55

60

65

70

75

80

85

90

Janu

ary

Febr

uary

March

April

May

June July

Augu

st

Sept

embe

r

Octobe

r

Novem

ber

Decem

ber

Month

NO

x (ug

/m3 )

0

10

20

30

40

50

60

70

80

90 5% - 95%

25% - 75%

Millenium

0

5

10

15

20

25

30

35

40

45

50

55

60Ja

nuar

y

Febr

uary

March

April

May

June July

Augu

st

Sept

embe

r

Octobe

r

Novem

ber

Decem

ber

Month

NO

x (ug

/m3 )

0

10

20

30

40

50

60 5% - 95%

25% - 75%

Syncrude UE1


December 2009

0

5

10

15

20

25

30

35

40

45

50

55

60

65

70

75

80

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

NO

x (ug

/m3 )

0

10

20

30

40

50

60

70

80 5% - 95%

25% - 75%

Albian Mine

0

5

10

15

20

25

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

NO

x (ug

/m3 )

0

5

10

15

20

25 5% - 95%

25% - 75%

Anzac

0

5

10

15

20

25

30

35

40

45

50

55

60

65

70

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

NO

x (ug

/m3 )

0

10

20

30

40

50

60

70 5% - 95%

25% - 75%

Athabasca Valley

0

5

10

15

20

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

NO

x (ug

/m3 )

0

5

10

15

20 5% - 95%

25% - 75%

Fort Chipewyan

0

5

10

15

20

25

30

35

40

45

50

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

NO

x (ug

/m3 )

0

5

10

15

20

25

30

35

40

45

50 5% - 95%

25% - 75%

Fort McKay

0

5

10

15

20

25

30

35

40

45

50

55

60

65

70

75

80

85

90

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

NO

x (ug

/m3 )

0

10

20

30

40

50

60

70

80

90 5% - 95%

25% - 75%

Millenium

Figure B3-5: Diurnal Variation of NO2 Concentration for WBEA Stations 2004-20081


0

5

10

15

20

25

30

35

40

45

50

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

NO

x (ug

/m3 )

0

5

10

15

20

25

30

35

40

45

50 5% - 95%

25% - 75%

Patricia McInnes

0

5

10

15

20

25

30

35

40

45

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

NO

x (ug

/m3 )

0

5

10

15

20

25

30

35

40

45 5% - 95%

25% - 75%

Syncrude UE1


December 2009

0

5

10

15

20

25

30

35

Janu

ary

Febr

uary

March

April

May

June July

Augu

st

Sept

embe

r

Octobe

r

Novem

ber

Decem

ber

Month

PM2.

5 (ug

/m3 )

0

5

10

15

20

25

30

35 5% - 95%

25% - 75%

Albian Mine

0

5

10

15

20

Janu

ary

Febr

uary

March

April

May

June July

Augu

st

Sept

embe

r

Octobe

r

Novem

ber

Decem

ber

Month

PM2.

5 (ug

/m3 )

0

5

10

15

20 5% - 95%

25% - 75%

Anzac

0

5

10

15

20

25

Janu

ary

Febr

uary

March

April

May

June July

Augu

st

Sept

embe

r

Octobe

r

Novem

ber

Decem

ber

Month

PM2.

5 (ug

/m3 )

0

5

10

15

20

25 5% - 95%

25% - 75%

Athabasca Valley

0

5

10

15

20

25

Janu

ary

Febr

uary

March

April

May

June July

Augu

st

Sept

embe

r

Octobe

r

Novem

ber

Decem

ber

Month

PM2.

5 (ug

/m3 )

0

5

10

15

20

25 5% - 95%

25% - 75%

Fort Chipewyan

0

5

10

15

20

25

Janu

ary

Febr

uary

March

April

May

June July

Augu

st

Sept

embe

r

Octobe

r

Novem

ber

Decem

ber

Month

PM2.

5 (ug

/m3 )

0

5

10

15

20

25 5% - 95%

25% - 75%

Fort McKay

0

5

10

15

20

25

30

Janu

ary

Febr

uary

March

April

May

June July

Augu

st

Sept

embe

r

Octobe

r

Novem

ber

Decem

ber

Month

PM2.

5 (ug

/m3 )

0

5

10

15

20

25

30 5% - 95%

25% - 75%

Millenium

Figure B3-6: Seasonal Variation of PM2.5 Concentrations for WBEA Stations 2004-2008

0

5

10

15

20

25

Janu

ary

Febr

uary

March

April

May

June July

Augu

st

Sept

embe

r

Octobe

r

Novem

ber

Decem

ber

Month

PM2.

5 (ug

/m3 )

0

5

10

15

20

25 5% - 95%

25% - 75%

Patricia McInnes

0

5

10

15

20

25

Janu

ary

Febr

uary

March

April

May

June July

Augu

st

Sept

embe

r

Octobe

r

Novem

ber

Decem

ber

Month

PM2.

5 (ug

/m3 )

0

5

10

15

20

25 5% - 95%

25% - 75%

Syncrude UE1


December 2009

0

5

10

15

20

25

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

PM2.

5 (ug

/m3 )

0

5

10

15

20

25 5% - 95%

25% - 75%

Albian Mine

0

5

10

15

20

25

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

PM2.

5 (ug

/m3 )

0

2

4

6

8

10

12 5% - 95%

25% - 75%

Anzac

0

5

10

15

20

25

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

PM2.

5 (ug

/m3 )

0

5

10

15

20

25 5% - 95%

25% - 75%

Athabasca Valley

0

5

10

15

20

25

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

PM2.

5 (ug

/m3 )

0

1

2

3

4

5

6

7

8

9 5% - 95%

25% - 75%

Fort Chipewyan

0

5

10

15

20

25

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

PM2.

5 (ug

/m3 )

0

2

4

6

8

10

12

14

16

18 5% - 95%

25% - 75%

Fort McKay

0

5

10

15

20

25

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

PM2.

5 (ug

/m3 )

0

5

10

15

20

25 5% - 95%

25% - 75%

Millenium

Figure B3-7: Diurnal Variation in PM2.5 Concentration for WBEA Stations 2004-20081


0

5

10

15

20

25

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

PM2.

5 (ug

/m3 )

0

2

4

6

8

10

12

14

16

18 5% - 95%

25% - 75%

Patricia McInnes

0

5

10

15

20

25

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

PM2.

5 (ug

/m3 )

0

2

4

6

8

10

12

14

16

18 5% - 95%

25% - 75%

Syncrude UE1


December 2009

0

5

10

15

20

25

Janu

ary

Februa

ry

March

April

May

June Ju

ly

Augu

st

Septem

ber

Octobe

r

Novem

ber

Decem

ber

Month

PM2.

5 (ug

/m3 )

0

100

200

300

400

500

600

700

800 5% - 95%

25% - 75%

Athabasca Valley

0

100

200

300

400

500

600

700

800

900

1000

1100

1200

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

CO

(ug/

m3 )

0

200

400

600

800

1000

1200 5% - 95%

25% - 75%

Athabasca Valley

Figure B3-8: Seasonal (Top) and Diurnal (Bottom) Variation in 1-h

Average CO Concentration at Athabasca Valley, 2004-2008


December 2009

0

10

20

30

40

50

60

70

80

90

100

110

120

Janu

ary

Febr

uary

March

April

May

June July

Augu

st

Sept

embe

r

Octobe

r

Novem

ber

Decem

ber

Month

PM2.

5 (ug

/m3 )

0

10

20

30

40

50

60

70

80

90

100

110

120 5% - 95%

25% - 75%

Anzac

0

10

20

30

40

50

60

70

80

90

100

110

120

Janu

ary

Febr

uary

March

April

May

June July

Augu

st

Sept

embe

r

Octobe

r

Novem

ber

Decem

ber

Month

PM2.

5 (ug

/m3 )

0

10

20

30

40

50

60

70

80

90

100

110

120 5% - 95%

25% - 75%

Athabasca Valley

0

10

20

30

40

50

60

70

80

90

100

110

120

Janu

ary

Febr

uary

March

April

May

June July

Augu

st

Sept

embe

r

Octobe

r

Novem

ber

Decem

ber

Month

PM2.

5 (ug

/m3 )

0

10

20

30

40

50

60

70

80

90

100

110

120 5% - 95%

25% - 75%

Fort Chipewyan

0

10

20

30

40

50

60

70

80

90

100

110

120

Janu

ary

Febr

uary

March

April

May

June July

Augu

st

Sept

embe

r

Octobe

r

Novem

ber

Decem

ber

Month

PM2.

5 (ug

/m3 )

0

10

20

30

40

50

60

70

80

90

100

110

120 5% - 95%

25% - 75%

Fort McKay

0

10

20

30

40

50

60

70

80

90

100

110

120

Janu

ary

Febr

uary

March

April

May

June July

Augu

st

Sept

embe

r

Octobe

r

Novem

ber

Decem

ber

Month

PM2.

5 (ug

/m3 )

0

10

20

30

40

50

60

70

80

90

100

110

120 5% - 95%

25% - 75%

Patricia McInnes

0

10

20

30

40

50

60

70

80

90

100

110

120

Janu

ary

Febr

uary

March

April

May

June July

Augu

st

Sept

embe

r

Octobe

r

Novem

ber

Decem

ber

Month

PM2.

5 (ug

/m3 )

0

10

20

30

40

50

60

70

80

90

100

110

120 5% - 95%

25% - 75%

Syncrude UE1

Figure B3-9: Seasonal Variation of O3 Concentrations

for WBEA Stations 2004-2008


December 2009

0

10

20

30

40

50

60

70

80

90

100

110

120

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

O3 (u

g/m

3 )

0

20

40

60

80

100

120 5% - 95%

25% - 75%

Anzac

0

10

20

30

40

50

60

70

80

90

100

110

120

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

O3 (u

g/m

3 )

0

20

40

60

80

100

120 5% - 95%

25% - 75%

Athabasca Valley

0

10

20

30

40

50

60

70

80

90

100

110

120

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

O3 (u

g/m

3 )

0

10

20

30

40

50

60

70

80

90

100

110

120 5% - 95%

25% - 75%

Fort Chipewyan

0

10

20

30

40

50

60

70

80

90

100

110

120

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

O3 (u

g/m

3 )

0

20

40

60

80

100

120 5% - 95%

25% - 75%

Fort McKay

0

10

20

30

40

50

60

70

80

90

100

110

120

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

O3 (u

g/m

3 )

0

20

40

60

80

100

120 5% - 95%

25% - 75%

Patricia McInnes

0

10

20

30

40

50

60

70

80

90

100

110

120

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hour

O3 (u

g/m

3 )

0

20

40

60

80

100

120 5% - 95%

25% - 75%

Syncrude UE1

Figure B3-10: Diurnal Variation in O3 Concentrations



December 2009

0

1

2

3

4


Month

H2S

(ug/

m3 )

0

1

2

3

4 5% - 95%

25% - 75%

Buffalo Viewpoint

0

1

2

3

4

5

6

7

8


Month

H2S

(ug/

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December 2009

Figure B3-13: Wind Roses for 2002-2006 at the Fort McMurray Airport


December 2009

Figure B3-14: Seasonal Wind Roses for 2002-2006 at the Fort McMurray Airport


December 2009

Figure B3-15: Six-hour Wind Roses for 2002-2006 the Fort McMurray Airport


December 2009

Figure B3-16: Wind Rose for 2002-2006 at the Project Pseudo-Station


December 2009

Figure B3-17: Monthly Wind Roses for 2002-2006 at the Project Pseudo-Station


December 2009

Figure B3-18: Six-hour Wind Roses for 2002-2006 at the Project Pseudo-Station


December 2009

Figure B3-19: Annual Wind Roses for 2002-2006 at the Project Pseudo-Station


December 2009

W4*. Wind roses at other locations in the study area.

Figure B3-20: Wind Roses at other locations in the study area for 2002-2006


December 2009

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December 2009

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Figure B3-24: Diurnal and Seasonal Stability Class Frequency Distributions

at the Project Pseudo-Station


December 2009

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December 2009

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Figure B3-26: Average Monthly Rainfall, Snowfall and Total Precipitation Values for

Fort McMurray Airport from 1980 through to 2008


December 2009

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Figure B3-27: Annual Relative Humidity at the Project Pseudo-Station

Appendix B4

Background Emission Source Information VOCs and PAHs


December 2009


APPENDIX B4: BACKGROUND EMISSION SOURCE INFORMATION VOCS AND PAHS TABLE OF CONTENTS

PAGE

1.0 INTRODUCTION......................................................................................................... B4-1

2.0 INDUSTRIAL FACILITIES.......................................................................................... B4-4 2.1 Albian Sands Energy Inc. ................................................................................ B4-4 2.2 Birch Mountain Resources .............................................................................. B4-5 2.3 Canadian Natural Resources Limited.............................................................. B4-7 2.4 Connacher Oil and Gas Limited ...................................................................... B4-8 2.5 ConocoPhillips Canada Resources Corporation ........................................... B4-10 2.6 Deer Creek Energy Limited ........................................................................... B4-12 2.7 Devon Energy Corp. ...................................................................................... B4-14 2.8 EnCana Corporation...................................................................................... B4-16 2.9 Husky Energy ................................................................................................ B4-18 2.10 Imperial Oil / ExxonMobil............................................................................... B4-19 2.11 Japan Canada Oil Sands .............................................................................. B4-20 2.12 MEG Energy Corporation .............................................................................. B4-22 2.13 OPTI Canada/Nexen Canada Limited ........................................................... B4-24 2.14 Petro-Canada ................................................................................................ B4-26 2.15 Shell Canada Limited .................................................................................... B4-28 2.16 StatoilHydro................................................................................................... B4-30 2.17 Suncor Energy Inc. ........................................................................................ B4-32 2.18 Syncrude Canada Ltd.................................................................................... B4-35 2.19 Whitesands In-situ Partnership ..................................................................... B4-37

3.0 COMMUNITIES AND HIGHWAYS ........................................................................... B4-38



December 2009



LIST OF TABLES

Table B4-1: Estimated Fugitive TRS Emissions from the Joslyn North Mine Tailings Pond ................................................................................................................ B4-2

Table B4-2: Summary of Albian Sands Muskeg River Mine and ATCO Cogeneration Facility VOC and PAH Air Emissions Used for Baseline, Project and Planned Development Scenarios .................................................................... B4-4

Table B4-3: Summary of Birch Mountain Muskeg River Quarry VOC and PAH Air Emissions Used for the Baseline and Project Scenarios ............................... B4-5

Table B4-4: Summary of Birch Mountain Hammerstone Quarry VOC and PAH Air Emissions Used for the Planned Scenario ...................................................... B4-6

Table B4-5: Summary of CNRL Horizon and Kirby VOC and PAH Air Emissions Used for the Baseline, Project and Planned Development Scenarios...................... B4-7

Table B4-6: Summary of Connacher VOC and PAH Air Emissions Used for the Baseline and Project Scenarios ...................................................................... B4-8

Table B4-7: Summary of Connacher VOC and PAH Air Emissions Used for the Planned Development Scenario ...................................................................... B4-9

Table B4-8: Summary of ConocoPhillips Surmont VOC and PAH Air Emissions Used in the Baseline and Project Scenarios.......................................................... B4-10

Table B4-9: Summary of ConocoPhillips Surmont VOC and PAH Air Emissions Used in the Planned Development Scenario .......................................................... B4-11

Table B4-10: Summary of DCEL Joslyn VOC and PAH Air Emissions Used for the Baseline and Project Scenarios .................................................................... B4-12

Table B4-11: Summary of DCEL Joslyn VOC and PAH Air Emissions Used for the Planned Development Scenario .................................................................... B4-13

Table B4-12: Summary of Devon VOC and PAH Air Emissions Used for the Baseline, and Project Scenarios ................................................................................... B4-14

Table B4-13: Summary of Devon VOC and PAH Air Emissions Used for the Planned Development Scenario .................................................................................. B4-15

Table B4-14: Summary of EnCana VOC and PAH Air Emissions Used for the Baseline and Project Scenarios ................................................................................... B4-16

Table B4-15: Summary of EnCana VOC and PAH Air Emissions Used for the Planned Development Scenario .................................................................................. B4-17

Table B4-16: Summary of Husky Sunrise VOC and PAH Air Emissions Used for Baseline, Project and Planned Development Scenarios ............................... B4-18

Table B4-17: Summary of IOL / ExxonMobil Kearl Mine VOC and PAH Air Emissions Used for Baseline, Project and Planned Development Scenarios................. B4-19

Table B4-18: Summary of JACOS Hangingstone VOC and PAH Air Emissions Used for the Baseline and Project Scenarios ........................................................ B4-20

Table B4-19: Summary of JACOS Hangingstone VOC and PAH Air Emissions Used for the Planned Development Scenario......................................................... B4-21

Table B4-20: Summary of OPTI/Nexen long Lake VOC and PAH Air Emissions Used for the Baseline and Project Scenarios ......................................................... B4-22

Table B4-21: Summary of OPTI/Nexen long Lake VOC and PAH Air Emissions Used for the Planned Development Scenario......................................................... B4-23


December 2009


Table B4-22: Summary of OPTI/Nexen long Lake VOC and PAH Air Emissions Used for the Baseline and Project Scenarios ......................................................... B4-24

Table B4-23: Summary of OPTI/Nexen Long Lake VOC and PAH Air Emissions Used for the Planned Development Scenario......................................................... B4-25

Table B4-24: Summary of Petro-Canada VOC and PAH Air Emissions Used for the Baseline and Project Scenarios .................................................................... B4-26

Table B4-25: Summary of Petro-Canada VOC and PAH Air Emissions Used for the Planned Development Scenario .................................................................... B4-27

Table B4-26: Summary of Shell Jackpine Mine VOC and PAH Air Emissions Used for the Baseline and Project Scenarios .............................................................. B4-28

Table B4-27: Summary of Shell Jackpine Mine VOC and PAH Air Emissions Used for the Planned Development Scenario .............................................................. B4-29

Table B4-28: Summary of StatoilHydro VOC and PAH Air Emissions Used for the Baseline and Project Scenarios .................................................................... B4-30

Table B4-29: Summary of StatoilHydro VOC and PAH Air Emissions Used for the Planned Development Scenario .................................................................... B4-31

Table B4-30: Summary of Suncor Millennium and Voyageur VOC and PAH Air Emissions Used for the Baseline, Project and Planned Development Scenarios ...................................................................................................... B4-32

Table B4-31: Summary of Suncor Firebag VOC and PAH Air Emissions Used for the Baseline and Project Scenarios .................................................................... B4-33

Table B4-32: Summary of Suncor Firebag VOC and PAH Air Emissions Used for the Planned Development Scenario .................................................................... B4-34

Table B4-33: Summary of Syncrude Mildred Lake VOC and PAH Air Emissions Used for the Baseline, Project and Planned Development Emission Scenarios .... B4-35

Table B4-34: Summary of Syncrude Aurora North and South Mine Facilities VOC and PAH Air Emissions Used for the Baseline, Project and Planned Development Scenarios ................................................................................ B4-36

Table B4-35: Summary of Whitesands VOC and PAH Air Emissions Used for the Baseline, Project and Planned Development Scenarios .............................. B4-37

Table B4-36: Summary of Community VOC and PAH Air Emissions Used for the Baseline and Project Scenarios .................................................................... B4-38

Table B4-37: Summary of Highway VOC and PAH Air Emissions Used for the Baseline and Project Scenarios ................................................................................... B4-39

Table B4-38: Summary of Community VOC and PAH Air Emissions Used for the Planned Development Scenario .................................................................... B4-40

Table B4-39: Summary of Highway VOC and PAH Air Emissions Used for the Planned Development Scenario .................................................................................. B4-41

S:\Project Ce\Ce03745\EIA\Vol 3\app b4-Volume 3-final EIA-ce03745-dec09-dr.doc


December 2009

Page B4-1

APPENDIX B4: BACKGROUND EMISSION SOURCE INFORMATION VOCS AND PAHS

1.0 INTRODUCTION

This appendix lists the emission source characteristics and emission rate details of VOCs and PAHs species within the AQRSA. The data represent facility and planned project emission information obtained primarily from recent EIAs (DCEL 2007, EnCana 2007). The facility and planned project emissions within the AQRSA that were included in the Baseline and Planned Development (Planned) emission scenarios of this air quality assessment are presented on a company-by-company basis. Background emission sources for the project emission scenario were considered to be the same as those for the Baseline scenario. The emission rates for all individual species were not provided by project operators although total VOC emissions, as well as those for certain species, were available for some. For those chemicals whose emissions were not directly available, they were estimated as follows.

Tailings Ponds

Whenever speciated tailings pond emissions were directly available from other operations, they were used (e.g., UTS Fort Hills, Syncrude Mildred Lake). Tailings pond emissions for other facilities, were based on the speciated VOC emission profile from the Joslyn North Mine Tailings Pond (DCEL 2007) and scaled to the respective bitumen production of each facility. It is generally understood that emission rates of VOCs from tailings ponds vary with temperature. A monthly variable tailings pond emissions scheme has been employed in some recent EIAs in the region (CNRL 2003, Suncor 2003, Imperial Oil 2005) to determine the monthly average emission rates for the tailing ponds. Typically such a scheme varies the total emissions from the ponds between 100% in the summer and 2% in the coldest winder months. For this assessment however, it has been assumed that tailings pond emissions are constant at 100%.This assumption is conservative, however the project has no pond emissions and the effect of this change on the gross regional emissions is minimal. Emission rates of total reduced sulphur (TRS) compounds from the Joslyn North Mine tailings pond are shown in Table B4-1. These emission rates were derived from unpublished emission flux rate measurements taken from various locations on and around the Syncrude Mildred Lake settling basin (Clearstone 1998). Based on these measurements, TRS emissions were largely comprised of the following five compounds: H2S, CS2 (carbon disulphide), COS (carbonyl sulphide), mercaptans and thiophenes. TRS emissions for all other tailings ponds in the region were scaled to corresponding facility bitumen production.


December 2009

Page B4-2

Table B4-1: Estimated Fugitive TRS Emissions from the Joslyn North Mine Tailings Pond

Component Emissions From Tailings Pond1 (kg/day)

Hydrogen Sulphide 9.9 Carbonyl Sulphide 8.3 Carbon Disulphide 2.6 Thiophenes 17.2 Mercaptans 0.022 1 Tailings pond emissions are based on peak summer emission rates.

