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Actual. Forecast. Figure 1.1 Price of WTI at Chicago. Actual. Forecast. Figure 1.2 Average price of oil at Alberta wellhead. Actual. Forecast. Figure 1.3 Average price of natural gas at plant gate. Figure 1.4. Alberta gas well cost estimations - PowerPoint PPT Presentation
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0
50
100
150
200
250
300
350
400
1995 1998 2001 2004 2007 2010 2013
$U
S/C
ub
ic M
etr
e
05101520253035404550556065
$U
S/B
bl
Figure 1.1 Price of WTI at Chicago
Actual Forecast
0
50
100
150
200
250
300
350
400
450
1995 1998 2001 2004 2007 2010 2013
$C
dn
/cu
bic
me
tre
0
8
16
24
32
40
48
56
64
72
$C
dn
/ba
rre
l
current $/m3 constant 2004$
Figure 1.2 Average price of oil at Alberta wellhead
Actual Forecast
0
1
2
3
4
5
6
7
8
9
1995 1998 2001 2004 2007 2010 2013
$C
dn
/gig
ajo
ule
Current $/GJ Constant 2004 $/GJ
Figure 1.3 Average price of natural gas at plant gate
Actual Forecast
Figure 1.4. Alberta gas well cost estimationsDrilling, casing and completion costs estimates (in millions 2003$)
By Modified PSAC Area
2002 2004
Area 1Area 1
Area 2Area 2
Area 3Area 3
Area 4Area 4Area 5Area 5
Area 6Area 6Area 7Area 7
•Source: PSAC 2004 Well Cost study (2003 dollars) and PSAC 2002 Well Cost study
(2001 dollars)
2.29
0.18
0.42
0.73 1.79
0.270.42 0.45 0.29
1.97 0.82
0.45
0.18
2.29
0.0% 4.8%
5.5% 12.0%
12.3%
6.2%5.5%
increase in costs (in percentage, over 2 years)
Figure 1.5. Alberta oil well cost estimationsDrilling, casing and completion