Other Sources

Mining area fugitive emission rates for VOCs and PAHs at active faces were derived based on Clearstone (1998) data for the Syncrude Mildred Lake plant and mine facilities. These data represent emission flux rates measured for a variety of mine surface areas. The fugitive emission rates were determined using one normalized data set of “g/s per 1,000 bpd of bitumen production” to represent all types of mine fugitive emission surfaces. Estimated benzene emission rates were compared with those reported for other developments, if available. For those cases in which benzene emission rates were reported, the emission rates for all chemicals were readjusted in proportion to the reported benzene emission rate. Fugitive emission rates for VOCs and PAHs from upgrading facilities, as well as from mining and extraction facilities, were derived and applied in the same manner as described above (using only one normalized data set of “g/s per 1000 bpd of bitumen production” to represent all types of plant fugitive emission sources, including plant fittings, wastewater pond and API separator, and storage tanks). Mining area fleet exhaust emission rates for the four criteria emissions were based on the rates reported by each facility and development. Exhaust emission rates for the remaining VOCs and PAHs were based on US EPA AP-42 derived diesel engine emission factors (g/1000L diesel fuel consumption). The diesel fuel consumption rate for each development, where unavailable directly, was determined by scaling from the diesel fuel consumption rate reported for the Syncrude Mildred Lake mine using the reported bitumen production rate for each development. Processing plant emissions from plant combustion sources were estimated based on derived fuel gas consumptions (Sm3 per 1000 bpd of bitumen or upgraded product production, typical for SAGD, mining & extraction, and mining, extraction & upgrading type facilities, respectively) and US EPA AP-42 derived natural gas external combustion emission factors for the VOCs and PAHs. Bitumen or upgraded product production data as reported for each development were used to estimate the fuel gas consumption rate and, thus, the total emission rates for each development. Baseline community fugitive VOCs emissions for the community were calculated using a fugitive benzene emission rate that was determined for Fort McMurray in 2001 (Martin Rawlings, personal communication, as documented in True North 2001). This fugitive benzene emission


December 2009

Page B4-3

rate was scaled to current population figures, and the adjusted value was used to back-calculate per capita natural gas and equivalent-diesel fuel consumption rates for Fort McMurray. The other speciated VOCs were then calculated using the fuel usage numbers and the AP-42 emission factors. Community emission rates of VOCs and PAHs for the Planned Development case were scaled up based on the projected population of these communities 25 years after the start of project operations. The populations were all assumed to grow at a rate of 3% per year for 25 years over baseline estimates. Baseline highway fugitive emission rates for VOCs and PAHs were derived by estimating the annual average daily traffic volume, the average number of kilometres each vehicle traveled, and the average equivalent diesel fuel consumption rate of each vehicle travelling on the highways, and then multiplying these figures by the US EPA AP-42 derived diesel fuel internal combustion emission factors. For the Planned Development case, highway emission rates of VOCs and PAHs were scaled up from Baseline values assuming that traffic on these highways grew at a rate of 3% per year for 25 years while the average fuel consumption rate of each vehicle decreased by 1% per year for 25 years.


December 2009

Page B4-4

2.0 INDUSTRIAL FACILITIES

2.1 Albian Sands Energy Inc. Table B4-2: Summary of Albian Sands Muskeg River Mine and

ATCO Cogeneration Facility VOC and PAH Air Emissions Used for Baseline, Project and Planned Development Scenarios

Emission Source

NW Mine Fleet/

Fugitives Lease 90 Mine Fleet/

Fugitives Tailing Pond1

Process Plant Fugitives

UTM North - NE 6,348,638 6,339,217 6,344,288 6,346,673 UTM East - NE 465,177 469,266 467,538 470,094 UTM North - SE 6,347,138 6,337,208 6,341,680 6,345,173 UTM East - SE 465,177 469,266 467,538 470,094 UTM North - SW 6,347,138 6,337,208 6,341,680 6,345,173 UTM East - SW 462,177 467,009 464,930 469,094 UTM North - NW 6,348,638 6,339,217 6,344,288 6,346,673 UTM East - NW 462,177 467,009 464,930 469,094 Area (km2) 4.5 4.53 6.802 1.5 Elevation (m) 2461 2491 284 286 1,3-Butadiene (kg/d) 1.47E-01 1.49E-01 0.00 0.00 2-MethylNaphthalene (kg/d) 0.00 0.00 0.00 1.88E-03 3-Methylcholanthrene (kg/d) 0.00 0.00 0.00 1.41E-04 7,12-Dimethylbenz(a)anthracene (kg/d) 0.00 0.00 0.00 1.25E-03 Acenaphthene (kg/d) 1.34E-02 1.36E-02 0.00 1.41E-04 Acenaphthylene (kg/d) 3.02E-02 3.07E-02 0.00 1.41E-04 Acetaldehyde (kg/d) 1.49 1.51 0.00 0.00 Acrolein (kg/d) 1.89E-01 1.92E-01 0.00 0.00 Aliphatic&C19-C34 (kg/d) 3.64 3.69 0.00 6.48 Aliphatic&C5-C8 (kg/d) 2.47E+01 2.50E+01 1.25E+05 4.47E+02 Aliphatic&C9-C18 (kg/d) 8.82E+01 8.94E+01 4.03E+03 2.64E+02 Anthracene (kg/d) 5.73E-03 5.82E-03 0.00 1.88E-04 Aromatic (kg/d) 5.05 5.11 8.52 1.23E+02 Benzene (kg/d) 3.97 4.02 5.10E+01 2.22E+01 Benzo(a)anthracene (kg/d) 3.34E-03 3.39E-03 0.00 1.41E-04 Benzo(a)pyrene (kg/d) 7.33E-04 7.43E-04 0.00 9.41E-05 Benzo(b)fluoranthene (kg/d) 2.98E-03 3.02E-03 0.00 1.41E-04 Benzo(g,h,i)perylene (kg/d) 1.69E-03 1.71E-03 0.00 9.41E-05 Benzo(k)fluoranthene (kg/d) 6.34E-04 6.43E-04 0.00 1.41E-04 Carbon Disulphide (kg/d) 6.18 6.26 7.91 2.88E-01 Carbonyl Sulphide (kg/d) 3.59E+01 3.63E+01 2.51E+01 3.15E-01 Chrysene (kg/d) 3.60E-03 3.66E-03 0.00 1.41E-04 Dibenzo(a,h)anthracene (kg/d) 1.62E-03 1.65E-03 0.00 9.41E-05 Dichlorobenzene (kg/d) 0.00 0.00 0.00 9.41E-02 Ethylbenzene (kg/d) 6.40E-01 6.48E-01 1.48E+01 1.04E+01 Fluoranthene (kg/d) 1.90E-02 1.93E-02 0.00 2.35E-04 Fluorene (kg/d) 6.97E-02 7.07E-02 0.00 2.19E-04 Formaldehyde (kg/d) 2.37 2.40 0.00 5.88 Hydrogen Sulphide (kg/d) 1.08 1.09 2.98E+01 2.23 Indeno(1,2,3-cd)pyrene (kg/d) 1.27E-03 1.29E-03 0.00 1.41E-04 Mercaptans (kg/d) 2.58E-01 2.62E-01 6.64E-02 6.38E-03 Naphthalene (kg/d) 4.92E-01 4.99E-01 0.00 4.79E-02 n-hexane (kg/d) 0.00 0.00 0.00 1.41E+02 n-pentane (kg/d) 0.00 0.00 0.00 2.04E+02 Phenanthrene (kg/d) 1.38E-01 1.40E-01 0.00 1.33E-03 Pyrene (kg/d) 1.42E-02 1.45E-02 0.00 3.92E-04 Thiophenes (kg/d) 4.13E-01 4.19E-01 5.16E+01 1.29 Toluene (kg/d) 6.59 6.68 7.34E+01 6.30E+01 Xylenes (kg/d) 5.16 5.23 9.07E+01 2.47E+01

1 Elevation sunken in to compensate for the mine pit; 1Tailings pond emissions are based on peak summer emission rates.


December 2009

Page B4-5

2.2 Birch Mountain Resources

Table B4-3: Summary of Birch Mountain Muskeg River Quarry VOC and PAH Air Emissions Used for the

Baseline and Project Scenarios Emission Source

Muskeg Valley Quarry Fleet UTM North - NE 6,338,297 UTM East - NE 466,406 UTM North - SE 6,338,047 UTM East - SE 466,406 UTM North - SW 6,338,047 UTM East - SW 466,156 UTM North - NW 6,338,297 UTM East - NW 466,156 Area (km2) 0.06 Elevation (m) 2491 1,3-Butadiene (kg/d) 1.21E-02 2-MethylNaphthalene (kg/d) 0.00 3-Methylcholanthrene (kg/d) 0.00 7,12-Dimethylbenz(a)anthracene (kg/d) 0.00 Acenaphthene (kg/d) 1.10E-03 Acenaphthylene (kg/d) 2.48E-03 Acetaldehyde (kg/d) 1.22E-01 Acrolein (kg/d) 1.55E-02 Aliphatic&C19-C34 (kg/d) 0.00 Aliphatic& C5-C8 (kg/d) 0.00 Aliphatic& C9-C18 (kg/d) 0.00 Anthracene (kg/d) 4.71E-04 Aromatic (kg/d) 0.00 Benzene (kg/d) 3.18E-01 Benzo(a)anthracene (kg/d) 2.74E-04 Benzo(a)pyrene (kg/d) 6.02E-05 Benzo(b)fluoranthene (kg/d) 2.44E-04 Benzo(g,h,i)perylene (kg/d) 1.39E-04 Benzo(k)fluoranthene (kg/d) 5.21E-05 Carbon Disulphide (kg/d) 0.00 Carbonyl Sulphide (kg/d) 0.00 Chrysene (kg/d) 2.96E-04 Dibenzo(a,h)anthracene (kg/d) 1.33E-04 Dichlorobenzene (kg/d) 0.00 Ethylbenzene (kg/d) 0.00 Fluoranthene (kg/d) 1.56E-03 Fluorene (kg/d) 5.72E-03 Formaldehyde (kg/d) 1.95E-01 Hydrogen Sulphide (kg/d) 0.00 Indeno(1,2,3-cd)pyrene (kg/d) 1.04E-04 Mercaptans (kg/d) 0.00 Naphthalene (kg/d) 3.63E-02 n-hexane (kg/d) 0.00 n-pentane (kg/d) 0.00 Phenanthrene (kg/d) 1.13E-02 Pyrene (kg/d) 1.17E-03 Thiophenes (kg/d) 0.00 Toluene (kg/d) 1.07E-01 Xylenes (kg/d) 7.43E-02

1 Elevation sunken in to compensate for the quarry pit.


December 2009

Page B4-6

Table B4-4: Summary of Birch Mountain Hammerstone Quarry VOC and PAH Air Emissions Used for the Planned Scenario

Emission Source

Emission Source Quarry 1 Fleet

Quarry 2 Fleet

Quarry 3 Fleet

Quarry 4 Fleet

South Unpaved

Haul

Paved Haul

North Unpaved

Haul UTM North - NE 6,336,369 6,336,258 6,335,683 6,335,683 6,336,916 6,340,400 6,339,239 UTM East - NE 466,800 465,954 466,198 466,767 466,723 467,015 466,903 UTM North - SE 6,336,069 6,336,069 6,335,416 6,335,416 6,334,842 6,336,916 6,339,224 UTM East - SE 466,800 465,954 466,198 466,767 466,240 466,723 466,903 UTM North - SW 6,336,069 6,336,069 6,335,416 6,335,416 6,334,842 6,336,916 6,338,985 UTM East - SW 466,500 465,765 465,931 466,500 466,225 466,708 466,314 UTM North - NW 6,336,369 6,336,258 6,335,683 6,335,683 6,336,916 6,340,400 6,339,000 UTM East - NW 466,500 465,765 465,931 466,500 466,708 467,000 466,314 Area (km2) 0.09 0.04 0.07 0.07 0.03 0.05 0.01 Elevation (m) 1 235 236 250 255 279 281 281 1,3-Butadiene (kg/d) 8.68E-03 3.47E-03 6.95E-03 6.95E-03 5.38E-03 2.03E-02 3.89E-04 2-MethylNaphthalene (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3-Methylcholanthrene (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 7,12-Dimethylbenz(a)anthracene (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Acenaphthene (kg/d) 7.91E-04 3.17E-04 6.33E-04 6.33E-04 4.91E-04 1.85E-03 3.55E-05 Acenaphthylene (kg/d) 1.79E-03 7.14E-04 1.43E-03 1.43E-03 1.11E-03 4.17E-03 8.00E-05 Acetaldehyde (kg/d) 8.80E-02 3.52E-02 7.04E-02 7.04E-02 5.46E-02 2.05E-01 3.94E-03 Acrolein (kg/d) 1.12E-02 4.46E-03 8.93E-03 8.93E-03 6.92E-03 2.61E-02 5.00E-04 Aliphatic& C19-C34 (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Aliphatic& C5-C8 (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Aliphatic& C9-C18 (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Anthracene (kg/d) 3.38E-04 1.35E-04 2.71E-04 2.71E-04 2.10E-04 7.91E-04 1.52E-05 Aromatic (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Benzene (kg/d) 2.27E-01 9.09E-02 1.82E-01 1.82E-01 1.41E-01 5.30E-01 1.02E-02 Benzo(a)anthracene (kg/d) 1.97E-04 7.89E-05 1.58E-04 1.58E-04 1.22E-04 4.60E-04 8.84E-06 Benzo(a)pyrene (kg/d) 4.33E-05 1.73E-05 3.46E-05 3.46E-05 2.68E-05 1.01E-04 1.94E-06 Benzo(b)fluoranthene (kg/d) 1.76E-04 7.03E-05 1.41E-04 1.41E-04 1.09E-04 4.10E-04 7.87E-06 Benzo(g,h,i)perylene (kg/d) 9.97E-05 3.99E-05 7.98E-05 7.98E-05 6.18E-05 2.33E-04 4.47E-06 Benzo(k)fluoranthene (kg/d) 3.74E-05 1.50E-05 2.99E-05 2.99E-05 2.32E-05 8.74E-05 1.68E-06 Carbon Disulphide (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Carbonyl Sulphide (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Chrysene (kg/d) 2.13E-04 8.51E-05 1.70E-04 1.70E-04 1.32E-04 4.97E-04 9.54E-06 Dibenzo(a,h)anthracene (kg/d) 9.58E-05 3.83E-05 7.67E-05 7.67E-05 5.94E-05 2.24E-04 4.30E-06 Dichlorobenzene (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Ethylbenzene (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Fluoranthene (kg/d) 1.12E-03 4.49E-04 8.98E-04 8.98E-04 6.96E-04 2.62E-03 5.03E-05 Fluorene (kg/d) 4.11E-03 1.65E-03 3.29E-03 3.29E-03 2.55E-03 9.61E-03 1.84E-04 Formaldehyde (kg/d) 1.40E-01 5.59E-02 1.12E-01 1.12E-01 8.67E-02 3.27E-01 6.27E-03 Hydrogen Sulphide (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Indeno(1,2,3-cd)pyrene (kg/d) 7.48E-05 2.99E-05 5.99E-05 5.99E-05 4.64E-05 1.75E-04 3.35E-06 Mercaptans (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Naphthalene (kg/d) 2.61E-02 1.05E-02 2.09E-02 2.09E-02 1.62E-02 6.11E-02 1.17E-03 n-hexane (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 n-pentane (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Phenanthrene (kg/d) 8.14E-03 3.26E-03 6.52E-03 6.52E-03 5.05E-03 1.90E-02 3.65E-04 Pyrene (kg/d) 8.41E-04 3.37E-04 6.73E-04 6.73E-04 5.22E-04 1.96E-03 3.77E-05 Thiophenes (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Toluene (kg/d) 7.67E-02 3.07E-02 6.14E-02 6.14E-02 4.76E-02 1.79E-01 3.44E-03 Xylenes (kg/d) 5.31E-02 2.13E-02 4.25E-02 4.25E-02 3.30E-02 1.24E-01 2.38E-03 1 Elevation of quarry taken from 2040 Quarry Plan.


December 2009

Page B4-7

2.3 Canadian Natural Resources Limited

Table B4-5: Summary of CNRL Horizon and Kirby VOC and PAH Air Emissions Used for the Baseline, Project and Planned Development Scenarios

Horizon Emission Source Kirby Emission

Source

Mine Fleet/ Fugitives

Tailings Pond1 Plant Fugitives Kirby Total

UTM North - NE 6,356,146 6,359,810 6,355,560 6,133,091 UTM East - NE 451,740 447,599 455,415 498,238 UTM North - SE 6,351,868 6,352,949 6,354,790 6,132,668 UTM East - SE 451,740 447,599 455,415 498,238 UTM North - SW 6,351,868 6,352,949 6,354,790 6,132,668 UTM East - SW 448,002 443,556 454,145 498,662 UTM North - NW 6,356,146 6,359,810 6,355,560 6,133,091 UTM East - NW 448,002 443,556 454,145 498,662 Area (km2) 15.991 27.74 0.978 0.180 Elevation (m) 2711 347 294 732 1,3-Butadiene (kg/d) 2.11E-01 0.00 0.00 0.00 2-MethylNaphthalene (kg/d) 0.00 0.00 1.99E-03 6.21E-04 3-Methylcholanthrene (kg/d) 0.00 0.00 1.49E-04 4.66E-05 7,12-Dimethylbenz(a)anthracene (kg/d) 0.00 0.00 1.33E-03 4.14E-04 Acenaphthene (kg/d) 1.92E-02 0.00 1.49E-04 4.66E-05 Acenaphthylene (kg/d) 4.33E-02 0.00 1.49E-04 4.66E-05 Acetaldehyde (kg/d) 2.13 0.00 0.00 0.00E+00 Acrolein (kg/d) 2.71E-01 0.00 0.00 0.00E+00 Aliphatic& C19-C34 (kg/d) 6.60 0.00 5.88 0.00 Aliphatic& C5-C8 (kg/d) 4.48E+01 1.13E+05 4.02E+02 0.00 Aliphatic& C9-C18 (kg/d) 1.60E+02 3.62E+03 2.38E+02 0.00 Anthracene (kg/d) 8.21E-03 0.00 1.99E-04 6.21E-05 Aromatic (kg/d) 9.14 7.66 1.11E+02 0.00 Benzene (kg/d) 5.72 4.59E+01 2.00E+01 5.44E-02 Benzo(a)anthracene (kg/d) 4.78E-03 0.00 1.49E-04 4.66E-05 Benzo(a)pyrene (kg/d) 1.05E-03 0.00 9.97E-05 3.11E-05 Benzo(b)fluoranthene (kg/d) 4.26E-03 0.00 1.49E-04 4.66E-05 Benzo(g,h,i)perylene (kg/d) 2.42E-03 0.00 9.97E-05 3.11E-05 Benzo(k)fluoranthene (kg/d) 9.08E-04 0.00 1.49E-04 4.66E-05 Carbon Disulphide (kg/d) 1.12E+01 7.12 2.59E-01 0.00 Carbonyl Sulphide (kg/d) 6.50E+01 2.25E+01 2.83E-01 0.00 Chrysene (kg/d) 5.16E-03 0.00 1.49E-04 4.66E-05 Dibenzo(a,h)anthracene (kg/d) 2.32E-03 0.00 9.97E-05 3.11E-05 Dichlorobenzene (kg/d) 0.00 0.00 9.97E-02 3.11E-02 Ethylbenzene (kg/d) 1.16 1.33E+01 9.42 0.00 Fluoranthene (kg/d) 2.72E-02 0.00 2.49E-04 7.77E-05 Fluorene (kg/d) 9.98E-02 0.00 2.33E-04 7.25E-05 Formaldehyde (kg/d) 3.39 0.00 6.23 1.94E+00 Hydrogen Sulphide (kg/d) 1.96 2.68E+01 2.01 0.00 Indeno(1,2,3-cd)pyrene (kg/d) 1.82E-03 0.00 1.49E-04 4.66E-05 Mercaptans (kg/d) 4.68E-01 5.98E-02 5.74E-03 0.00 Naphthalene (kg/d) 7.23E-01 0.00 5.07E-02 1.58E-02 n-hexane (kg/d) 0.00 0.00 1.50E+02 4.66E+01 n-pentane (kg/d) 0.00 0.00 2.16E+02 6.73E+01 Phenanthrene (kg/d) 1.97E-01 0.00 1.41E-03 4.40E-04 Pyrene (kg/d) 2.04E-02 0.00 4.15E-04 1.29E-04 Thiophenes (kg/d) 7.49E-01 4.64E+01 1.16 0.00 Toluene (kg/d) 1.14E+01 6.65E+01 5.67E+01 8.80E-02 Xylenes (kg/d) 9.01 8.21E+01 2.22E+01 0.00



December 2009

Page B4-8

2.4 Connacher Oil and Gas Limited

Table B4-6: Summary of Connacher VOC and PAH Air Emissions Used for the Baseline and Project Scenarios

Emission Source Great Divide SAGD UTM North - NE 6,219,300 UTM East - NE 448,800 UTM North - SE 6,218,900 UTM East - SE 448,800 UTM North - SW 6,218,900 UTM East - SW 448,400 UTM North - NW 6,219,300 UTM East - NW 448,400 Area (km2) 0.16 Elevation (m) 710 1,3-Butadiene (kg/d) 0.00E+00 2-MethylNaphthalene (kg/d) 1.38E-04 3-Methylcholanthrene (kg/d) 1.03E-05 7,12-Dimethylbenz(a)anthracene (kg/d) 9.21E-05 Acenaphthene (kg/d) 1.03E-05 Acenaphthylene (kg/d) 1.03E-05 Acetaldehyde (kg/d) 0.00E+00 Acrolein (kg/d) 0.00E+00 Aliphatic& C19-C34 (kg/d) 0.00E+00 Aliphatic& C5-C8 (kg/d) 0.00E+00 Aliphatic& C9-C18 (kg/d) 0.00E+00 Anthracene (kg/d) 1.38E-05 Aromatic (kg/d) 0.00E+00 Benzene (kg/d) 1.21E-02 Benzo(a)anthracene (kg/d) 1.03E-05 Benzo(a)pyrene (kg/d) 6.90E-06 Benzo(b)fluoranthene (kg/d) 1.03E-05 Benzo(g,h,i)perylene (kg/d) 6.90E-06 Benzo(k)fluoranthene (kg/d) 1.03E-05 Carbon Disulphide (kg/d) 0.00E+00 Carbonyl Sulphide (kg/d) 0.00E+00 Chrysene (kg/d) 1.03E-05 Dibenzo(a,h)anthracene (kg/d) 6.90E-06 Dichlorobenzene (kg/d) 6.90E-03 Ethylbenzene (kg/d) 0.00E+00 Fluoranthene (kg/d) 1.73E-05 Fluorene (kg/d) 1.61E-05 Formaldehyde (kg/d) 4.31E-01 Hydrogen Sulphide (kg/d) 0.00E+00 Indeno(1,2,3-cd)pyrene (kg/d) 1.03E-05 Mercaptans (kg/d) 0.00E+00 Naphthalene (kg/d) 3.51E-03 n-hexane (kg/d) 1.04E+01 n-pentane (kg/d) 1.50E+01 Phenanthrene (kg/d) 9.78E-05 Pyrene (kg/d) 2.88E-05 Thiophenes (kg/d) 0.00E+00 Toluene (kg/d) 1.96E-02 Xylenes (kg/d) 0.00E+00


December 2009

Page B4-9

Table B4-7: Summary of Connacher VOC and PAH Air Emissions Used for the Planned Development Scenario

Emission Source Great Divide SAGD Algar SAGD UTM North - NE 6,219,300 6,219,100 UTM East - NE 448,800 455,800 UTM North - SE 6,218,900 6,218,700 UTM East - SE 448,800 455,800 UTM North - SW 6,218,900 6,218,700 UTM East - SW 448,400 455,400 UTM North - NW 6,219,300 6,219,100 UTM East - NW 448,400 455,400 Area (km2) 0.16 0.16 Elevation (m) 710 750 1,3-Butadiene (kg/d) 0.00E+00 0.00E+00 2-MethylNaphthalene (kg/d) 1.38E-04 1.38E-04 3-Methylcholanthrene (kg/d) 1.03E-05 1.03E-05 7,12-Dimethylbenz(a)anthracene (kg/d) 9.21E-05 9.21E-05 Acenaphthene (kg/d) 1.03E-05 1.03E-05 Acenaphthylene (kg/d) 1.03E-05 1.03E-05 Acetaldehyde (kg/d) 0.00E+00 0.00E+00 Acrolein (kg/d) 0.00E+00 0.00E+00 Aliphatic& C19-C34 (kg/d) 0.00E+00 0.00E+00 Aliphatic& C5-C8 (kg/d) 0.00E+00 0.00E+00 Aliphatic& C9-C18 (kg/d) 0.00E+00 0.00E+00 Anthracene (kg/d) 1.38E-05 1.38E-05 Aromatic (kg/d) 0.00E+00 0.00E+00 Benzene (kg/d) 1.21E-02 1.21E-02 Benzo(a)anthracene (kg/d) 1.03E-05 1.03E-05 Benzo(a)pyrene (kg/d) 6.90E-06 6.90E-06 Benzo(b)fluoranthene (kg/d) 1.03E-05 1.03E-05 Benzo(g,h,i)perylene (kg/d) 6.90E-06 6.90E-06 Benzo(k)fluoranthene (kg/d) 1.03E-05 1.03E-05 Carbon Disulphide (kg/d) 0.00E+00 0.00E+00 Carbonyl Sulphide (kg/d) 0.00E+00 0.00E+00 Chrysene (kg/d) 1.03E-05 1.03E-05 Dibenzo(a,h)anthracene (kg/d) 6.90E-06 6.90E-06 Dichlorobenzene (kg/d) 6.90E-03 6.90E-03 Ethylbenzene (kg/d) 0.00E+00 0.00E+00 Fluoranthene (kg/d) 1.73E-05 1.73E-05 Fluorene (kg/d) 1.61E-05 1.61E-05 Formaldehyde (kg/d) 4.31E-01 4.31E-01 Hydrogen Sulphide (kg/d) 0.00E+00 0.00E+00 Indeno(1,2,3-cd)pyrene (kg/d) 1.03E-05 1.03E-05 Mercaptans (kg/d) 0.00E+00 0.00E+00 Naphthalene (kg/d) 3.51E-03 3.51E-03 n-hexane (kg/d) 1.04E+01 1.04E+01 n-pentane (kg/d) 1.50E+01 1.50E+01 Phenanthrene (kg/d) 9.78E-05 9.78E-05 Pyrene (kg/d) 2.88E-05 2.88E-05 Thiophenes (kg/d) 0.00E+00 0.00E+00 Toluene (kg/d) 1.96E-02 1.96E-02 Xylenes (kg/d) 0.00E+00 0.00E+00


December 2009

Page B4-10

2.5 ConocoPhillips Canada Resources Corporation

Table B4-8: Summary of ConocoPhillips Surmont VOC and PAH Air Emissions Used in the Baseline and

Project Scenarios Emission Source

Pilot and SAGD UTM North - NE 6,227,800 UTM East - NE 503,600 UTM North - SE 6,227,300 UTM East - SE 503,600 UTM North - SW 6,227,300 UTM East - SW 503,100 UTM North - NW 6,227,800 UTM East - NW 503,100 Area (km2) 0.25 Elevation (m) 642 1,3-Butadiene (kg/d) 0.00 2-MethylNaphthalene (kg/d) 3.45E-04 3-Methylcholanthrene (kg/d) 2.59E-05 7,12-Dimethylbenz(a)anthracene (kg/d) 2.30E-04 Acenaphthene (kg/d) 2.59E-05 Acenaphthylene (kg/d) 2.59E-05 Acetaldehyde (kg/d) 0.00 Acrolein (kg/d) 0.00 Aliphatic& C19-C34 (kg/d) 0.00 Aliphatic& C5-C8 (kg/d) 0.00 Aliphatic& C9-C18 (kg/d) 0.00 Anthracene (kg/d) 3.45E-05 Aromatic (kg/d) 0.00 Benzene (kg/d) 3.02E-02 Benzo(a)anthracene (kg/d) 2.59E-05 Benzo(a)pyrene (kg/d) 1.73E-05 Benzo(b)fluoranthene (kg/d) 2.59E-05 Benzo(g,h,i)perylene (kg/d) 1.73E-05 Benzo(k)fluoranthene (kg/d) 2.59E-05 Carbon Disulphide (kg/d) 0.00 Carbonyl Sulphide (kg/d) 0.00 Chrysene (kg/d) 2.59E-05 Dibenzo(a,h)anthracene (kg/d) 1.73E-05 Dichlorobenzene (kg/d) 1.73E-02 Ethylbenzene (kg/d) 0.00 Fluoranthene (kg/d) 4.32E-05 Fluorene (kg/d) 4.03E-05 Formaldehyde (kg/d) 1.08 Hydrogen Sulphide (kg/d) 0.00 Indeno(1,2,3-cd)pyrene (kg/d) 2.59E-05 Mercaptans (kg/d) 0.00 Naphthalene (kg/d) 8.81E-03 n-hexane (kg/d) 25.90 n-pentane (kg/d) 3.74E+01 Phenanthrene (kg/d) 2.45E-04 Pyrene (kg/d) 7.19E-05 Thiophenes (kg/d) 0.00 Toluene (kg/d) 4.89E-02 Xylenes (kg/d) 0.00


December 2009

Page B4-11

Table B4-9: Summary of ConocoPhillips Surmont VOC and PAH Air Emissions Used in the Planned Development Scenario

Emission Source Pilot and SAGD Surmont UTM North - NE 6,227,800 6,228,000 UTM East - NE 503,600 504,700 UTM North - SE 6,227,300 6,227,200 UTM East - SE 503,600 504,700 UTM North - SW 6,227,300 6,227,200 UTM East - SW 503,100 503,800 UTM North - NW 6,227,800 6,228,000 UTM East - NW 503,100 503,800 Area (km2) 0.25 0.72 Elevation (m) 642 620 1,3-Butadiene (kg/d) 0.00 0.00 2-MethylNaphthalene (kg/d) 3.45E-04 1.03E-03 3-Methylcholanthrene (kg/d) 2.59E-05 7.76E-05 7,12-Dimethylbenz(a)anthracene (kg/d) 2.30E-04 6.90E-04 Acenaphthene (kg/d) 2.59E-05 7.76E-05 Acenaphthylene (kg/d) 2.59E-05 7.76E-05 Acetaldehyde (kg/d) 0.00 0.00 Acrolein (kg/d) 0.00 0.00 Aliphatic& C19-C34 (kg/d) 0.00 0.00 Aliphatic& C5-C8 (kg/d) 0.00 0.00 Aliphatic& C9-C18 (kg/d) 0.00 0.00 Anthracene (kg/d) 3.45E-05 1.03E-04 Aromatic (kg/d) 0.00 0.00 Benzene (kg/d) 3.02E-02 9.07E-02 Benzo(a)anthracene (kg/d) 2.59E-05 7.76E-05 Benzo(a)pyrene (kg/d) 1.73E-05 5.17E-05 Benzo(b)fluoranthene (kg/d) 2.59E-05 7.76E-05 Benzo(g,h,i)perylene (kg/d) 1.73E-05 5.17E-05 Benzo(k)fluoranthene (kg/d) 2.59E-05 7.76E-05 Carbon Disulphide (kg/d) 0.00 0.00 Carbonyl Sulphide (kg/d) 0.00 0.00 Chrysene (kg/d) 2.59E-05 7.76E-05 Dibenzo(a,h)anthracene (kg/d) 1.73E-05 5.17E-05 Dichlorobenzene (kg/d) 1.73E-02 5.17E-02 Ethylbenzene (kg/d) 0.00 0.00 Fluoranthene (kg/d) 4.32E-05 1.29E-04 Fluorene (kg/d) 4.03E-05 1.21E-04 Formaldehyde (kg/d) 1.08 3.23 Hydrogen Sulphide (kg/d) 0.00 0.00 Indeno(1,2,3-cd)pyrene (kg/d) 2.59E-05 7.76E-05 Mercaptans (kg/d) 0.00 0.00 Naphthalene (kg/d) 8.81E-03 2.64E-02 n-hexane (kg/d) 25.90 77.60 n-pentane (kg/d) 3.74E+01 1.12E+02 Phenanthrene (kg/d) 2.45E-04 7.33E-04 Pyrene (kg/d) 7.19E-05 2.16E-04 Thiophenes (kg/d) 0.00 0.00 Toluene (kg/d) 4.89E-02 1.47E-01 Xylenes (kg/d) 0.00 0.00


December 2009

Page B4-12

2.6 Deer Creek Energy Limited

Table B4-10: Summary of DCEL Joslyn VOC and PAH Air Emissions Used for the Baseline and Project Scenarios

Emission Source SAGD Phase II

UTM North - NE 6,348,559 UTM East - NE 445,929 UTM North - SE 6,348,049 UTM East - SE 445,929 UTM North - SW 6,348,049 UTM East - SW 445,409 UTM North - NW 6,348,559 UTM East - NW 445,409 Area (km2) 0.26 Elevation (m) 348 1,3-Butadiene (kg/d) 0.00 2-MethylNaphthalene (kg/d) 1.51E-04 3-Methylcholanthrene (kg/d) 1.14E-05 7,12-Dimethylbenz(a)anthracene (kg/d) 1.01E-04 Acenaphthene (kg/d) 1.14E-05 Acenaphthylene (kg/d) 1.14E-05 Acetaldehyde (kg/d) 0.00 Acrolein (kg/d) 0.00 Aliphatic& C19-C34 (kg/d) 0.00 Aliphatic& C5-C8 (kg/d) 0.00 Aliphatic& C9-C18 (kg/d) 0.00 Anthracene (kg/d) 1.51E-05 Aromatic (kg/d) 0.00 Benzene (kg/d) 1.32E-02 Benzo(a)anthracene (kg/d) 1.14E-05 Benzo(a)pyrene (kg/d) 7.57E-06 Benzo(b)fluoranthene (kg/d) 1.14E-05 Benzo(g,h,i)perylene (kg/d) 7.57E-06 Benzo(k)fluoranthene (kg/d) 1.14E-05 Carbon Disulphide (kg/d) 0.00 Carbonyl Sulphide (kg/d) 0.00 Chrysene (kg/d) 1.14E-05 Dibenzo(a,h)anthracene (kg/d) 7.57E-06 Dichlorobenzene (kg/d) 7.57E-03 Ethylbenzene (kg/d) 0.00 Fluoranthene (kg/d) 1.89E-05 Fluorene (kg/d) 1.77E-05 Formaldehyde (kg/d) 4.73E-01 Hydrogen Sulphide (kg/d) 0.00 Indeno(1,2,3-cd)pyrene (kg/d) 1.14E-05 Mercaptans (kg/d) 0.00 Naphthalene (kg/d) 3.84E-03 n-hexane (kg/d) 1.14E+01 n-pentane (kg/d) 1.64E+01 Phenanthrene (kg/d) 1.07E-04 Pyrene (kg/d) 3.15E-05 Thiophenes (kg/d) 0.00 Toluene (kg/d) 2.14E-02 Xylenes (kg/d) 0.00


December 2009

Page B4-13

Table B4-11: Summary of DCEL Joslyn VOC and PAH Air Emissions Used for the Planned Development Scenario

Emission Source

SAGD Phase IIIa

North Mine Fleet/ Fugitives

North Mine Process Plant

Fugitives

North Mine Tailings Pond1

UTM North - NE 6,348,559 6,351,940 6,347,700 6,351,140 UTM East - NE 445,929 456,240 452,230 453,180 UTM North - SE 6,347,869 6,349,380 6,346,460 6,349,760 UTM East - SE 445,929 456,240 450,580 453,180 UTM North - SW 6,347,869 6,350,440 6,347,130 6,349,080 UTM East - SW 445,409 454,040 450,070 451,960 UTM North - NW 6,348,559 6,351,940 6,348,380 6,351,140 UTM East - NW 445,409 454,040 451,720 451,960 Area (km2) 0.36 4.47 1.75 2.1 Elevation (m) 348 2471 325 307 1,3-Butadiene (kg/d) 0.00 1.65E-01 0.00 0.00 2-MethylNaphthalene (kg/d) 3.49E-04 0.00 5.99E-04 0.00 3-Methylcholanthrene (kg/d) 2.62E-05 0.00 4.49E-05 0.00 7,12-Dimethylbenz(a)anthracene (kg/d) 2.33E-04 0.00 3.99E-04 0.00 Acenaphthene (kg/d) 2.62E-05 1.51E-02 4.49E-05 0.00 Acenaphthylene (kg/d) 2.62E-05 3.40E-02 4.49E-05 0.00 Acetaldehyde (kg/d) 0.00 1.68 0.00 0.00 Acrolein (kg/d) 0.00 2.13E-01 0.00 0.00 Aliphatic& C19-C34 (kg/d) 0.00 2.45 2.17 0.00 Aliphatic& C5-C8 (kg/d) 0.00 1.66E+01 1.49E+02 4.18E+04 Aliphatic& C9-C18 (kg/d) 0.00 5.92E+01 8.80E+01 1.34E+03 Anthracene (kg/d) 3.49E-05 6.45E-03 5.99E-05 0.00 Aromatic (kg/d) 0.00 3.39 4.10E+01 2.84 Benzene (kg/d) 3.05E-02 4.41 7.40 1.70E+01 Benzo(a)anthracene (kg/d) 2.62E-05 3.76E-03 4.49E-05 0.00 Benzo(a)pyrene (kg/d) 1.74E-05 8.25E-04 3.00E-05 0.00 Benzo(b)fluoranthene (kg/d) 2.62E-05 3.35E-03 4.49E-05 0.00 Benzo(g,h,i)perylene (kg/d) 1.74E-05 1.90E-03 3.00E-05 0.00 Benzo(k)fluoranthene (kg/d) 2.62E-05 7.13E-04 4.49E-05 0.00 Carbon Disulphide (kg/d) 0.00 4.15 9.59E-02 2.64 Carbonyl Sulphide (kg/d) 0.00 2.41E+01 1.05E-01 8.64 Chrysene (kg/d) 2.62E-05 4.06E-03 4.49E-05 0.00 Dibenzo(a,h)anthracene (kg/d) 1.74E-05 1.83E-03 3.00E-05 0.00 Dichlorobenzene (kg/d) 1.74E-02 0.00 3.00E-02 0.00 Ethylbenzene (kg/d) 0.00 4.29E-01 3.48 4.92 Fluoranthene (kg/d) 4.36E-05 2.14E-02 7.49E-05 0.00 Fluorene (kg/d) 4.07E-05 7.84E-02 6.99E-05 0.00 Formaldehyde (kg/d) 1.09 2.66 1.87 0.00 Hydrogen Sulphide (kg/d) 0.00 7.25E-01 7.44E-01 9.92 Indeno(1,2,3-cd)pyrene (kg/d) 2.62E-05 1.43E-03 4.49E-05 0.00 Mercaptans (kg/d) 0.00 1.74E-01 2.13E-03 2.21E-02 Naphthalene (kg/d) 8.86E-03 5.31E-01 1.52E-02 0.00 n-hexane (kg/d) 2.62E+01 0.00 4.49E+01 0.00 n-pentane (kg/d) 3.78E+01 0.00 6.49E+01 0.00 Phenanthrene (kg/d) 2.47E-04 1.55E-01 4.24E-04 0.00 Pyrene (kg/d) 7.27E-05 1.60E-02 1.25E-04 0.00 Thiophenes (kg/d) 0.00 2.77E-01 4.31E-01 1.72E+01 Toluene (kg/d) 4.94E-02 5.01 2.10E+01 2.42E+01 Xylenes (kg/d) 0.00 3.87 8.24 3.02E+01



December 2009

Page B4-14

2.7 Devon Energy Corp.

Table B4-12: Summary of Devon VOC and PAH Air Emissions Used for the Baseline, and Project Scenarios

Emission Source Point Source Jackfish 1 Total

UTM North - NE 6,133,091 UTM East - NE 498,238 UTM North - SE 6,132,668 UTM East - SE 498,238 UTM North - SW 6,132,668 UTM East - SW 498,662 UTM North - NW 6,133,091 UTM East - NW 498,662 Area (km2) 0.180 Elevation (m) 732 1,3-Butadiene (kg/d) 0.00 2-MethylNaphthalene (kg/d) 4.83E-04 3-Methylcholanthrene (kg/d) 3.62E-05 7,12-Dimethylbenz(a)anthracene (kg/d) 3.22E-04 Acenaphthene (kg/d) 3.62E-05 Acenaphthylene (kg/d) 3.62E-05 Acetaldehyde (kg/d) 0.00 Acrolein (kg/d) 0.00 Aliphatic& C19-C34 (kg/d) 0.00 Aliphatic& C5-C8 (kg/d) 0.00 Aliphatic& C9-C18 (kg/d) 0.00 Anthracene (kg/d) 4.83E-05 Aromatic (kg/d) 0.00 Benzene (kg/d) 4.23E-02 Benzo(a)anthracene (kg/d) 3.62E-05 Benzo(a)pyrene (kg/d) 2.42E-05 Benzo(b)fluoranthene (kg/d) 3.62E-05 Benzo(g,h,i)perylene (kg/d) 2.42E-05 Benzo(k)fluoranthene (kg/d) 3.62E-05 Carbon Disulphide (kg/d) 0.00 Carbonyl Sulphide (kg/d) 0.00 Chrysene (kg/d) 3.62E-05 Dibenzo(a,h)anthracene (kg/d) 2.42E-05 Dichlorobenzene (kg/d) 2.42E-02 Ethylbenzene (kg/d) 0.00 Fluoranthene (kg/d) 6.04E-05 Fluorene (kg/d) 5.64E-05 Formaldehyde (kg/d) 1.51E+00 Hydrogen Sulphide (kg/d) 0.00 Indeno(1,2,3-cd)pyrene (kg/d) 3.62E-05 Mercaptans (kg/d) 0.00 Naphthalene (kg/d) 1.23E-02 n-hexane (kg/d) 3.63E+01 n-pentane (kg/d) 5.24E+01 Phenanthrene (kg/d) 3.42E-04 Pyrene (kg/d) 1.01E-04 Thiophenes (kg/d) 0.00 Toluene (kg/d) 6.85E-02 Xylenes (kg/d) 0.00


December 2009

Page B4-15

Table B4-13: Summary of Devon VOC and PAH Air Emissions

Used for the Planned Development Scenario Emission Source Emission Source Point Source Jackfish 1 Total Jackfish 2 Total

UTM North - NE 6,133,091 6,133,091 UTM East - NE 498,238 498,238 UTM North - SE 6,132,668 6,132,668 UTM East - SE 498,238 498,238 UTM North - SW 6,132,668 6,132,668 UTM East - SW 498,662 498,662 UTM North - NW 6,133,091 6,133,091 UTM East - NW 498,662 498,662 Area (km2) 0.180 0.180 Elevation (m) 732 732 1,3-Butadiene (kg/d) 0.00 0.00 2-MethylNaphthalene (kg/d) 4.83E-04 4.83E-04 3-Methylcholanthrene (kg/d) 3.62E-05 3.62E-05 7,12-Dimethylbenz(a)anthracene (kg/d) 3.22E-04 3.22E-04 Acenaphthene (kg/d) 3.62E-05 3.62E-05 Acenaphthylene (kg/d) 3.62E-05 3.62E-05 Acetaldehyde (kg/d) 0.00 0.00 Acrolein (kg/d) 0.00 0.00 Aliphatic& C19-C34 (kg/d) 0.00 0.00 Aliphatic& C5-C8 (kg/d) 0.00 0.00 Aliphatic& C9-C18 (kg/d) 0.00 0.00 Anthracene (kg/d) 4.83E-05 4.83E-05 Aromatic (kg/d) 0.00 0.00 Benzene (kg/d) 4.23E-02 4.23E-02 Benzo(a)anthracene (kg/d) 3.62E-05 3.62E-05 Benzo(a)pyrene (kg/d) 2.42E-05 2.42E-05 Benzo(b)fluoranthene (kg/d) 3.62E-05 3.62E-05 Benzo(g,h,i)perylene (kg/d) 2.42E-05 2.42E-05 Benzo(k)fluoranthene (kg/d) 3.62E-05 3.62E-05 Carbon Disulphide (kg/d) 0.00 0.00 Carbonyl Sulphide (kg/d) 0.00 0.00 Chrysene (kg/d) 3.62E-05 3.62E-05 Dibenzo(a,h)anthracene (kg/d) 2.42E-05 2.42E-05 Dichlorobenzene (kg/d) 2.42E-02 2.42E-02 Ethylbenzene (kg/d) 0.00 0.00 Fluoranthene (kg/d) 6.04E-05 6.04E-05 Fluorene (kg/d) 5.64E-05 5.64E-05 Formaldehyde (kg/d) 1.51E+00 1.51E+00 Hydrogen Sulphide (kg/d) 0.00 0.00 Indeno(1,2,3-cd)pyrene (kg/d) 3.62E-05 3.62E-05 Mercaptans (kg/d) 0.00 0.00 Naphthalene (kg/d) 1.23E-02 1.23E-02 n-hexane (kg/d) 3.63E+01 3.63E+01 n-pentane (kg/d) 5.24E+01 5.24E+01 Phenanthrene (kg/d) 3.42E-04 3.42E-04 Pyrene (kg/d) 1.01E-04 1.01E-04 Thiophenes (kg/d) 0.00 0.00 Toluene (kg/d) 6.85E-02 6.85E-02 Xylenes (kg/d) 0.00 0.00


December 2009

Page B4-16

2.8 EnCana Corporation

Table B4-14: Summary of EnCana VOC and PAH Air Emissions Used for the Baseline and Project Scenarios

EnCana Emission Source Christina Lake Foster Creek



December 2009

Page B4-17

Table B4-15: Summary of EnCana VOC and PAH Air Emissions Used for the Planned Development Scenario

EnCana Emission Source Christina Lake Foster Creek Borealis UTM North - NE 6,159,911 6,103,904 6,337,300 UTM East - NE 507,318 530,534 538,000 UTM North - SE 6,158,548 6,101,743 6,336,500 UTM East - SE 507,318 530,534 538,000 UTM North - SW 6,158,548 6,101,743 6,336,500 UTM East - SW 506,062 528,591 537,500 UTM North - NW 6,159,911 6,103,904 6,337,300 UTM East - NW 506,062 528,591 537,500 Area (km2) 0.100 0.100 0.400 Elevation (m) 580 671 510 1,3-Butadiene (kg/d) 0.00 0.00 0.00 2-MethylNaphthalene (kg/d) 1.36E-03 1.66E-03 3.18E-04 3-Methylcholanthrene (kg/d) 1.02E-04 1.24E-04 2.38E-05 7,12-Dimethylbenz(a)anthracene (kg/d) 9.10E-04 1.10E-03 2.12E-04 Acenaphthene (kg/d) 1.02E-04 1.24E-04 2.38E-05 Acenaphthylene (kg/d) 1.02E-04 1.24E-04 2.38E-05 Acetaldehyde (kg/d) 0.00 0.00 0.00 Acrolein (kg/d) 0.00 0.00 0.00 Aliphatic& C19-C34 (kg/d) 0.00 0.00 0.00 Aliphatic& C5-C8 (kg/d) 0.00 0.00 0.00 Aliphatic& C9-C18 (kg/d) 0.00 0.00 0.00 Anthracene (kg/d) 1.36E-04 1.66E-04 3.18E-05 Aromatic (kg/d) 0.00 0.00 0.00 Benzene (kg/d) 1.19E-01 1.45E-01 2.78E-02 Benzo(a)anthracene (kg/d) 1.02E-04 1.24E-04 2.38E-05 Benzo(a)pyrene (kg/d) 6.82E-05 8.29E-05 1.59E-05 Benzo(b)fluoranthene (kg/d) 1.02E-04 1.24E-04 2.38E-05 Benzo(g,h,i)perylene (kg/d) 6.82E-05 8.29E-05 1.59E-05 Benzo(k)fluoranthene (kg/d) 1.02E-04 1.24E-04 2.38E-05 Carbon Disulphide (kg/d) 0.00 0.00 0.00 Carbonyl Sulphide (kg/d) 0.00 0.00 0.00 Chrysene (kg/d) 1.02E-04 1.24E-04 2.38E-05 Dibenzo(a,h)anthracene (kg/d) 6.82E-05 8.29E-05 1.59E-05 Dichlorobenzene (kg/d) 6.82E-02 8.29E-02 1.59E-02 Ethylbenzene (kg/d) 0.00 0.00 0.00 Fluoranthene (kg/d) 1.71E-04 2.07E-04 3.97E-05 Fluorene (kg/d) 1.59E-04 1.93E-04 3.71E-05 Formaldehyde (kg/d) 4.26E+00 5.18E+00 9.93E-01 Hydrogen Sulphide (kg/d) 0.00 0.00 0.00 Indeno(1,2,3-cd)pyrene (kg/d) 1.02E-04 1.24E-04 2.38E-05 Mercaptans (kg/d) 0.00 0.00 0.00 Naphthalene (kg/d) 3.47E-02 4.21E-02 8.08E-03 n-hexane (kg/d) 1.02E+02 1.24E+02 2.38E+01 n-pentane (kg/d) 1.48E+02 1.80E+02 3.44E+01 Phenanthrene (kg/d) 9.66E-04 1.17E-03 2.25E-04 Pyrene (kg/d) 2.84E-04 3.45E-04 6.62E-05 Thiophenes (kg/d) 0.00 0.00 0.00 Toluene (kg/d) 1.93E-01 2.35E-01 4.50E-02 Xylenes (kg/d) 0.00 0.00 0.00


December 2009

Page B4-18

2.9 Husky Energy

Table B4-16: Summary of Husky Sunrise VOC and PAH Air Emissions Used for

Baseline, Project and Planned Development Scenarios Emission Source

Sunrise SAGD Facility UTM North - NE 6,344,600 UTM East - NE 496,900 UTM North - SE 6,343,600 UTM East - SE 496,900 UTM North - SW 6,343,600 UTM East - SW 495,800 UTM North - NW 6,344,600 UTM East - NW 495,800 Area (km2) 1.100 Elevation (m) 486 1,3-Butadiene (kg/d) 0.00 2-MethylNaphthalene (kg/d) 2.77E-03 3-Methylcholanthrene (kg/d) 2.07E-04 7,12-Dimethylbenz(a)anthracene (kg/d) 1.84E-03 Acenaphthene (kg/d) 2.07E-04 Acenaphthylene (kg/d) 2.07E-04 Acetaldehyde (kg/d) 0.00 Acrolein (kg/d) 0.00 Aliphatic& C19-C34 (kg/d) 0.00 Aliphatic& C5-C8 (kg/d) 0.00 Aliphatic& C9-C18 (kg/d) 0.00 Anthracene (kg/d) 2.77E-04 Aromatic (kg/d) 0.00 Benzene (kg/d) 2.42E-01 Benzo(a)anthracene (kg/d) 2.07E-04 Benzo(a)pyrene (kg/d) 1.38E-04 Benzo(b)fluoranthene (kg/d) 2.07E-04 Benzo(g,h,i)perylene (kg/d) 1.38E-04 Benzo(k)fluoranthene (kg/d) 2.07E-04 Carbon Disulphide (kg/d) 0.00 Carbonyl Sulphide (kg/d) 0.00 Chrysene (kg/d) 2.07E-04 Dibenzo(a,h)anthracene (kg/d) 1.38E-04 Dichlorobenzene (kg/d) 1.38E-01 Ethylbenzene (kg/d) 0.00 Fluoranthene (kg/d) 3.46E-04 Fluorene (kg/d) 3.23E-04 Formaldehyde (kg/d) 8.64 Hydrogen Sulphide (kg/d) 0.00 Indeno(1,2,3-cd)pyrene (kg/d) 2.07E-04 Mercaptans (kg/d) 0.00 Naphthalene (kg/d) 7.02E-02 n-hexane (kg/d) 2.07E+02 n-pentane (kg/d) 2.99E+02 Phenanthrene (kg/d) 1.96E-03 Pyrene (kg/d) 5.76E-04 Thiophenes (kg/d) 0.00 Toluene (kg/d) 0.39 Xylenes (kg/d) 0.00


December 2009

Page B4-19

2.10 Imperial Oil / ExxonMobil

Table B4-17: Summary of IOL / ExxonMobil Kearl Mine VOC and PAH Air Emissions Used for Baseline, Project and Planned Development Scenarios

Emission Source

Mine Fleet/ Fugitives North 1





Tailings Pond1

Process Plant

Fugitives

UTM North - NE 6,365,143 6,363,942 6,362,440 6,360,629 6,358,833 6,366,091 6,362,500 UTM East - NE 490,112 492,409 494,388 495,509 495,509 499,117 496,500 UTM North - SE 6,361,857 6,360,885 6,360,726 6,359,006 6,356,496 6,362,866 6,361,500 UTM East - SE 490,042 492,356 494,582 495,578 494,059 499,173 496,500 UTM North - SW 6,361,839 6,360,903 6,360,762 6,358,925 6,356,404 6,362,754 6,361,500 UTM East - SW 489,229 490,165 492,710 490,698 491,492 494,246 495,000 UTM North - NW 6,365,143 6,363,871 6,362,546 6,360,560 6,358,775 6,366,023 6,362,500 UTM East - NW 489,088 490,130 492,692 490,606 491,423 492,298 495,000 Area (km2) 3.03 6.73 3.11 7.97 7.78 19.16 1.5 Elevation (m) 2461 2611 2901 2711 2841 354 372 1,3-Butadiene (kg/d) 4.31E-02 9.56E-02 4.41E-02 1.13E-01 1.10E-01 0.00 0.00 2-MethylNaphthalene (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 1.28E-03 3-Methylcholanthrene (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 9.59E-05 7,12-Dimethylbenz(a)anthracene (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 8.53E-04 Acenaphthene (kg/d) 3.92E-03 8.71E-03 4.02E-03 1.03E-02 1.01E-02 0.00 9.59E-05 Acenaphthylene (kg/d) 8.86E-03 1.97E-02 9.07E-03 2.32E-02 2.27E-02 0.00 9.59E-05 Acetaldehyde (kg/d) 4.36E-01 9.69E-01 4.47E-01 1.14 1.12 0.00 0.00 Acrolein (kg/d) 5.53E-02 1.23E-01 5.67E-02 1.45E-01 1.42E-01 0.00 0.00 Aliphatic& C19-C34 (kg/d) 7.76E-01 1.72 7.97E-01 2.04 1.99 0.00 6.48 Aliphatic& C5-C8 (kg/d) 5.26 1.17E+01 5.41 1.39E+01 1.35E+01 1.25E+05 4.47E+02 Aliphatic& C9-C18 (kg/d) 1.88E+01 4.18E+01 1.93E+01 4.95E+01 4.82E+01 4.03E+03 2.64E+02 Anthracene (kg/d) 1.68E-03 3.73E-03 1.72E-03 4.40E-03 4.30E-03 0.00 1.28E-04 Aromatic (kg/d) 1.07 2.39 1.11 2.83 2.76 8.52 1.23E+02 Benzene (kg/d) 1.15 2.55 1.18 3.02 2.95 5.10E+01 2.22E+01 Benzo(a)anthracene (kg/d) 9.78E-04 2.17E-03 1.00E-03 2.56E-03 2.50E-03 0.00 9.59E-05 Benzo(a)pyrene (kg/d) 2.15E-04 4.76E-04 2.20E-04 5.63E-04 5.50E-04 0.00 6.40E-05 Benzo(b)fluoranthene (kg/d) 8.71E-04 1.93E-03 8.93E-04 2.28E-03 2.23E-03 0.00 9.59E-05 Benzo(g,h,i)perylene (kg/d) 4.95E-04 1.10E-03 5.07E-04 1.30E-03 1.27E-03 0.00 6.40E-05 Benzo(k)fluoranthene (kg/d) 1.86E-04 4.12E-04 1.90E-04 4.87E-04 4.75E-04 0.00 9.59E-05 Carbon Disulphide (kg/d) 1.32 2.92 1.35 3.46 3.38 7.91 2.88E-01 Carbonyl Sulphide (kg/d) 7.64 1.70E+01 7.85 2.01E+01 1.96E+01 2.51E+01 3.15E-01 Chrysene (kg/d) 1.06E-03 2.34E-03 1.08E-03 2.77E-03 2.70E-03 0.00 9.59E-05 Dibenzo(a,h)anthracene (kg/d) 4.75E-04 1.06E-03 4.87E-04 1.25E-03 1.22E-03 0.00 6.40E-05 Dichlorobenzene (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 6.40E-02 Ethylbenzene (kg/d) 1.37E-01 3.03E-01 1.40E-01 3.59E-01 3.50E-01 1.48E+01 1.05E+01 Fluoranthene (kg/d) 5.57E-03 1.24E-02 5.70E-03 1.46E-02 1.43E-02 0.00 1.60E-04 Fluorene (kg/d) 2.04E-02 4.53E-02 2.09E-02 5.35E-02 5.23E-02 0.00 1.49E-04 Formaldehyde (kg/d) 6.94E-01 1.54 7.11E-01 1.82 1.78 0.00 4.00 Hydrogen Sulphide (kg/d) 2.30E-01 5.11E-01 2.37E-01 6.06E-01 5.91E-01 2.98E+01 2.23 Indeno(1,2,3-cd)pyrene (kg/d) 3.71E-04 8.24E-04 3.80E-04 9.73E-04 9.51E-04 0.00 9.59E-05 Mercaptans (kg/d) 5.53E-02 1.23E-01 5.62E-02 1.45E-01 1.42E-01 6.64E-02 6.38E-03 Naphthalene (kg/d) 1.39E-01 3.10E-01 1.43E-01 3.68E-01 3.59E-01 0.00 3.26E-02 n-hexane (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 9.59E+01 n-pentane (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 1.39E+02 Phenanthrene (kg/d) 4.04E-02 8.96E-02 4.14E-02 1.06E-01 1.03E-01 0.00 9.06E-04 Pyrene (kg/d) 4.17E-03 9.26E-03 4.27E-03 1.09E-02 1.07E-02 0.00 2.66E-04 Thiophenes (kg/d) 8.81E-02 1.95E-01 9.07E-02 2.32E-01 2.26E-01 5.16E+01 1.29 Toluene (kg/d) 1.51 3.35 1.55 3.97 3.87 7.34E+01 6.30E+01 Xylenes (kg/d) 1.17 2.60 1.20 3.08 3.01 9.07E+01 2.47E+01



December 2009

Page B4-20

2.11 Japan Canada Oil Sands

Table B4-18: Summary of JACOS Hangingstone VOC and PAH Air Emissions Used for the Baseline

and Project Scenarios Emission Source

Demo SAGD Facility UTM North - NE 6,241,846 UTM East - NE 460,813 UTM North - SE 6,241,402 UTM East - SE 460,813 UTM North - SW 6,241,402 UTM East - SW 460,340 UTM North - NW 6,241,846 UTM East - NW 460,340 Area (km2) 0.21 Elevation (m) 563 1,3-Butadiene (kg/d) 0.00 2-MethylNaphthalene (kg/d) 1.52E-04 3-Methylcholanthrene (kg/d) 1.14E-05 7,12-Dimethylbenz(a)anthracene (kg/d) 1.02E-04 Acenaphthene (kg/d) 1.14E-05 Acenaphthylene (kg/d) 1.14E-05 Acetaldehyde (kg/d) 0.00 Acrolein (kg/d) 0.00 Aliphatic& C19-C34 (kg/d) 0.00 Aliphatic& C5-C8 (kg/d) 0.00 Aliphatic& C9-C18 (kg/d) 0.00 Anthracene (kg/d) 1.52E-05 Aromatic (kg/d) 0.00 Benzene (kg/d) 1.33E-02 Benzo(a)anthracene (kg/d) 1.14E-05 Benzo(a)pyrene (kg/d) 7.62E-06 Benzo(b)fluoranthene (kg/d) 1.14E-05 Benzo(g,h,i)perylene (kg/d) 7.62E-06 Benzo(k)fluoranthene (kg/d) 1.14E-05 Carbon Disulphide (kg/d) 0.00 Carbonyl Sulphide (kg/d) 0.00 Chrysene (kg/d) 1.14E-05 Dibenzo(a,h)anthracene (kg/d) 7.62E-06 Dichlorobenzene (kg/d) 7.62E-03 Ethylbenzene (kg/d) 0.00 Fluoranthene (kg/d) 1.90E-05 Fluorene (kg/d) 1.78E-05 Formaldehyde (kg/d) 4.76E-01 Hydrogen Sulphide (kg/d) 0.00 Indeno(1,2,3-cd)pyrene (kg/d) 1.14E-05 Mercaptans (kg/d) 0.00 Naphthalene (kg/d) 3.86E-03 n-hexane (kg/d) 1.14E+01 n-pentane (kg/d) 1.65E+01 Phenanthrene (kg/d) 1.08E-04 Pyrene (kg/d) 3.17E-05 Thiophenes (kg/d) 0.00 Toluene (kg/d) 2.15E-02 Xylenes (kg/d) 0.00


December 2009

Page B4-21

Table B4-19: Summary of JACOS Hangingstone VOC

and PAH Air Emissions Used for the Planned Development Scenario Emission Source

Demo SAGD Facility Commercial SAGD Plant UTM North - NE 6,241,846 6,239,346 UTM East - NE 460,813 459,836 UTM North - SE 6,241,402 6,238,846 UTM East - SE 460,813 459,836 UTM North - SW 6,241,402 6,238,846 UTM East - SW 460,340 459,336 UTM North - NW 6,241,846 6,239,346 UTM East - NW 460,340 459,336 Area (km2) 0.21 0.25 Elevation (m) 563 580 1,3-Butadiene (kg/d) 0.00 0.00 2-MethylNaphthalene (kg/d) 1.52E-04 4.84E-04 3-Methylcholanthrene (kg/d) 1.14E-05 3.62E-05 7,12-Dimethylbenz(a)anthracene (kg/d) 1.02E-04 3.22E-04 Acenaphthene (kg/d) 1.14E-05 3.62E-05 Acenaphthylene (kg/d) 1.14E-05 3.62E-05 Acetaldehyde (kg/d) 0.00 0.00 Acrolein (kg/d) 0.00 0.00 Aliphatic& C19-C34 (kg/d) 0.00 0.00 Aliphatic& C5-C8 (kg/d) 0.00 0.00 Aliphatic& C9-C18 (kg/d) 0.00 0.00 Anthracene (kg/d) 1.52E-05 4.84E-05 Aromatic (kg/d) 0.00 0.00 Benzene (kg/d) 1.33E-02 4.23E-02 Benzo(a)anthracene (kg/d) 1.14E-05 3.62E-05 Benzo(a)pyrene (kg/d) 7.62E-06 2.42E-05 Benzo(b)fluoranthene (kg/d) 1.14E-05 3.62E-05 Benzo(g,h,i)perylene (kg/d) 7.62E-06 2.42E-05 Benzo(k)fluoranthene (kg/d) 1.14E-05 3.62E-05 Carbon Disulphide (kg/d) 0.00 0.00 Carbonyl Sulphide (kg/d) 0.00 0.00 Chrysene (kg/d) 1.14E-05 3.62E-05 Dibenzo(a,h)anthracene (kg/d) 7.62E-06 2.42E-05 Dichlorobenzene (kg/d) 7.62E-03 2.42E-02 Ethylbenzene (kg/d) 0.00 0.00 Fluoranthene (kg/d) 1.90E-05 6.04E-05 Fluorene (kg/d) 1.78E-05 5.64E-05 Formaldehyde (kg/d) 4.76E-01 1.51 Hydrogen Sulphide (kg/d) 0.00 0.00 Indeno(1,2,3-cd)pyrene (kg/d) 1.14E-05 3.62E-05 Mercaptans (kg/d) 0.00 0.00 Naphthalene (kg/d) 3.86E-03 1.23E-02 n-hexane (kg/d) 1.14E+01 3.63E+01 n-pentane (kg/d) 1.65E+01 5.24E+01 Phenanthrene (kg/d) 1.08E-04 3.42E-04 Pyrene (kg/d) 3.17E-05 1.01E-04 Thiophenes (kg/d) 0.00 0.00 Toluene (kg/d) 2.15E-02 6.85E-02 Xylenes (kg/d) 0.00 0.00


December 2009

Page B4-22

2.12 MEG Energy Corporation

Table B4-20: Summary of OPTI/Nexen long Lake VOC and PAH Air Emissions Used for the Baseline and Project Scenarios

Emission Source MEG Phases 1 & 2

UTM North - NE 6,170,528 UTM East - NE 520,590 UTM North - SE 6,167,978 UTM East - SE 520,590 UTM North - SW 6,167,978 UTM East - SW 517,651 UTM North - NW 6,170,528 UTM East - NW 517,651 Area (km2) 0.100 Elevation (m) 601 1,3-Butadiene (kg/d) 0.00 2-MethylNaphthalene (kg/d) 8.29E-04 3-Methylcholanthrene (kg/d) 6.21E-05 7,12-Dimethylbenz(a)anthracene (kg/d) 5.52E-04 Acenaphthene (kg/d) 6.21E-05 Acenaphthylene (kg/d) 6.21E-05 Acetaldehyde (kg/d) 0.00 Acrolein (kg/d) 0.00 Aliphatic& C19-C34 (kg/d) 0.00 Aliphatic& C5-C8 (kg/d) 0.00 Aliphatic& C9-C18 (kg/d) 0.00 Anthracene (kg/d) 8.29E-05 Aromatic (kg/d) 0.00 Benzene (kg/d) 7.25E-02 Benzo(a)anthracene (kg/d) 6.21E-05 Benzo(a)pyrene (kg/d) 4.14E-05 Benzo(b)fluoranthene (kg/d) 6.21E-05 Benzo(g,h,i)perylene (kg/d) 4.14E-05 Benzo(k)fluoranthene (kg/d) 6.21E-05 Carbon Disulphide (kg/d) 0.00 Carbonyl Sulphide (kg/d) 0.00 Chrysene (kg/d) 6.21E-05 Dibenzo(a,h)anthracene (kg/d) 4.14E-05 Dichlorobenzene (kg/d) 4.14E-02 Ethylbenzene (kg/d) 0.00 Fluoranthene (kg/d) 1.04E-04 Fluorene (kg/d) 9.67E-05 Formaldehyde (kg/d) 2.59E+00 Hydrogen Sulphide (kg/d) 0.00 Indeno(1,2,3-cd)pyrene (kg/d) 6.21E-05 Mercaptans (kg/d) 0.00 Naphthalene (kg/d) 2.11E-02 n-hexane (kg/d) 6.21E+01 n-pentane (kg/d) 8.98E+01 Phenanthrene (kg/d) 5.87E-04 Pyrene (kg/d) 1.73E-04 Thiophenes (kg/d) 0.00 Toluene (kg/d) 1.17E-01 Xylenes (kg/d) 0.00


December 2009

Page B4-23

Table B4-21: Summary of OPTI/Nexen long Lake VOC and PAH Air Emissions Used for the Planned Development Scenario

Emission Source MEG Phases 1 & 2 MEG Phase 3



December 2009

Page B4-24

2.13 OPTI Canada/Nexen Canada Limited

Table B4-22: Summary of OPTI/Nexen long Lake VOC and PAH Air Emissions Used for the Baseline and Project Scenarios

Emission Source Long Lake

Upgrader Plant Long Lake

SAGD UTM North - NE 6,251,800 6,251,800 UTM East - NE 504,100 504,100 UTM North - SE 6,250,800 6,250,800 UTM East - SE 504,100 504,100 UTM North - SW 6,250,800 6,250,800 UTM East - SW 502,700 502,700 UTM North - NW 6,251,800 6,251,800 UTM East - NW 502,700 502,700 Area (km2) 1.4 1.4 Elevation (m) 501 501 1,3-Butadiene (kg/d) 0.00 0.00E+00 2-MethylNaphthalene (kg/d) 1.03E-03 9.67E-04 3-Methylcholanthrene (kg/d) 7.76E-05 7.25E-05 7,12-Dimethylbenz(a)anthracene (kg/d) 6.90E-04 6.45E-04 Acenaphthene (kg/d) 7.76E-05 7.25E-05 Acenaphthylene (kg/d) 7.76E-05 7.25E-05 Acetaldehyde (kg/d) 0.00 0.00E+00 Acrolein (kg/d) 0.00 0.00E+00 Aliphatic& C19-C34 (kg/d) 3.02 0.00E+00 Aliphatic& C5-C8 (kg/d) 2.09E+02 0.00E+00 Aliphatic& C9-C18 (kg/d) 1.23E+02 0.00E+00 Anthracene (kg/d) 1.03E-04 9.67E-05 Aromatic (kg/d) 5.75E+01 0.00E+00 Benzene (kg/d) 1.04E+01 8.46E-02 Benzo(a)anthracene (kg/d) 7.76E-05 7.25E-05 Benzo(a)pyrene (kg/d) 5.17E-05 4.83E-05 Benzo(b)fluoranthene (kg/d) 7.76E-05 7.25E-05 Benzo(g,h,i)perylene (kg/d) 5.17E-05 4.83E-05 Benzo(k)fluoranthene (kg/d) 7.76E-05 7.25E-05 Carbon Disulphide (kg/d) 1.34E-01 0.00E+00 Carbonyl Sulphide (kg/d) 1.47E-01 0.00E+00 Chrysene (kg/d) 7.76E-05 7.25E-05 Dibenzo(a,h)anthracene (kg/d) 5.17E-05 4.83E-05 Dichlorobenzene (kg/d) 5.17E-02 4.83E-02 Ethylbenzene (kg/d) 4.87 0.00E+00 Fluoranthene (kg/d) 1.29E-04 1.21E-04 Fluorene (kg/d) 1.21E-04 1.13E-04 Formaldehyde (kg/d) 3.23 3.02E+00 Hydrogen Sulphide (kg/d) 1.04 0.00E+00 Indeno(1,2,3-cd)pyrene (kg/d) 7.76E-05 7.25E-05 Mercaptans (kg/d) 2.98E-03 0.00E+00 Naphthalene (kg/d) 2.63E-02 2.46E-02 n-hexane (kg/d) 7.76E+01 7.25E+01 n-pentane (kg/d) 1.12E+02 1.05E+02 Phenanthrene (kg/d) 7.33E-04 6.85E-04 Pyrene (kg/d) 2.16E-04 2.01E-04 Thiophenes (kg/d) 6.03E-01 0.00E+00 Toluene (kg/d) 2.94E+01 1.37E-01 Xylenes (kg/d) 1.15E+01 0.00E+00


December 2009

Page B4-25

Table B4-23: Summary of OPTI/Nexen Long Lake VOC and PAH Air Emissions Used for the Planned Development Scenario

Emission Source Long Lake

Upgrader Plant Long Lake

SAGD Long Lake South

SAGD UTM North - NE 6,251,800 6,251,800 6,240,800 UTM East - NE 504,100 504,100 501,700 UTM North - SE 6,250,800 6,250,800 6,239,400 UTM East - SE 504,100 504,100 501,700 UTM North - SW 6,250,800 6,250,800 6,239,400 UTM East - SW 502,700 502,700 500,400 UTM North - NW 6,251,800 6,251,800 6,240,800 UTM East - NW 502,700 502,700 500,400 Area (km2) 1.4 1.4 1.82 Elevation (m) 501 501 520 1,3-Butadiene (kg/d) 0.00 0.00E+00 0.00E+00 2-MethylNaphthalene (kg/d) 1.03E-03 9.67E-04 9.67E-04 3-Methylcholanthrene (kg/d) 7.76E-05 7.25E-05 7.25E-05 7,12-Dimethylbenz(a)anthracene (kg/d) 6.90E-04 6.45E-04 6.45E-04 Acenaphthene (kg/d) 7.76E-05 7.25E-05 7.25E-05 Acenaphthylene (kg/d) 7.76E-05 7.25E-05 7.25E-05 Acetaldehyde (kg/d) 0.00 0.00E+00 0.00E+00 Acrolein (kg/d) 0.00 0.00E+00 0.00E+00 Aliphatic& C19-C34 (kg/d) 3.02 0.00E+00 0.00E+00 Aliphatic& C5-C8 (kg/d) 2.09E+02 0.00E+00 0.00E+00 Aliphatic& C9-C18 (kg/d) 1.23E+02 0.00E+00 0.00E+00 Anthracene (kg/d) 1.03E-04 9.67E-05 9.67E-05 Aromatic (kg/d) 5.75E+01 0.00E+00 0.00E+00 Benzene (kg/d) 1.04E+01 8.46E-02 8.46E-02 Benzo(a)anthracene (kg/d) 7.76E-05 7.25E-05 7.25E-05 Benzo(a)pyrene (kg/d) 5.17E-05 4.83E-05 4.83E-05 Benzo(b)fluoranthene (kg/d) 7.76E-05 7.25E-05 7.25E-05 Benzo(g,h,i)perylene (kg/d) 5.17E-05 4.83E-05 4.83E-05 Benzo(k)fluoranthene (kg/d) 7.76E-05 7.25E-05 7.25E-05 Carbon Disulphide (kg/d) 1.34E-01 0.00E+00 0.00E+00 Carbonyl Sulphide (kg/d) 1.47E-01 0.00E+00 0.00E+00 Chrysene (kg/d) 7.76E-05 7.25E-05 7.25E-05 Dibenzo(a,h)anthracene (kg/d) 5.17E-05 4.83E-05 4.83E-05 Dichlorobenzene (kg/d) 5.17E-02 4.83E-02 4.83E-02 Ethylbenzene (kg/d) 4.87 0.00E+00 0.00E+00 Fluoranthene (kg/d) 1.29E-04 1.21E-04 1.21E-04 Fluorene (kg/d) 1.21E-04 1.13E-04 1.13E-04 Formaldehyde (kg/d) 3.23 3.02E+00 3.02E+00 Hydrogen Sulphide (kg/d) 1.04 0.00E+00 0.00E+00 Indeno(1,2,3-cd)pyrene (kg/d) 7.76E-05 7.25E-05 7.25E-05 Mercaptans (kg/d) 2.98E-03 0.00E+00 0.00E+00 Naphthalene (kg/d) 2.63E-02 2.46E-02 2.46E-02 n-hexane (kg/d) 7.76E+01 7.25E+01 7.25E+01 n-pentane (kg/d) 1.12E+02 1.05E+02 1.05E+02 Phenanthrene (kg/d) 7.33E-04 6.85E-04 6.85E-04 Pyrene (kg/d) 2.16E-04 2.01E-04 2.01E-04 Thiophenes (kg/d) 6.03E-01 0.00E+00 0.00E+00 Toluene (kg/d) 2.94E+01 1.37E-01 1.37E-01 Xylenes (kg/d) 1.15E+01 0.00E+00 0.00E+00


December 2009

Page B4-26

2.14 Petro-Canada

Table B4-24: Summary of Petro-Canada VOC and PAH Air Emissions Used for the Baseline and Project Scenarios

SAGD Facility Fort Hills Emission Source

MacKay River

Meadow Creek

S. Mine Fleet/

Fugitives

N. Mine Fleet/

Fugitives

Tailings Pond1

Process Plant

Fugitives

UTM North - NE 6,322,473 6,242,620 6,357,700 6,360,450 6,362,000 6,360,600 UTM East - NE 445,297 482,494 464,800 463,050 467,550 463,000 UTM North - SE 6,321,561 6,241,754 6,355,200 6,358,450 6,361,000 6,359,600 UTM East - SE 445,297 482,494 464,800 463,050 467,550 463,000 UTM North - SW 6,321,561 6,241,754 6,355,200 6,358,450 6,361,000 6,359,600 UTM East - SW 444,797 481,628 461,550 461,050 466,550 461,500 UTM North - NW 6,322,473 6,242,620 6,357,700 6,360,450 6,362,000 6,360,600 UTM East - NW 444,797 481,628 461,550 461,050 466,550 461,500 Area (km2) 0.46 0.75 8.13 4 1 1.5 Elevation (m) 429 725 2421 2471 347 291 1,3-Butadiene (kg/d) 0.00 0.00 1.43E-01 7.04E-02 0.00 0.00 2-MethylNaphthalene (kg/d) 4.56E-04 1.10E-03 0.00 0.00 0.00 1.48E-03 3-Methylcholanthrene (kg/d) 3.42E-05 8.25E-05 0.00 0.00 0.00 1.11E-04 7,12-Dimethylbenz(a)anthracene (kg/d) 3.04E-04 7.34E-04 0.00 0.00 0.00 9.85E-04 Acenaphthene (kg/d) 3.42E-05 8.25E-05 1.31E-02 6.41E-03 0.00 1.11E-04 Acenaphthylene (kg/d) 3.42E-05 8.25E-05 2.95E-02 1.45E-02 0.00 1.11E-04 Acetaldehyde (kg/d) 0.00 0.00 1.45 7.13E-01 0.00 0.00 Acrolein (kg/d) 0.00 0.00 1.84E-01 9.04E-02 0.00 0.00 Aliphatic& C19-C34 (kg/d) 0.00 0.00 3.85 1.89 0.00 5.10 Aliphatic& C5-C8 (kg/d) 0.00 0.00 2.61E+01 1.29E+01 1.35E+04 3.50E+02 Aliphatic& C9-C18 (kg/d) 0.00 0.00 9.32E+01 4.59E+01 3.00E+03 2.07E+02 Anthracene (kg/d) 4.56E-05 1.10E-04 5.59E-03 2.74E-03 0.00 1.48E-04 Aromatic (kg/d) 0.00 0.00 5.33 2.62 6.34 9.65E+01 Benzene (kg/d) 3.99E-02 9.67E-02 3.88 1.91 3.79E+01 1.74E+01 Benzo(a)anthracene (kg/d) 3.42E-05 8.25E-05 3.26E-03 1.60E-03 0.00 1.11E-04 Benzo(a)pyrene (kg/d) 2.28E-05 5.50E-05 7.15E-04 3.51E-04 0.00 7.38E-05 Benzo(b)fluoranthene (kg/d) 3.42E-05 8.25E-05 2.90E-03 1.42E-03 0.00 1.11E-04 Benzo(g,h,i)perylene (kg/d) 2.28E-05 5.50E-05 1.65E-03 8.08E-04 0.00 7.38E-05 Benzo(k)fluoranthene (kg/d) 3.42E-05 8.25E-05 6.18E-04 3.03E-04 0.00 1.11E-04 Carbon Disulphide (kg/d) 0.00 0.00 6.53 3.21 6.19 2.26E-01 Carbonyl Sulphide (kg/d) 0.00 0.00 3.79E+01 1.87E+01 1.99E+01 2.46E-01 Chrysene (kg/d) 3.42E-05 8.25E-05 3.51E-03 1.73E-03 0.00 1.11E-04 Dibenzo(a,h)anthracene (kg/d) 2.28E-05 5.50E-05 1.58E-03 7.77E-04 0.00 7.38E-05 Dichlorobenzene (kg/d) 2.28E-02 5.50E-02 0.00 0.00 0.00 7.38E-02 Ethylbenzene (kg/d) 0.00 0.00 6.77E-01 3.33E-01 1.10E+01 8.18 Fluoranthene (kg/d) 5.70E-05 1.38E-04 1.85E-02 9.10E-03 0.00 1.85E-04 Fluorene (kg/d) 5.32E-05 1.28E-04 6.79E-02 3.33E-02 0.00 1.72E-04 Formaldehyde (kg/d) 1.43 3.44 2.31 1.13 0.00 4.61 Hydrogen Sulphide (kg/d) 0.00 0.00 1.14 5.62E-01 2.33E+01 1.75 Indeno(1,2,3-cd)pyrene (kg/d) 3.42E-05 8.25E-05 1.24E-03 6.07E-04 0.00 1.11E-04 Mercaptans (kg/d) 0.00 0.00 2.73E-01 1.35E-01 5.20E-02 5.00E-03 Naphthalene (kg/d) 1.16E-02 2.81E-02 4.84E-01 2.38E-01 0.00 3.75E-02 n-hexane (kg/d) 3.42E+01 8.25E+01 0.00 0.00 0.00 1.11E+02 n-pentane (kg/d) 4.94E+01 1.19E+02 0.00 0.00 0.00 1.60E+02 Phenanthrene (kg/d) 3.23E-04 7.79E-04 1.34E-01 6.60E-02 0.00 1.05E-03 Pyrene (kg/d) 9.50E-05 2.29E-04 1.39E-02 6.82E-03 0.00 3.08E-04 Thiophenes (kg/d) 0.00 0.00 4.37E-01 2.15E-01 4.04E+01 1.01 Toluene (kg/d) 6.46E-02 1.57E-01 6.86 3.37 5.44E+01 4.93E+01 Xylenes (kg/d) 0.00 0.00 5.38 2.65 6.74E+01 1.94E+01



December 2009

Page B4-27

Table B4-25: Summary of Petro-Canada VOC and PAH Air Emissions Used for the Planned Development Scenario

SAGD Facility Fort Hills Emission Source

MacKay River

Meadow Creek Lewis

MacKay River

Expansion

S. Mine Fleet/

Fugitives

N. Mine Fleet/

Fugitives

Tailings Pond1

Process Plant

Fugitives

UTM North - NE 6,322,473 6,242,620 6,305,376 6,323,373 6,357,700 6,360,450 6,362,000 6,360,600 UTM East - NE 445,297 482,494 495,217 445,297 464,800 463,050 467,550 463,000 UTM North - SE 6,321,561 6,241,754 6,304,669 6,322,461 6,355,200 6,358,450 6,361,000 6,359,600 UTM East - SE 445,297 482,494 495,217 445,297 464,800 463,050 467,550 463,000 UTM North - SW 6,321,561 6,241,754 6,304,669 6,322,461 6,355,200 6,358,450 6,361,000 6,359,600 UTM East - SW 444,797 481,628 494,510 444,797 461,550 461,050 466,550 461,500 UTM North - NW 6,322,473 6,242,620 6,305,376 6,323,373 6,357,700 6,360,450 6,362,000 6,360,600 UTM East - NW 444,797 481,628 494,510 444,797 461,550 461,050 466,550 461,500 Area (km2) 0.46 0.75 0.5 0.456 8.13 4 1 1.5 Elevation (m) 429 725 466 433 2421 2471 347 291 1,3-Butadiene (kg/d) 0.00 0.00 0.00 0.00 1.43E-01 7.04E-02 0.00 0.00 2-MethylNaphthalene (kg/d) 4.56E-04 1.10E-03 8.29E-04 4.56E-04 0.00 0.00 0.00 1.48E-03 3-Methylcholanthrene (kg/d) 3.42E-05 8.25E-05 6.21E-05 3.42E-05 0.00 0.00 0.00 1.11E-04 7,12-Dimethylbenz(a)anthracene (kg/d) 3.04E-04 7.34E-04 5.52E-04 3.04E-04 0.00 0.00 0.00 9.85E-04 Acenaphthene (kg/d) 3.42E-05 8.25E-05 6.21E-05 3.42E-05 1.31E-02 6.41E-03 0.00 1.11E-04 Acenaphthylene (kg/d) 3.42E-05 8.25E-05 6.21E-05 3.42E-05 2.95E-02 1.45E-02 0.00 1.11E-04 Acetaldehyde (kg/d) 0.00 0.00 0.00 0.00 1.45 7.13E-01 0.00 0.00 Acrolein (kg/d) 0.00 0.00 0.00 0.00 1.84E-01 9.04E-02 0.00 0.00 Aliphatic& C19-C34 (kg/d) 0.00 0.00 0.00 0.00 3.85 1.89 0.00 5.10 Aliphatic& C5-C8 (kg/d) 0.00 0.00 0.00 0.00 2.61E+01 1.29E+01 1.35E+04 3.50E+02 Aliphatic& C9-C18 (kg/d) 0.00 0.00 0.00 0.00 9.32E+01 4.59E+01 3.00E+03 2.07E+02 Anthracene (kg/d) 4.56E-05 1.10E-04 8.29E-05 4.56E-05 5.59E-03 2.74E-03 0.00 1.48E-04 Aromatic (kg/d) 0.00 0.00 0.00 0.00 5.33 2.62 6.34 9.65E+01 Benzene (kg/d) 3.99E-02 9.67E-02 7.25E-02 3.99E-02 3.88 1.91 3.79E+01 1.74E+01 Benzo(a)anthracene (kg/d) 3.42E-05 8.25E-05 6.21E-05 3.42E-05 3.26E-03 1.60E-03 0.00 1.11E-04 Benzo(a)pyrene (kg/d) 2.28E-05 5.50E-05 4.14E-05 2.28E-05 7.15E-04 3.51E-04 0.00 7.38E-05 Benzo(b)fluoranthene (kg/d) 3.42E-05 8.25E-05 6.21E-05 3.42E-05 2.90E-03 1.42E-03 0.00 1.11E-04 Benzo(g,h,i)perylene (kg/d) 2.28E-05 5.50E-05 4.14E-05 2.28E-05 1.65E-03 8.08E-04 0.00 7.38E-05 Benzo(k)fluoranthene (kg/d) 3.42E-05 8.25E-05 6.21E-05 3.42E-05 6.18E-04 3.03E-04 0.00 1.11E-04 Carbon Disulphide (kg/d) 0.00 0.00 0.00 0.00 6.53 3.21 6.19 2.26E-01 Carbonyl Sulphide (kg/d) 0.00 0.00 0.00 0.00 3.79E+01 1.87E+01 1.99E+01 2.46E-01 Chrysene (kg/d) 3.42E-05 8.25E-05 6.21E-05 3.42E-05 3.51E-03 1.73E-03 0.00 1.11E-04 Dibenzo(a,h)anthracene (kg/d) 2.28E-05 5.50E-05 4.14E-05 2.28E-05 1.58E-03 7.77E-04 0.00 7.38E-05 Dichlorobenzene (kg/d) 2.28E-02 5.50E-02 4.14E-02 2.28E-02 0.00 0.00 0.00 7.38E-02 Ethylbenzene (kg/d) 0.00 0.00 0.00 0.00 6.77E-01 3.33E-01 1.10E+01 8.18 Fluoranthene (kg/d) 5.70E-05 1.38E-04 1.04E-04 5.70E-05 1.85E-02 9.10E-03 0.00 1.85E-04 Fluorene (kg/d) 5.32E-05 1.28E-04 9.67E-05 5.32E-05 6.79E-02 3.33E-02 0.00 1.72E-04 Formaldehyde (kg/d) 1.43 3.44 2.59 1.43 2.31 1.13 0.00 4.61 Hydrogen Sulphide (kg/d) 0.00 0.00 0.00 0.00 1.14 5.62E-01 2.33E+01 1.75 Indeno(1,2,3-cd)pyrene (kg/d) 3.42E-05 8.25E-05 6.21E-05 3.42E-05 1.24E-03 6.07E-04 0.00 1.11E-04 Mercaptans (kg/d) 0.00 0.00 0.00 0.00 2.73E-01 1.35E-01 5.20E-02 5.00E-03 Naphthalene (kg/d) 1.16E-02 2.81E-02 2.11E-02 1.16E-02 4.84E-01 2.38E-01 0.00 3.75E-02 n-hexane (kg/d) 3.42E+01 8.25E+01 6.22E+01 3.42E+01 0.00 0.00 0.00 1.11E+02 n-pentane (kg/d) 4.94E+01 1.19E+02 8.97E+01 4.94E+01 0.00 0.00 0.00 1.60E+02 Phenanthrene (kg/d) 3.23E-04 7.79E-04 5.87E-04 3.23E-04 1.34E-01 6.60E-02 0.00 1.05E-03 Pyrene (kg/d) 9.50E-05 2.29E-04 1.73E-04 9.50E-05 1.39E-02 6.82E-03 0.00 3.08E-04 Thiophenes (kg/d) 0.00 0.00 0.00 0.00 4.37E-01 2.15E-01 4.04E+01 1.01 Toluene (kg/d) 6.46E-02 1.57E-01 1.17E-01 6.46E-02 6.86 3.37 5.44E+01 4.93E+01 Xylenes (kg/d) 0.00 0.00 0.00 0.00 5.38 2.65 6.74E+01 1.94E+01



December 2009

Page B4-28

2.15 Shell Canada Limited

Table B4-26: Summary of Shell Jackpine Mine VOC and PAH Air Emissions Used for the Baseline and Project Scenarios

Emission Source

Phase 1 Mine

Fleet/ Fugitives Phase 1

Tailings Pond1 Process Plant

Fugitives

UTM North - NE 6,348,249 6,343,187 6,345,055 UTM East - NE 480,595 480,595 477,594 UTM North - SE 6,343,561 6,340,749 6,344,055 UTM East - SE 480,595 480,595 477,594 UTM North - SW 6,343,561 6,340,749 6,344,055 UTM East - SW 477,782 477,783 476,094 UTM North - NW 6,348,249 6,343,187 6,345,055 UTM East - NW 477,782 477,783 476,094 Area (km2) 13.18 6.86 1.5 Elevation (m) 2771 323 318 1,3-Butadiene (kg/d) 1.83E-01 0.00 0.00 2-MethylNaphthalene (kg/d) 0.00 0.00 1.26E-03 3-Methylcholanthrene (kg/d) 0.00 0.00 9.45E-05 7,12-Dimethylbenz(a)anthracene (kg/d) 0.00 0.00 8.40E-04 Acenaphthene (kg/d) 1.67E-02 0.00 9.45E-05 Acenaphthylene (kg/d) 3.77E-02 0.00 9.45E-05 Acetaldehyde (kg/d) 1.86 0.00 0.00 Acrolein (kg/d) 2.35E-01 0.00 0.00 Aliphatic& C19-C34 (kg/d) 4.89 0.00 4.32 Aliphatic& C5-C8 (kg/d) 3.32E+01 8.35E+04 2.98E+02 Aliphatic& C9-C18 (kg/d) 1.18E+02 2.68E+03 1.76E+02 Anthracene (kg/d) 7.15E-03 0.00 1.26E-04 Aromatic (kg/d) 6.77 5.68 8.21E+01 Benzene (kg/d) 4.95 3.40E+01 1.48E+01 Benzo(a)anthracene (kg/d) 4.16E-03 0.00 9.45E-05 Benzo(a)pyrene (kg/d) 9.14E-04 0.00 6.30E-05 Benzo(b)fluoranthene (kg/d) 3.71E-03 0.00 9.45E-05 Benzo(g,h,i)perylene (kg/d) 2.10E-03 0.00 6.30E-05 Benzo(k)fluoranthene (kg/d) 7.90E-04 0.00 9.45E-05 Carbon Disulphide (kg/d) 8.29 5.27 1.92E-01 Carbonyl Sulphide (kg/d) 4.81E+01 1.64E+01 2.10E-01 Chrysene (kg/d) 4.49E-03 0.00 9.45E-05 Dibenzo(a,h)anthracene (kg/d) 2.02E-03 0.00 6.30E-05 Dichlorobenzene (kg/d) 0.00 0.00 6.30E-02 Ethylbenzene (kg/d) 8.59E-01 9.85 6.96 Fluoranthene (kg/d) 2.37E-02 0.00 1.58E-04 Fluorene (kg/d) 8.68E-02 0.00 1.47E-04 Formaldehyde (kg/d) 2.95 0.00 3.94 Hydrogen Sulphide (kg/d) 1.45 1.98E+01 1.49 Indeno(1,2,3-cd)pyrene (kg/d) 1.58E-03 0.00 9.45E-05 Mercaptans (kg/d) 3.46E-01 4.43E-02 4.25E-03 Naphthalene (kg/d) 6.18E-01 0.00 3.19E-02 n-hexane (kg/d) 0.00 0.00 9.45E+01 n-pentane (kg/d) 0.00 0.00 1.36E+02 Phenanthrene (kg/d) 1.72E-01 0.00 8.93E-04 Pyrene (kg/d) 1.78E-02 0.00 2.63E-04 Thiophenes (kg/d) 5.55E-01 3.44E+01 8.62E-01 Toluene (kg/d) 8.72 4.92E+01 4.20E+01 Xylenes (kg/d) 6.84 6.05E+01 1.65E+01



December 2009

Page B4-29

Table B4-27: Summary of Shell Jackpine Mine VOC and PAH Air Emissions Used for the Planned Development Scenario

Emission Source

Phase 1 Mine Fleet/ Fugitives

Phase 2 Mine Fleet/ Fugitive

Phase 1 Tailings Pond1

Phase 2 Tailings Pond1

Process Plant

Fugitives

UTM North - NE 6,348,249 6,359,809 6,343,187 6,358,419 6,345,055 UTM East - NE 480,595 486,867 480,595 484,109 477,594 UTM North - SE 6,343,561 6,357,209 6,340,749 6,356,568 6,344,055 UTM East - SE 480,595 486,867 480,595 484,109 477,594 UTM North - SW 6,343,561 6,357,209 6,340,749 6,356,568 6,344,055 UTM East - SW 477,782 484,291 477,783 482,258 476,094 UTM North - NW 6,348,249 6,359,809 6,343,187 6,358,419 6,345,055 UTM East - NW 477,782 484,291 477,783 482,258 476,094 Area (km2) 13.18 6.7 6.86 3.43 1.5 Elevation (m) 2771 2441 323 295 318 1,3-Butadiene (kg/d) 1.83E-01 9.14E-02 0.00 0.00 0.00 2-MethylNaphthalene (kg/d) 0.00 0.00 0.00 0.00 1.88E-03 3-Methylcholanthrene (kg/d) 0.00 0.00 0.00 0.00 1.41E-04 7,12-Dimethylbenz(a)anthracene (kg/d) 0.00 0.00 0.00 0.00 1.25E-03 Acenaphthene (kg/d) 1.67E-02 8.33E-03 0.00 0.00 1.41E-04 Acenaphthylene (kg/d) 3.77E-02 1.88E-02 0.00 0.00 1.41E-04 Acetaldehyde (kg/d) 1.86 9.26E-01 0.00 0.00 0.00 Acrolein (kg/d) 2.35E-01 1.17E-01 0.00 0.00 0.00 Aliphatic& C19-C34 (kg/d) 4.89 2.45 0.00 0.00 6.48 Aliphatic& C5-C8 (kg/d) 3.32E+01 1.66E+01 8.35E+04 4.18E+04 4.47E+02 Aliphatic& C9-C18 (kg/d) 1.18E+02 5.92E+01 2.68E+03 1.34E+03 2.64E+02 Anthracene (kg/d) 7.15E-03 3.56E-03 0.00 0.00 1.88E-04 Aromatic (kg/d) 6.77 3.39 5.68 2.84 1.23E+02 Benzene (kg/d) 4.95 2.47 3.40E+01 1.70E+01 2.22E+01 Benzo(a)anthracene (kg/d) 4.16E-03 2.07E-03 0.00 0.00 1.41E-04 Benzo(a)pyrene (kg/d) 9.14E-04 4.56E-04 0.00 0.00 9.41E-05 Benzo(b)fluoranthene (kg/d) 3.71E-03 1.85E-03 0.00 0.00 1.41E-04 Benzo(g,h,i)perylene (kg/d) 2.10E-03 1.05E-03 0.00 0.00 9.41E-05 Benzo(k)fluoranthene (kg/d) 7.90E-04 3.94E-04 0.00 0.00 1.41E-04 Carbon Disulphide (kg/d) 8.29 4.15 5.27 2.64 2.88E-01 Carbonyl Sulphide (kg/d) 4.81E+01 2.41E+01 1.64E+01 8.64 3.15E-01 Chrysene (kg/d) 4.49E-03 2.24E-03 0.00 0.00 1.41E-04 Dibenzo(a,h)anthracene (kg/d) 2.02E-03 1.01E-03 0.00 0.00 9.41E-05 Dichlorobenzene (kg/d) 0.00 0.00 0.00 0.00 9.41E-02 Ethylbenzene (kg/d) 8.59E-01 4.29E-01 9.85 4.92 1.04E+01 Fluoranthene (kg/d) 2.37E-02 1.18E-02 0.00 0.00 2.35E-04 Fluorene (kg/d) 8.68E-02 4.33E-02 0.00 0.00 2.19E-04 Formaldehyde (kg/d) 2.95 1.47 0.00 0.00 5.88 Hydrogen Sulphide (kg/d) 1.45 7.25E-01 1.98E+01 9.92 2.23 Indeno(1,2,3-cd)pyrene (kg/d) 1.58E-03 7.88E-04 0.00 0.00 1.41E-04 Mercaptans (kg/d) 3.46E-01 1.74E-01 4.43E-02 2.21E-02 6.38E-03 Naphthalene (kg/d) 6.18E-01 3.08E-01 0.00 0.00 4.79E-02 n-hexane (kg/d) 0.00 0.00 0.00 0.00 1.41E+02 n-pentane (kg/d) 0.00 0.00 0.00 0.00 2.04E+02 Phenanthrene (kg/d) 1.72E-01 8.57E-02 0.00 0.00 1.33E-03 Pyrene (kg/d) 1.78E-02 8.85E-03 0.00 0.00 3.92E-04 Thiophenes (kg/d) 5.55E-01 2.77E-01 3.44E+01 1.72E+01 1.29 Toluene (kg/d) 8.72 4.36 4.92E+01 2.42E+01 6.30E+01 Xylenes (kg/d) 6.84 3.42 6.05E+01 3.02E+01 2.47E+01



December 2009

Page B4-30

2.16 StatoilHydro

Table B4-28: Summary of StatoilHydro VOC and PAH Air Emissions Used for the

Baseline and Project Scenarios Emission Source

Leismer UTM North - NE 6,186,000 UTM East - NE 472,000 UTM North - SE 6,186,825 UTM East - SE 472,000 UTM North - SW 6,186,825 UTM East - SW 473,650 UTM North - NW 6,186,000 UTM East - NW 473,650 Area (km2) 0.100 Elevation (m) 671 1,3-Butadiene (kg/d) 0.00 2-MethylNaphthalene (kg/d) 1.38E-04 3-Methylcholanthrene (kg/d) 1.04E-05 7,12-Dimethylbenz(a)anthracene (kg/d) 9.21E-05 Acenaphthene (kg/d) 1.04E-05 Acenaphthylene (kg/d) 1.04E-05 Acetaldehyde (kg/d) 0.00 Acrolein (kg/d) 0.00 Aliphatic& C19-C34 (kg/d) 0.00 Aliphatic& C5-C8 (kg/d) 0.00 Aliphatic& C9-C18 (kg/d) 0.00 Anthracene (kg/d) 1.38E-05 Aromatic (kg/d) 0.00 Benzene (kg/d) 1.21E-02 Benzo(a)anthracene (kg/d) 1.04E-05 Benzo(a)pyrene (kg/d) 6.91E-06 Benzo(b)fluoranthene (kg/d) 1.04E-05 Benzo(g,h,i)perylene (kg/d) 6.91E-06 Benzo(k)fluoranthene (kg/d) 1.04E-05 Carbon Disulphide (kg/d) 0.00 Carbonyl Sulphide (kg/d) 0.00 Chrysene (kg/d) 1.04E-05 Dibenzo(a,h)anthracene (kg/d) 6.91E-06 Dichlorobenzene (kg/d) 6.91E-03 Ethylbenzene (kg/d) 0.00 Fluoranthene (kg/d) 1.73E-05 Fluorene (kg/d) 1.61E-05 Formaldehyde (kg/d) 4.32E-01 Hydrogen Sulphide (kg/d) 0.00 Indeno(1,2,3-cd)pyrene (kg/d) 1.04E-05 Mercaptans (kg/d) 0.00 Naphthalene (kg/d) 3.51E-03 n-hexane (kg/d) 1.04E+01 n-pentane (kg/d) 1.50E+01 Phenanthrene (kg/d) 9.78E-05 Pyrene (kg/d) 2.88E-05 Thiophenes (kg/d) 0.00 Toluene (kg/d) 1.96E-02 Xylenes (kg/d) 0.00


December 2009

Page B4-31

Table B4-29: Summary of StatoilHydro VOC and PAH Air Emissions Used for the Planned Development Scenario

Emission Source Leismer Corner Thornbury Hangingstone UTM North - NE 6,186,000 6,203,000 6,195,000 6,226,000 UTM East - NE 472,000 476,000 456,500 476,000 UTM North - SE 6,186,825 6,204,650 6,196,500 6,226,825 UTM East - SE 472,000 476,000 456,500 476,000 UTM North - SW 6,186,825 6,204,650 6,196,500 6,226,825 UTM East - SW 473,650 476,825 457,325 477,650 UTM North - NW 6,186,000 6,203,000 6,195,000 6,226,000 UTM East - NW 473,650 476,825 457,325 477,650 Area (km2) 0.100 0.100 0.100 0.100 Elevation (m) 671 671 671 671 1,3-Butadiene (kg/d) 0.00 0.00 0.00 0.00 2-MethylNaphthalene (kg/d) 5.52E-04 5.52E-04 9.67E-04 9.67E-04 3-Methylcholanthrene (kg/d) 4.14E-05 4.14E-05 7.25E-05 7.25E-05 7,12-Dimethylbenz(a)anthracene (kg/d) 3.68E-04 3.68E-04 6.44E-04 6.44E-04 Acenaphthene (kg/d) 4.14E-05 4.14E-05 7.25E-05 7.25E-05 Acenaphthylene (kg/d) 4.14E-05 4.14E-05 7.25E-05 7.25E-05 Acetaldehyde (kg/d) 0.00 0.00 0.00 0.00 Acrolein (kg/d) 0.00 0.00 0.00 0.00 Aliphatic& C19-C34 (kg/d) 0.00 0.00 0.00 0.00 Aliphatic& C5-C8 (kg/d) 0.00 0.00 0.00 0.00 Aliphatic& C9-C18 (kg/d) 0.00 0.00 0.00 0.00 Anthracene (kg/d) 5.52E-05 5.52E-05 9.67E-05 9.67E-05 Aromatic (kg/d) 0.00 0.00 0.00 0.00 Benzene (kg/d) 4.83E-02 4.83E-02 8.46E-02 8.46E-02 Benzo(a)anthracene (kg/d) 4.14E-05 4.14E-05 7.25E-05 7.25E-05 Benzo(a)pyrene (kg/d) 2.76E-05 2.76E-05 4.83E-05 4.83E-05 Benzo(b)fluoranthene (kg/d) 4.14E-05 4.14E-05 7.25E-05 7.25E-05 Benzo(g,h,i)perylene (kg/d) 2.76E-05 2.76E-05 4.83E-05 4.83E-05 Benzo(k)fluoranthene (kg/d) 4.14E-05 4.14E-05 7.25E-05 7.25E-05 Carbon Disulphide (kg/d) 0.00 0.00 0.00 0.00 Carbonyl Sulphide (kg/d) 0.00 0.00 0.00 0.00 Chrysene (kg/d) 4.14E-05 4.14E-05 7.25E-05 7.25E-05 Dibenzo(a,h)anthracene (kg/d) 2.76E-05 2.76E-05 4.83E-05 4.83E-05 Dichlorobenzene (kg/d) 2.76E-02 2.76E-02 4.83E-02 4.83E-02 Ethylbenzene (kg/d) 0.00 0.00 0.00 0.00 Fluoranthene (kg/d) 6.91E-05 6.91E-05 1.21E-04 1.21E-04 Fluorene (kg/d) 6.44E-05 6.44E-05 1.13E-04 1.13E-04 Formaldehyde (kg/d) 1.73E+00 1.73E+00 3.02E+00 3.02E+00 Hydrogen Sulphide (kg/d) 0.00 0.00 0.00 0.00 Indeno(1,2,3-cd)pyrene (kg/d) 4.14E-05 4.14E-05 7.25E-05 7.25E-05 Mercaptans (kg/d) 0.00 0.00 0.00 0.00 Naphthalene (kg/d) 1.40E-02 1.40E-02 2.46E-02 2.46E-02 n-hexane (kg/d) 4.14E+01 4.14E+01 7.25E+01 7.25E+01 n-pentane (kg/d) 5.98E+01 5.98E+01 1.05E+02 1.05E+02 Phenanthrene (kg/d) 3.91E-04 3.91E-04 6.85E-04 6.85E-04 Pyrene (kg/d) 1.15E-04 1.15E-04 2.01E-04 2.01E-04 Thiophenes (kg/d) 0.00 0.00 0.00 0.00 Toluene (kg/d) 7.83E-02 7.83E-02 1.37E-01 1.37E-01 Xylenes (kg/d) 0.00 0.00 0.00 0.00


December 2009

Page B4-32

2.17 Suncor Energy Inc.

Table B4-30: Summary of Suncor Millennium and Voyageur VOC and PAH Air Emissions Used for the Baseline, Project and Planned Development Scenarios Emission Source

Mine Fleet/ Fugitives 1








Pit 4 Area 1


Pit 4 Area 2


Pit 4 Area 3

Coker Fleet Fugitives Pond 2/31

South Tail

Pond1

Base and Millennium

Upgrader Plant

Voyageur Upgrader Plant

UTM North - NE 6,311,147 6,311,147 6,314,560 6,315,427 6,316,584 6,318,251 6,319,546 6,319,240 6,318,332 6,317,490 6,311,147 6,317,061 6,305,130 6,318,693 6,314,830 UTM East - NE 478,254 481,401 481,033 477,810 475,317 473,348 472,480 477,273 479,603 477,685 478,254 469,459 481,783 470,728 468,970 UTM North - SE 6,306,719 6,307,136 6,311,254 6,311,240 6,315,510 6,317,245 6,318,457 6,318,310 6,316,809 6,316,846 6,306,719 6,315,759 6,301,456 6,317,492 6,314,350 UTM East - SE 478,244 481,401 481,075 477,797 475,372 474,312 473,182 476,341 479,603 477,361 478,244 469,459 481,783 471,443 469,922 UTM North - SW 6,306,719 6,307,116 6,311,254 6,311,254 6,315,510 6,316,667 6,317,920 6,320,144 6,316,955 6,318,058 6,306,719 6,315,759 6,301,456 6,317,203 6,313,701 UTM East - SW 474,431 478,373 477,865 473,954 473,885 473,706 472,590 474,503 477,635 475,241 474,431 468,233 478,109 470,953 469,599 UTM North - NW 6,311,147 6,311,147 6,314,587 6,315,427 6,316,612 6,317,590 6,319,077 6,321,077 6,318,332 6,318,712 6,311,147 6,317,061 6,305,130 6,318,402 6,314,184 UTM East - NW 474,421 478,383 477,865 473,940 473,885 472,714 471,819 475,436 477,771 475,672 474,421 468,233 478,109 470,238 468,647 Area (km2) 16.93 12.16 10.58 16.12 1.59 1.2 1.07 3.42 2.76 1.8 16.93 1.6 13.5 0.8 0.77 Elevation (m) 2781 3031 3051 2801 2681 2261 2151 2861 2911 2881 318 363 357 256 322 1,3-Butadiene (kg/d) 1.16E-01 8.33E-02 7.24E-02 1.11E-01 1.09E-02 8.27E-03 7.36E-03 2.35E-02 1.89E-02 1.23E-02 3.39E-02 0.00 0.00E+00 0.00 0.00 2-MethylNaphthalene (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00E+00 2.40E-03 2.40E-03 3-Methylcholanthrene (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00E+00 1.80E-04 1.80E-04 7,12-Dimethylbenz(a)anthracene (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00E+00 1.60E-03 1.60E-03 Acenaphthene (kg/d) 1.06E-02 7.59E-03 6.59E-03 1.01E-02 9.92E-04 7.53E-04 6.70E-04 2.14E-03 1.72E-03 1.12E-03 3.09E-03 0.00 0.00E+00 1.80E-04 1.80E-04 Acenaphthylene (kg/d) 2.39E-02 1.71E-02 1.49E-02 2.27E-02 2.24E-03 1.70E-03 1.51E-03 4.82E-03 3.89E-03 2.54E-03 6.96E-03 0.00 0.00E+00 1.80E-04 1.80E-04 Acetaldehyde (kg/d) 1.18 0.84 0.73 1.12 0.11 0.08 0.07 0.24 0.19 0.13 3.43E-01 0.00 0.00E+00 0.00 0.00 Acrolein (kg/d) 1.49E-01 1.07E-01 9.29E-02 1.42E-01 1.40E-02 1.06E-02 9.45E-03 3.01E-02 2.43E-02 1.59E-02 4.35E-02 0.00 0.00E+00 0.00 0.00 Aliphatic& C19-C34 (kg/d) 5.95 4.27 3.72 5.66 0.56 0.42 0.38 8.03 6.47 4.22 0.00 0.00 0.00E+00 5.56 2.38E-01 Aliphatic& C5-C8 (kg/d) 40.40 29.00 25.20 38.40 3.79 2.87 2.56 54.50 43.90 28.70 0.00 1.49E+04 3.81E+02 3.83E+02 1.64E+01 Aliphatic& C9-C18 (kg/d) 144.0 103.0 90.0 137.0 13.5 10.2 9.1 194.0 157.0 102.0 0.00 478.0 1.23E+01 2.26E+02 9.50 Anthracene (kg/d) 4.53E-03 3.25E-03 2.82E-03 4.31E-03 4.24E-04 3.22E-04 2.87E-04 9.15E-04 7.37E-04 4.81E-04 1.32E-03 0.00 0.00E+00 2.40E-04 2.40E-04 Aromatic (kg/d) 8.24 5.92 5.15 7.85 0.77 0.59 0.52 11.10 8.97 5.85 0.0 1.01 2.59E-02 1.05E+02 4.32 Benzene (kg/d) 5.46 3.92 3.41 5.20 0.51 0.39 0.35 7.37 5.94 3.88 7.84E-01 6.05 1.55E-01 18.98 8.13E-01 Benzo(a)anthracene (kg/d) 2.64E-03 1.89E-03 1.64E-03 2.51E-03 2.47E-04 1.88E-04 1.67E-04 5.33E-04 4.29E-04 2.80E-04 7.69E-04 0.00 0.00E+00 1.80E-04 1.80E-04 Benzo(a)pyrene (kg/d) 5.79E-04 4.15E-04 3.61E-04 5.51E-04 5.42E-05 4.12E-05 3.67E-05 1.17E-04 9.42E-05 6.15E-05 1.69E-04 0.00 0.00E+00 1.20E-04 1.20E-04 Benzo(b)fluoranthene (kg/d) 2.35E-03 1.69E-03 1.46E-03 2.24E-03 2.20E-04 1.67E-04 1.49E-04 4.75E-04 3.83E-04 2.50E-04 6.85E-04 0.00 0.00E+00 1.80E-04 1.80E-04 Benzo(g,h,i)perylene (kg/d) 1.33E-03 9.56E-04 8.31E-04 1.27E-03 1.25E-04 9.49E-05 8.45E-05 2.69E-04 2.17E-04 1.42E-04 3.89E-04 0.00 0.00E+00 1.20E-04 1.20E-04 Benzo(k)fluoranthene (kg/d) 5.00E-04 3.59E-04 3.12E-04 4.77E-04 4.69E-05 3.56E-05 3.17E-05 1.01E-04 8.15E-05 5.32E-05 1.46E-04 0.00 0.00E+00 1.80E-04 1.80E-04 Carbon Disulphide (kg/d) 5.81 4.17 3.63 5.53 0.55 0.41 0.37 1.18 0.95 0.62 0.0 14.40 3.69E-01 2.46E-01 1.05E-02 Carbonyl Sulphide (kg/d) 33.70 24.20 21.10 32.10 3.16 2.40 2.14 6.82 5.50 3.59 0.0 45.50 1.17E+00 2.70E-01 1.15E-02 Chrysene (kg/d) 2.85E-03 2.04E-03 1.77E-03 2.71E-03 2.67E-04 2.03E-04 1.80E-04 5.75E-04 4.63E-04 3.02E-04 8.30E-04 0.00 0.00E+00 1.80E-04 1.80E-04 Dibenzo(a,h)anthracene (kg/d) 1.28E-03 9.19E-04 7.98E-04 1.22E-03 1.20E-04 9.13E-05 8.12E-05 2.59E-04 2.09E-04 1.36E-04 3.74E-04 0.00 0.00E+00 1.20E-04 1.20E-04 Dichlorobenzene (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00E+00 1.20E-01 1.20E-01 Ethylbenzene (kg/d) 1.04E+00 7.50E-01 6.53E-01 9.95E-01 9.80E-02 7.43E-02 6.63E-02 1.41E+00 1.14E+00 7.42E-01 0.0 1.75 4.50E-02 8.90 3.83E-01 Fluoranthene (kg/d) 1.50E-02 1.08E-02 9.35E-03 1.43E-02 1.41E-03 1.07E-03 9.51E-04 3.03E-03 2.44E-03 1.60E-03 4.38E-03 0.00 0.00E+00 3.00E-04 3.00E-04 Fluorene (kg/d) 5.50E-02 3.95E-02 3.43E-02 5.24E-02 5.16E-03 3.92E-03 3.48E-03 1.11E-02 8.96E-03 5.85E-03 1.60E-02 0.00 0.00E+00 2.80E-04 2.80E-04 Formaldehyde (kg/d) 1.87 1.34 1.17 1.78 0.18 0.13 0.12 0.38 0.30 0.20 5.45E-01 0.00 0.00E+00 7.50 7.50 Hydrogen Sulphide (kg/d) 1.02E+00 7.29E-01 6.35E-01 9.67E-01 9.52E-02 7.22E-02 6.44E-02 2.05E-01 1.65E-01 1.08E-01 0.0 54.20 1.39E+00 1.91 8.17E-02 Indeno(1,2,3-cd)pyrene (kg/d) 1.00E-03 7.18E-04 6.24E-04 9.54E-04 9.38E-05 7.13E-05 6.34E-05 2.02E-04 1.63E-04 1.06E-04 2.92E-04 0.00 0.00E+00 1.80E-04 1.80E-04 Mercaptans (kg/d) 2.43E-01 1.75E-01 1.52E-01 2.31E-01 2.28E-02 1.73E-02 1.54E-02 4.92E-02 3.96E-02 2.59E-02 0.0 0.12 3.10E-03 5.46E-03 2.33E-04 Naphthalene (kg/d) 5.39E-01 3.87E-01 3.37E-01 5.13E-01 5.06E-02 3.83E-02 3.42E-02 7.28E-01 5.87E-01 3.83E-01 6.83E-02 0.00 0.00E+00 6.10E-02 6.10E-02 n-hexane (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00E+00 1.80E+02 1.80E+02 n-pentane (kg/d) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00E+00 2.60E+02 2.60E+02 Phenanthrene (kg/d) 1.09E-01 7.81E-02 6.78E-02 1.04E-01 1.02E-02 7.75E-03 6.90E-03 2.20E-02 1.77E-02 1.16E-02 3.17E-02 0.00 0.00E+00 1.70E-03 1.70E-03 Pyrene (kg/d) 1.12E-02 8.07E-03 7.01E-03 1.07E-02 1.05E-03 8.01E-04 7.13E-04 2.27E-03 1.83E-03 1.20E-03 3.28E-03 0.00 0.00E+00 5.00E-04 5.00E-04 Thiophenes (kg/d) 3.89E-01 2.79E-01 2.43E-01 3.70E-01 3.65E-02 2.76E-02 2.47E-02 7.86E-02 6.34E-02 4.14E-02 0.0 93.90 2.41E+00 1.11 4.73E-02 Toluene (kg/d) 9.98 7.17 6.24 9.51 0.94 0.71 0.63 13.50 10.90 7.09 2.01E-01 8.72 2.24E-01 5.36E+01 2.59 Xylenes (kg/d) 7.89 5.67 4.93 7.51 0.74 0.56 0.50 10.70 8.59 5.60 1.39E-01 10.80 2.77E-01 2.07E+01 8.64E-01



December 2009

Page B4-33

Table B4-31: Summary of Suncor Firebag VOC and PAH Air Emissions Used for the Baseline

and Project Scenarios Emission Source

Firebag 1, 2 and 3 UTM North - NE 6,344,910 UTM East - NE 509,611 UTM North - SE 6,343,024 UTM East - SE 509,260 UTM North - SW 6,343,016 UTM East - SW 508,630 UTM North - NW 6,344,914 UTM East - NW 508,630 Area (km2) 1.524 Elevation (m) 582 1,3-Butadiene (kg/d) 0.00 2-MethylNaphthalene (kg/d) 1.94E-03 3-Methylcholanthrene (kg/d) 1.45E-04 7,12-Dimethylbenz(a)anthracene (kg/d) 1.29E-03 Acenaphthene (kg/d) 1.45E-04 Acenaphthylene (kg/d) 1.45E-04 Acetaldehyde (kg/d) 0.00 Acrolein (kg/d) 0.00 Aliphatic& C19-C34 (kg/d) 0.00 Aliphatic& C5-C8 (kg/d) 0.00 Aliphatic& C9-C18 (kg/d) 0.00 Anthracene (kg/d) 1.94E-04 Aromatic (kg/d) 0.00 Benzene (kg/d) 7.19E-01 Benzo(a)anthracene (kg/d) 1.45E-04 Benzo(a)pyrene (kg/d) 9.69E-05 Benzo(b)fluoranthene (kg/d) 1.45E-04 Benzo(g,h,i)perylene (kg/d) 9.69E-05 Benzo(k)fluoranthene (kg/d) 1.45E-04 Carbon Disulphide (kg/d) 0.00 Carbonyl Sulphide (kg/d) 0.00 Chrysene (kg/d) 1.45E-04 Dibenzo(a,h)anthracene (kg/d) 9.69E-05 Dichlorobenzene (kg/d) 9.69E-02 Ethylbenzene (kg/d) 0.00 Fluoranthene (kg/d) 2.42E-04 Fluorene (kg/d) 2.26E-04 Formaldehyde (kg/d) 6.06 Hydrogen Sulphide (kg/d) 0.00 Indeno(1,2,3-cd)pyrene (kg/d) 1.45E-04 Mercaptans (kg/d) 0.00 Naphthalene (kg/d) 2.09E-01 n-hexane (kg/d) 1.45E+02 n-pentane (kg/d) 2.10E+02 Phenanthrene (kg/d) 1.37E-03 Pyrene (kg/d) 4.04E-04 Thiophenes (kg/d) 0.00 Toluene (kg/d) 1.16 Xylenes (kg/d) 0.00


December 2009

Page B4-34

Table B4-32: Summary of Suncor Firebag VOC and PAH Air Emissions Used for the Planned Development Scenario

Emission Source Firebag 1, 2 and 3 Firebag 4, 5 and 6 UTM North - NE 6,344,910 6,344,910 UTM East - NE 509,611 509,611 UTM North - SE 6,343,024 6,343,024 UTM East - SE 509,260 509,260 UTM North - SW 6,343,016 6,343,016 UTM East - SW 508,630 508,630 UTM North - NW 6,344,914 6,344,914 UTM East - NW 508,630 508,630 Area (km2) 1.524 1.524 Elevation (m) 582 582 1,3-Butadiene (kg/d) 0.00 0.00 2-MethylNaphthalene (kg/d) 1.94E-03 1.94E-03 3-Methylcholanthrene (kg/d) 1.45E-04 1.45E-04 7,12-Dimethylbenz(a)anthracene (kg/d) 1.29E-03 1.29E-03 Acenaphthene (kg/d) 1.45E-04 1.45E-04 Acenaphthylene (kg/d) 1.45E-04 1.45E-04 Acetaldehyde (kg/d) 0.00 0.00 Acrolein (kg/d) 0.00 0.00 Aliphatic& C19-C34 (kg/d) 0.00 0.00 Aliphatic& C5-C8 (kg/d) 0.00 0.00 Aliphatic& C9-C18 (kg/d) 0.00 0.00 Anthracene (kg/d) 1.94E-04 1.94E-04 Aromatic (kg/d) 0.00 0.00 Benzene (kg/d) 2.43 2.43 Benzo(a)anthracene (kg/d) 1.45E-04 1.45E-04 Benzo(a)pyrene (kg/d) 9.69E-05 9.69E-05 Benzo(b)fluoranthene (kg/d) 1.45E-04 1.45E-04 Benzo(g,h,i)perylene (kg/d) 9.69E-05 9.69E-05 Benzo(k)fluoranthene (kg/d) 1.45E-04 1.45E-04 Carbon Disulphide (kg/d) 0.00 0.00 Carbonyl Sulphide (kg/d) 0.00 0.00 Chrysene (kg/d) 1.45E-04 1.45E-04 Dibenzo(a,h)anthracene (kg/d) 9.69E-05 9.69E-05 Dichlorobenzene (kg/d) 9.69E-02 9.69E-02 Ethylbenzene (kg/d) 0.00 0.00 Fluoranthene (kg/d) 2.42E-04 2.42E-04 Fluorene (kg/d) 2.26E-04 2.26E-04 Formaldehyde (kg/d) 6.06 6.06 Hydrogen Sulphide (kg/d) 0.00 0.00 Indeno(1,2,3-cd)pyrene (kg/d) 1.45E-04 1.45E-04 Mercaptans (kg/d) 0.00 0.00 Naphthalene (kg/d) 7.05E-01 7.05E-01 n-hexane (kg/d) 1.45E+02 1.45E+02 n-pentane (kg/d) 2.10E+02 2.10E+02 Phenanthrene (kg/d) 1.37E-03 1.37E-03 Pyrene (kg/d) 4.04E-04 4.04E-04 Thiophenes (kg/d) 0.00 0.00 Toluene (kg/d) 3.93 3.93 Xylenes (kg/d) 0.00 0.00


December 2009

Page B4-35

2.18 Syncrude Canada Ltd.

Table B4-33: Summary of Syncrude Mildred Lake VOC and PAH Air Emissions Used for the Baseline, Project and Planned Development Emission Scenarios

Emission Source

North Mine Fleet/

Fugitives

West Mine Fleet/

Fugitives

Upgrader Plant

Fugitives

Settling Basin1

SW Sand Storage1

West In-Pit1

East- In-Pit1

UTM North - NE 6,323,363 6,318,621 6,323,873 6,327,610 6,319,190 6,319,930 6,320,450 UTM East - NE 459,532 460,394 464,133 463,640 457,450 464,010 467,350 UTM North - SE 6,321,163 6,316,321 6,321,673 6,323,310 6,314,390 6,317,380 6,317,250 UTM East - SE 459,532 460,394 464,133 463,640 457,450 464,010 467,350 UTM North - SW 6,321,163 6,316,321 6,321,673 6,323,310 6,314,390 6,317,380 6,317,250 UTM East - SW 455,832 458,794 461,933 459,340 452,650 461,460 464,150 UTM North - NW 6,323,363 6,318,621 6,323,873 6,327,610 6,319,190 6,319,930 6,320,450 UTM East - NW 455,832 458,794 461,933 459,340 452,650 461,460 464,150 Area (km2) 8.14 3.68 4.84 18.49 23.04 6.5 10.24 Elevation (m) 2211 2611 305 302 357 308 309 1,3-Butadiene (kg/d) 1.42E-01 9.77E-02 0.00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 2-MethylNaphthalene (kg/d) 0.00 0.00 4.17E-03 0.00E+00 0.00E+00 0.00E+00 0.00E+00 3-Methylcholanthrene (kg/d) 0.00 0.00 3.12E-04 0.00E+00 0.00E+00 0.00E+00 0.00E+00 7,12-Dimethylbenz(a)anthracene (kg/d) 0.00 0.00 2.78E-03 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Acenaphthene (kg/d) 1.30E-02 8.90E-03 3.12E-04 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Acenaphthylene (kg/d) 2.93E-02 2.01E-02 3.12E-04 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Acetaldehyde (kg/d) 1.44 9.90E-01 0.00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Acrolein (kg/d) 1.83E-01 1.26E-01 0.00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Aliphatic& C19-C34 (kg/d) 4.16 2.69 1.23E+01 5.90E+01 5.85E+01 1.17E+00 1.84E+00 Aliphatic& C5-C8 (kg/d) 2.82E+01 1.82E+01 8.42E+02 1.83E+04 6.38E+03 4.18E+02 6.58E+02 Aliphatic& C9-C18 (kg/d) 1.01E+02 6.51E+01 4.97E+02 7.66E+02 3.35E+02 5.59E+00 8.80E+00 Anthracene (kg/d) 5.55E-03 3.81E-03 4.17E-04 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Aromatic (kg/d) 5.76 3.73 2.32E+02 1.05E+03 5.94E+02 2.57E+01 4.04E+01 Benzene (kg/d) 3.85 2.64 4.18E+01 1.56E+02 1.10E+00 1.49E+01 2.34E+01 Benzo(a)anthracene (kg/d) 3.23E-03 2.22E-03 3.12E-04 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Benzo(a)pyrene (kg/d) 7.09E-04 4.87E-04 2.08E-04 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Benzo(b)fluoranthene (kg/d) 2.88E-03 1.98E-03 3.12E-04 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Benzo(g,h,i)perylene (kg/d) 1.63E-03 1.12E-03 2.08E-04 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Benzo(k)fluoranthene (kg/d) 6.13E-04 4.21E-04 3.12E-04 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Carbon Disulphide (kg/d) 7.05 4.56 5.43E-01 7.38E+00 6.97E+01 4.34E+00 6.83E+00 Carbonyl Sulphide (kg/d) 4.09E+01 2.65E+01 5.93E-01 2.33E+01 5.26E+01 1.19E+01 1.87E+01 Chrysene (kg/d) 3.49E-03 2.39E-03 3.12E-04 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Dibenzo(a,h)anthracene (kg/d) 1.57E-03 1.08E-03 2.08E-04 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Dichlorobenzene (kg/d) 0.00 0.00 2.08E-01 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Ethylbenzene (kg/d) 7.30E-01 4.73E-01 1.97E+01 1.97E+02 1.41E+00 1.83E+01 2.88E+01 Fluoranthene (kg/d) 1.84E-02 1.26E-02 5.21E-04 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Fluorene (kg/d) 6.74E-02 4.63E-02 4.86E-04 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Formaldehyde (kg/d) 2.29 1.57 1.30E+01 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Hydrogen Sulphide (kg/d) 1.23 7.97E-01 4.20 2.78E+01 4.37E+01 7.96E+00 1.25E+01 Indeno(1,2,3-cd)pyrene (kg/d) 1.23E-03 8.42E-04 3.12E-04 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Mercaptans (kg/d) 2.95E-01 1.91E-01 1.20E-02 6.20E-02 0.00E+00 0.00E+00 0.00E+00 Naphthalene (kg/d) 4.84E-01 3.30E-01 1.06E-01 1.52E+01 2.74E+00 7.98E+00 1.26E+01 n-hexane (kg/d) 0.00 0.00 3.13E+02 0.00E+00 0.00E+00 0.00E+00 0.00E+00 n-pentane (kg/d) 0.00 0.00 4.51E+02 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Phenanthrene (kg/d) 1.33E-01 9.16E-02 2.95E-03 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Pyrene (kg/d) 1.38E-02 9.47E-03 8.68E-04 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Thiophenes (kg/d) 4.72E-01 3.05E-01 2.43 4.82E+01 0.00E+00 0.00E+00 0.00E+00 Toluene (kg/d) 7.29 4.77 1.19E+02 4.74E+02 2.51E+01 1.90E+01 2.99E+01 Xylenes (kg/d) 5.73 3.74 4.66E+01 7.60E+02 6.74E+00 6.29E+01 9.91E+01



December 2009

Page B4-36

Table B4-34: Summary of Syncrude Aurora North and South Mine Facilities VOC and PAH Air Emissions Used for the Baseline, Project and Planned Development Scenarios

Emission Source

Aurora South Mine Fleet/ Fugitives

Aurora North Mine Fleet/ Fugitives

South Tailings Pond 1

North Tailings Pond1

North Plant Process Fugitives

South Plant Process Fugitives

UTM North - NE 6,347,587 6,354,537 6,340,330 6,352,490 6,351,506 6,343,426 UTM East - NE 484,935 468,965 488,530 474,890 469,886 484,648 UTM North - SE 6,344,587 6,351,537 6,338,430 6,350,590 6,350,006 6,341,926 UTM East - SE 484,935 468,965 488,530 474,890 469,886 484,648 UTM North - SW 6,344,587 6,351,537 6,338,430 6,350,590 6,350,006 6,341,926 UTM East - SW 482,935 466,965 486,630 472,990 468,886 483,648 UTM North - NW 6,347,587 6,354,537 6,340,330 6,352,490 6,351,506 6,343,426 UTM East - NW 482,935 466,965 486,630 472,990 468,886 483,648 Area (km2) 6 6 3.61 3.61 1.5 1.5 Elevation (m) 2811 2541 381 286 302 334 1,3-Butadiene (kg/d) 1.50E-01 1.13E-01 0.00 0.00 0.00 0.00 2-MethylNaphthalene (kg/d) 0.00 0.00 0.00 0.00 1.35E-03 1.35E-03 3-Methylcholanthrene (kg/d) 0.00 0.00 0.00 0.00 1.02E-04 1.02E-04 7,12-Dimethylbenz(a)anthracene (kg/d) 0.00 0.00 0.00 0.00 9.03E-04 9.03E-04 Acenaphthene (kg/d) 1.36E-02 1.03E-02 0.00 0.00 1.02E-04 1.02E-04 Acenaphthylene (kg/d) 3.08E-02 2.33E-02 0.00 0.00 1.02E-04 1.02E-04 Acetaldehyde (kg/d) 1.52 1.15 0.00 0.00 0.00 0.00 Acrolein (kg/d) 1.92E-01 1.46E-01 0.00 0.00 0.00 0.00 Aliphatic& C19-C34 (kg/d) 5.26 5.26 0.00 0.00 4.67 4.67 Aliphatic& C5-C8 (kg/d) 3.57E+01 3.57E+01 8.98E+04 8.98E+04 3.20E+02 3.20E+02 Aliphatic& C9-C18 (kg/d) 1.27E+02 1.27E+02 2.88E+03 2.88E+03 1.89E+02 1.89E+02 Anthracene (kg/d) 5.84E-03 4.42E-03 0.00 0.00 1.35E-04 1.35E-04 Aromatic (kg/d) 7.28 7.28 6.11 6.11 8.83E+01 8.83E+01 Benzene (kg/d) 4.08 3.13 3.65E+01 3.65E+01 1.59E+01 1.59E+01 Benzo(a)anthracene (kg/d) 3.40E-03 2.58E-03 0.00 0.00 1.02E-04 1.02E-04 Benzo(a)pyrene (kg/d) 7.46E-04 5.65E-04 0.00 0.00 6.77E-05 6.77E-05 Benzo(b)fluoranthene (kg/d) 3.03E-03 2.30E-03 0.00 0.00 1.02E-04 1.02E-04 Benzo(g,h,i)perylene (kg/d) 1.72E-03 1.30E-03 0.00 0.00 6.77E-05 6.77E-05 Benzo(k)fluoranthene (kg/d) 6.45E-04 4.89E-04 0.00 0.00 1.02E-04 1.02E-04 Carbon Disulphide (kg/d) 8.91 8.91 5.67 5.67 2.06E-01 2.06E-01 Carbonyl Sulphide (kg/d) 5.18E+01 5.18E+01 1.81E+01 1.81E+01 2.26E-01 2.26E-01 Chrysene (kg/d) 3.67E-03 2.78E-03 0.00 0.00 1.02E-04 1.02E-04 Dibenzo(a,h)anthracene (kg/d) 1.65E-03 1.25E-03 0.00 0.00 6.77E-05 6.77E-05 Dichlorobenzene (kg/d) 0.00 0.00 0.00 0.00 6.77E-02 6.77E-02 Ethylbenzene (kg/d) 9.24E-01 9.24E-01 1.06E+01 1.06E+01 7.48 7.48 Fluoranthene (kg/d) 1.94E-02 1.47E-02 0.00 0.00 1.69E-04 1.69E-04 Fluorene (kg/d) 7.09E-02 5.37E-02 0.00 0.00 1.58E-04 1.58E-04 Formaldehyde (kg/d) 2.41 1.83 0.00 0.00 4.23 4.23 Hydrogen Sulphide (kg/d) 1.56 1.56 2.13E+01 2.13E+01 1.60 1.60 Indeno(1,2,3-cd)pyrene (kg/d) 1.29E-03 9.78E-04 0.00 0.00 1.02E-04 1.02E-04 Mercaptans (kg/d) 3.73E-01 3.73E-01 4.76E-02 4.76E-02 4.57E-03 4.57E-03 Naphthalene (kg/d) 5.21E-01 4.12E-01 0.00 0.00 3.43E-02 3.43E-02 n-hexane (kg/d) 0.00 0.00 0.00 0.00 1.02E+02 1.02E+02 n-pentane (kg/d) 0.00 0.00 0.00 0.00 1.47E+02 1.47E+02 Phenanthrene (kg/d) 1.40E-01 1.06E-01 0.00 0.00 9.59E-04 9.59E-04 Pyrene (kg/d) 1.45E-02 1.10E-02 0.00 0.00 2.82E-04 2.82E-04 Thiophenes (kg/d) 5.96E-01 5.96E-01 3.70E+01 3.70E+01 9.26E-01 9.26E-01 Toluene (kg/d) 8.96 8.63 5.27E+01 5.27E+01 4.52E+01 4.52E+01 Xylenes (kg/d) 7.06 6.84 6.48E+01 6.48E+01 1.77E+01 1.77E+01



December 2009

Page B4-37

2.19 Whitesands In-situ Partnership

Table B4-35: Summary of Whitesands VOC and PAH Air Emissions Used for the Baseline, Project and

Planned Development Scenarios Emission Source

Pilot & May River UTM North - NE 6,170,900 UTM East - NE 483,800 UTM North - SE 6,168,500 UTM East - SE 483,800 UTM North - SW 6,168,500 UTM East - SW 482,050 UTM North - NW 6,170,900 UTM East - NW 482,050 Area (km2) 0.100 Elevation (m) 650 1,3-Butadiene (kg/d) 0.00 2-MethylNaphthalene (kg/d) 1.38E-04 3-Methylcholanthrene (kg/d) 1.04E-05 7,12-Dimethylbenz(a)anthracene (kg/d) 9.21E-05 Acenaphthene (kg/d) 1.04E-05 Acenaphthylene (kg/d) 1.04E-05 Acetaldehyde (kg/d) 0.00 Acrolein (kg/d) 0.00 Aliphatic& C19-C34 (kg/d) 0.00 Aliphatic& C5-C8 (kg/d) 0.00 Aliphatic& C9-C18 (kg/d) 0.00 Anthracene (kg/d) 1.38E-05 Aromatic (kg/d) 0.00 Benzene (kg/d) 1.21E-02 Benzo(a)anthracene (kg/d) 1.04E-05 Benzo(a)pyrene (kg/d) 6.91E-06 Benzo(b)fluoranthene (kg/d) 1.04E-05 Benzo(g,h,i)perylene (kg/d) 6.91E-06 Benzo(k)fluoranthene (kg/d) 1.04E-05 Carbon Disulphide (kg/d) 0.00 Carbonyl Sulphide (kg/d) 0.00 Chrysene (kg/d) 1.04E-05 Dibenzo(a,h)anthracene (kg/d) 6.91E-06 Dichlorobenzene (kg/d) 6.91E-03 Ethylbenzene (kg/d) 0.00 Fluoranthene (kg/d) 1.73E-05 Fluorene (kg/d) 1.61E-05 Formaldehyde (kg/d) 4.32E-01 Hydrogen Sulphide (kg/d) 0.00 Indeno(1,2,3-cd)pyrene (kg/d) 1.04E-05 Mercaptans (kg/d) 0.00 Naphthalene (kg/d) 3.51E-03 n-hexane (kg/d) 1.04E+01 n-pentane (kg/d) 1.50E+01 Phenanthrene (kg/d) 9.78E-05 Pyrene (kg/d) 2.88E-05 Thiophenes (kg/d) 0.00 Toluene (kg/d) 1.96E-02 Xylenes (kg/d) 0.00


December 2009

Page B4-38

3.0 COMMUNITIES AND HIGHWAYS

The emissions from communities and highways located within the RSA are included in all three of the emission scenarios. Tables B4-36 to B4-37 present a summary of the emission data.

Table B4-36: Summary of Community VOC and PAH Air Emissions Used for the Baseline and Project Scenarios

Emission Source Community

Anzac Fort McKay

Fort McMurray

Janvier/ Chard

Fort Chipewyan

UTM North 6,255,500 6,337,500 6,283,000 6,198,500 6,508,000 UTM East 497,400 462,750 479,500 517,200 491,000 Elevation (m) 505 251 330 470 210 Population 712 481 61722 600 992 1,3-Butadiene (kg/d) 3.76E-02 2.54E-02 4.92E+00 3.18E-02 5.25E-02 2-MethylNaphthalene (kg/d) 7.19E-05 4.85E-05 9.39E-03 6.07E-05 1.00E-04 3-Methylcholanthrene (kg/d) 5.39E-06 3.64E-06 7.04E-04 4.55E-06 7.51E-06 7,12-Dimethylbenz(a)anthracene (kg/d) 4.79E-05 3.24E-05 6.26E-03 4.04E-05 6.68E-05 Acenaphthene (kg/d) 3.43E-03 2.32E-03 4.49E-01 2.90E-03 4.79E-03 Acenaphthylene (kg/d) 7.74E-03 5.23E-03 1.01E+00 6.54E-03 1.08E-02 Acetaldehyde (kg/d) 3.81E-01 2.58E-01 4.98E+01 3.22E-01 5.32E-01 Acrolein (kg/d) 4.83E-02 3.27E-02 6.32E+00 4.08E-02 6.74E-02 Aliphatic& C19-C34 (kg/d) 0.00 0.00 0.00E+00 0.00 0.00 Aliphatic& C5-C8 (kg/d) 0.00 0.00 0.00E+00 0.00 0.00 Aliphatic& C9-C18 (kg/d) 0.00 0.00 0.00E+00 0.00 0.00 Anthracene (kg/d) 1.47E-03 9.95E-04 1.93E-01 1.24E-03 2.06E-03 Aromatic (kg/d) 0.00 0.00 0.00E+00 0.00 0.00 Benzene (kg/d) 9.93E-01 6.70E-01 1.29E+02 8.36E-01 1.38 Benzo(a)anthracene (kg/d) 8.59E-04 5.81E-04 1.12E-01 7.25E-04 1.20E-03 Benzo(a)pyrene (kg/d) 1.91E-04 1.29E-04 2.50E-02 1.61E-04 2.67E-04 Benzo(b)fluoranthene (kg/d) 7.67E-04 5.18E-04 1.00E-01 6.47E-04 1.07E-03 Benzo(g,h,i)perylene (kg/d) 4.36E-04 2.94E-04 5.69E-02 3.68E-04 6.08E-04 Benzo(k)fluoranthene (kg/d) 1.68E-04 1.13E-04 2.19E-02 1.41E-04 2.34E-04 Carbon Disulphide (kg/d) 0.00 0.00 0.00E+00 0.00 0.00 Carbonyl Sulphide (kg/d) 0.00 0.00 0.00E+00 0.00 0.00 Chrysene (kg/d) 9.28E-04 6.27E-04 1.21E-01 7.83E-04 1.29E-03 Dibenzo(a,h)anthracene (kg/d) 4.19E-04 2.83E-04 5.47E-02 3.54E-04 5.84E-04 Dichlorobenzene (kg/d) 3.59E-03 2.43E-03 4.69E-01 3.03E-03 5.01E-03 Ethylbenzene (kg/d) 0.00 0.00 0.00E+00 0.00 0.00 Fluoranthene (kg/d) 4.87E-03 3.29E-03 6.37E-01 4.11E-03 6.80E-03 Fluorene (kg/d) 1.78E-02 1.20E-02 2.33E+00 1.51E-02 2.49E-02 Formaldehyde (kg/d) 8.31E-01 5.61E-01 1.09E+02 7.01E-01 1.16 Hydrogen Sulphide (kg/d) 0.00 0.00 0.00E+00 0.00 0.00 Indeno(1,2,3-cd)pyrene (kg/d) 3.30E-04 2.23E-04 4.31E-02 2.78E-04 4.60E-04 Mercaptans (kg/d) 0.00 0.00 0.00E+00 0.00 0.00 Naphthalene (kg/d) 1.15E-01 7.77E-02 1.50E+01 9.69E-02 1.60E-01 n-hexane (kg/d) 5.39 3.64 7.04E+02 4.55 7.52 n-pentane (kg/d) 7.78 5.26 1.02E+03 6.57 1.09E+01 Phenanthrene (kg/d) 3.53E-02 2.39E-02 4.62E+00 2.98E-02 4.93E-02 Pyrene (kg/d) 3.66E-03 2.47E-03 4.78E-01 3.09E-03 5.11E-03 Thiophenes (kg/d) 0.00 0.00 0.00E+00 0.00 0.00 Toluene (kg/d) 3.41E-01 2.30E-01 4.48E+01 2.87E-01 4.75E-01 Xylenes (kg/d) 2.31E-01 1.56E-01 3.01E+01 1.95E-01 3.22E-01


December 2009

Page B4-39

Table B4-37: Summary of Highway VOC and PAH Air Emissions Used for the Baseline and Project Scenarios

Emission Source Highway Hwy 63a Hwy 63b Hwy 881 Hwy 69

UTM North - NE 6,315,000 6,333,000 6,287,300 6,275,665 UTM East - NE 470,015 463,515 476,115 492,900 UTM North - SE 6,287,500 6,315,000 6,209,900 6,275,650 UTM East - SE 474,015 470,015 508,515 492,900 UTM North - SW 6,287,500 6,315,000 6,209,900 6,280,150 UTM East - SW 474,000 470,000 508,500 478,500 UTM North - NW 6,315,000 6,333,000 6,287,300 6,280,165 UTM East - NW 470,000 463,500 476,100 478,500 Area (km2) 416,841 287,065 1,258,617 226,301 Elevation (m) 338 316 532 370 1,3-Butadiene (kg/d) 8.77E-03 4.26E-03 5.46E-03 5.46E-03 2-MethylNaphthalene (kg/d) 0.00 0.00 0.00 0.00 3-Methylcholanthrene (kg/d) 0.00 0.00 0.00 0.00 7,12-Dimethylbenz(a)anthracene (kg/d) 0.00 0.00 0.00 0.00 Acenaphthene (kg/d) 7.99E-04 3.88E-04 4.98E-04 4.98E-04 Acenaphthylene (kg/d) 1.80E-03 8.76E-04 1.12E-03 1.12E-03 Acetaldehyde (kg/d) 8.89E-02 4.32E-02 5.54E-02 5.54E-02 Acrolein (kg/d) 1.13E-02 5.47E-03 7.02E-03 7.02E-03 Aliphatic& C19-C34 (kg/d) 0.00 0.00 0.00 0.00 Aliphatic& C5-C8 (kg/d) 0.00 0.00 0.00 0.00 Aliphatic& C9-C18 (kg/d) 0.00 0.00 0.00 0.00 Anthracene (kg/d) 3.42E-04 1.66E-04 2.13E-04 2.13E-04 Aromatic (kg/d) 0.00 0.00 0.00 0.00 Benzene (kg/d) 2.29E-01 1.11E-01 1.43E-01 1.43E-01 Benzo(a)anthracene (kg/d) 1.99E-04 9.67E-05 1.24E-04 1.24E-04 Benzo(a)pyrene (kg/d) 4.37E-05 2.12E-05 2.72E-05 2.72E-05 Benzo(b)fluoranthene (kg/d) 1.77E-04 8.62E-05 1.11E-04 1.11E-04 Benzo(g,h,i)perylene (kg/d) 1.01E-04 4.89E-05 6.27E-05 6.27E-05 Benzo(k)fluoranthene (kg/d) 3.78E-05 1.84E-05 2.35E-05 2.35E-05 Carbon Disulphide (kg/d) 0.00 0.00 0.00 0.00 Carbonyl Sulphide (kg/d) 0.00 0.00 0.00 0.00 Chrysene (kg/d) 2.15E-04 1.04E-04 1.34E-04 1.34E-04 Dibenzo(a,h)anthracene (kg/d) 9.68E-05 4.70E-05 6.03E-05 6.03E-05 Dichlorobenzene (kg/d) 0.00 0.00 0.00 0.00 Ethylbenzene (kg/d) 0.00 0.00 0.00 0.00 Fluoranthene (kg/d) 1.13E-03 5.51E-04 7.06E-04 7.06E-04 Fluorene (kg/d) 4.16E-03 2.02E-03 2.59E-03 2.59E-03 Formaldehyde (kg/d) 1.41E-01 6.86E-02 8.80E-02 8.80E-02 Hydrogen Sulphide (kg/d) 0.00 0.00 0.00 0.00 Indeno(1,2,3-cd)pyrene (kg/d) 7.56E-05 3.67E-05 4.71E-05 4.71E-05 Mercaptans (kg/d) 0.00 0.00 0.00 0.00 Naphthalene (kg/d) 2.59E-02 1.30E-02 1.64E-02 1.64E-02 n-hexane (kg/d) 0.00 0.00 0.00 0.00 n-pentane (kg/d) 0.00 0.00 0.00 0.00 Phenanthrene (kg/d) 8.22E-03 3.99E-03 5.12E-03 5.12E-03 Pyrene (kg/d) 8.50E-04 4.13E-04 5.29E-04 5.29E-04 Thiophenes (kg/d) 0.00 0.00 0.00 0.00 Toluene (kg/d) 7.69E-02 3.80E-02 4.84E-02 4.84E-02 Xylenes (kg/d) 5.36E-02 2.59E-02 3.37E-02 3.37E-02


December 2009

Page B4-40

Table B4-38: Summary of Community VOC and PAH Air Emissions Used for the Planned Development Scenario

Community Emission Source Anzac Fort McKay

Fort McMurray

Janvier/ Chard

Fort Chipewyan

UTM North 6,255,500 6,337,500 6,283,000 6,198,500 6,508,000 UTM East 497,400 462,750 479,500 517,200 491,000 Elevation (m) 505 251 330 470 210 Population 1491 1007 120000 1256 2077 1,3-Butadiene (kg/d) 7.90E-02 5.34E-02 9.56E+00 6.65E-02 1.10E-01 2-MethylNaphthalene (kg/d) 1.51E-04 1.02E-04 1.83E-02 1.27E-04 2.09E-04 3-Methylcholanthrene (kg/d) 1.13E-05 7.63E-06 1.37E-03 9.52E-06 1.57E-05 7,12-Dimethylbenz(a)anthracene (kg/d) 1.00E-04 6.79E-05 1.22E-02 8.47E-05 1.40E-04 Acenaphthene (kg/d) 7.21E-03 4.85E-03 8.73E-01 6.07E-03 1.00E-02 Acenaphthylene (kg/d) 1.62E-02 1.10E-02 1.97E+00 1.37E-02 2.26E-02 Acetaldehyde (kg/d) 8.00E-01 5.40E-01 9.69E+01 6.74E-01 1.11 Acrolein (kg/d) 1.01E-01 6.85E-02 1.23E+01 8.55E-02 1.41E-01 Aliphatic& C19-C34 (kg/d) 0.00E+00 0.00E+00 0.00E+00 0.00 0.00 Aliphatic& C5-C8 (kg/d) 0.00E+00 0.00E+00 0.00E+00 0.00 0.00 Aliphatic& C9-C18 (kg/d) 0.00E+00 0.00E+00 0.00E+00 0.00 0.00 Anthracene (kg/d) 3.09E-03 2.09E-03 3.75E-01 2.61E-03 4.30E-03 Aromatic (kg/d) 0.00E+00 0.00E+00 0.00E+00 0.00 0.00 Benzene (kg/d) 2.08E+00 1.40E+00 2.52E+02 1.75 2.90 Benzo(a)anthracene (kg/d) 1.80E-03 1.22E-03 2.18E-01 1.52E-03 2.50E-03 Benzo(a)pyrene (kg/d) 4.00E-04 2.70E-04 4.86E-02 3.38E-04 5.57E-04 Benzo(b)fluoranthene (kg/d) 1.61E-03 1.09E-03 1.95E-01 1.36E-03 2.24E-03 Benzo(g,h,i)perylene (kg/d) 9.14E-04 6.16E-04 1.11E-01 7.70E-04 1.27E-03 Benzo(k)fluoranthene (kg/d) 3.51E-04 2.38E-04 4.26E-02 2.96E-04 4.88E-04 Carbon Disulphide (kg/d) 0.00E+00 0.00E+00 0.00E+00 0.00 0.00 Carbonyl Sulphide (kg/d) 0.00E+00 0.00E+00 0.00E+00 0.00 0.00 Chrysene (kg/d) 1.94E-03 1.31E-03 2.36E-01 1.64E-03 2.70E-03 Dibenzo(a,h)anthracene (kg/d) 8.75E-04 5.94E-04 1.06E-01 7.41E-04 1.22E-03 Dichlorobenzene (kg/d) 7.50E-03 5.10E-03 9.13E-01 6.35E-03 1.05E-02 Ethylbenzene (kg/d) 0.00E+00 0.00E+00 0.00E+00 0.00 0.00 Fluoranthene (kg/d) 1.02E-02 6.91E-03 1.24E+00 8.62E-03 1.42E-02 Fluorene (kg/d) 3.73E-02 2.52E-02 4.53E+00 3.15E-02 5.20E-02 Formaldehyde (kg/d) 1.74E+00 1.18E+00 2.11E+02 1.47 2.42 Hydrogen Sulphide (kg/d) 0.00E+00 0.00E+00 0.00E+00 0.00 0.00 Indeno(1,2,3-cd)pyrene (kg/d) 6.91E-04 4.67E-04 8.38E-02 5.83E-04 9.61E-04 Mercaptans (kg/d) 0.00E+00 0.00E+00 0.00E+00 0.00 0.00 Naphthalene (kg/d) 2.41E-01 1.63E-01 2.93E+01 2.03E-01 3.35E-01 n-hexane (kg/d) 1.13E+01 7.63E+00 1.37E+03 9.53 1.57E+01 n-pentane (kg/d) 1.63E+01 1.10E+01 1.98E+03 1.38E+01 2.27E+01 Phenanthrene (kg/d) 7.41E-02 4.99E-02 8.98E+00 6.25E-02 1.03E-01 Pyrene (kg/d) 7.65E-03 5.18E-03 9.30E-01 6.47E-03 1.07E-02 Thiophenes (kg/d) 0.00E+00 0.00E+00 0.00E+00 0.00 0.00 Toluene (kg/d) 7.16E-01 4.81E-01 8.71E+01 6.01E-01 9.94E-01 Xylenes (kg/d) 4.84E-01 3.26E-01 5.85E+01 4.08E-01 6.74E-01


December 2009

Page B4-41

Table B4-39: Summary of Highway VOC and PAH Air Emissions Used for the Planned Development Scenario

Emission Source Highway Hwy 63a Hwy 63b Hwy 881 Hwy 69

UTM North - NE 6,315,000 6,333,000 6,287,300 6,275,665 UTM East - NE 470,015 463,515 476,115 492,900 UTM North - SE 6,287,500 6,315,000 6,209,900 6,275,650 UTM East - SE 474,015 470,015 508,515 492,900 UTM North - SW 6,287,500 6,315,000 6,209,900 6,280,150 UTM East - SW 474,000 470,000 508,500 478,500 UTM North - NW 6,315,000 6,333,000 6,287,300 6,280,165 UTM East - NW 470,000 463,500 476,000 478,500 Area (km2) 841 287 65 1 Elevation (m) 338 316 532 370 1,3-Butadiene (kg/d) 1.43E-02 6.93E-03 8.93E-03 8.93E-03 2-MethylNaphthalene (kg/d) 0.00 0.00 0.00 0.00 3-Methylcholanthrene (kg/d) 0.00 0.00 0.00 0.00 7,12-Dimethylbenz(a)anthracene (kg/d) 0.00 0.00 0.00 0.00 Acenaphthene (kg/d) 1.30E-03 6.32E-04 8.14E-04 8.14E-04 Acenaphthylene (kg/d) 2.94E-03 1.43E-03 1.84E-03 1.84E-03 Acetaldehyde (kg/d) 1.45E-01 7.03E-02 9.05E-02 9.05E-02 Acrolein\ (kg/d) 1.84E-02 8.91E-03 1.15E-02 1.15E-02 Aliphatic& C19-C34 (kg/d) 0.00 0.00 0.00 0.00 Aliphatic& C5-C8 (kg/d) 0.00 0.00 0.00 0.00 Aliphatic& C9-C18 (kg/d) 0.00 0.00 0.00 0.00 Anthracene (kg/d) 5.57E-04 2.70E-04 3.48E-04 3.48E-04 Aromatic (kg/d) 0.00 0.00 0.00 0.00 Benzene (kg/d) 3.73E-01 1.82E-01 2.33E-01 2.33E-01 Benzo(a)anthracene (kg/d) 3.24E-04 1.57E-04 2.03E-04 2.03E-04 Benzo(a)pyrene (kg/d) 7.12E-05 3.46E-05 4.45E-05 4.45E-05 Benzo(b)fluoranthene (kg/d) 2.89E-04 1.40E-04 1.81E-04 1.81E-04 Benzo(g,h,i)perylene (kg/d) 1.64E-04 7.96E-05 1.03E-04 1.03E-04 Benzo(k)fluoranthene (kg/d) 6.16E-05 2.99E-05 3.85E-05 3.85E-05 Carbon Disulphide (kg/d) 0.00 0.00 0.00 0.00 Carbonyl Sulphide (kg/d) 0.00 0.00 0.00 0.00 Chrysene (kg/d) 3.50E-04 1.70E-04 2.19E-04 2.19E-04 Dibenzo(a,h)anthracene (kg/d) 1.58E-04 7.65E-05 9.86E-05 9.86E-05 Dichlorobenzene (kg/d) 0.00 0.00 0.00 0.00 Ethylbenzene (kg/d) 0.00 0.00 0.00 0.00 Fluoranthene (kg/d) 1.85E-03 8.96E-04 1.15E-03 1.15E-03 Fluorene (kg/d) 6.77E-03 3.28E-03 4.23E-03 4.23E-03 Formaldehyde (kg/d) 2.30E-01 1.12E-01 1.44E-01 1.44E-01 Hydrogen Sulphide (kg/d) 0.00 0.00 0.00 0.00 Indeno(1,2,3-cd)pyrene (kg/d) 1.23E-04 5.98E-05 7.70E-05 7.70E-05 Mercaptans (kg/d) 0.00 0.00 0.00 0.00 Naphthalene (kg/d) 4.32E-02 2.07E-02 2.68E-02 2.68E-02 n-hexane (kg/d) 0.00 0.00 0.00 0.00 n-pentane (kg/d) 0.00 0.00 0.00 0.00 Phenanthrene (kg/d) 1.34E-02 6.50E-03 8.37E-03 8.37E-03 Pyrene (kg/d) 1.38E-03 6.72E-04 8.65E-04 8.65E-04 Thiophenes (kg/d) 0.00 0.00 0.00 0.00 Toluene (kg/d) 1.26E-01 6.13E-02 7.86E-02 7.86E-02 Xylenes (kg/d) 8.73E-02 4.23E-02 5.44E-02 5.44E-02


December 2009

Page B4-42


Canadian Natural Resources Ltd. 2003. Horizon Oil Sands Project Update. Prepared by Golder Associates Ltd. Calgary, AB.

Clearstone Engineering Ltd., Alberta Research Council and QED Consultants Ltd. (Clearstone et al.).1998. Syncrude Mildred Lake Site: Assessment of Fugitive Emissions. Prepared for Syncrude Canada Ltd. Calgary, AB.

Deer Creek Energy Limited. 2007. Joslyn North Mine Project Updated Air Quality Assessment. Air Quality Section Prepared by AMEC. Calgary, AB.

EnCana Corp. (EnCana). 2007. Borealis In-Situ Project Application & Environmental Impact Assessment. Air Quality Section Prepared by AMEC E&E. Calgary, AB

Imperial Oil Resources. 2005. Kearl Oil Sands Project – Mine Development. Prepared by Golder Associates Ltd. Calgary, AB.

Suncor Energy Inc. 2003. South Tailings Pond Project Application. Prepared by Golder Associates Ltd. Calgary, AB.

TrueNorth Energy. 2001. Fort Hills Oil Sands Project. Application and Environmental Impact Assessment. Prepared by AXYS Environmental Consultants. Calgary, AB.

Appendix B5

Baseline, Application and Planned Development Model Predictions

This section has been reissued in Volume 4, Appendix B5

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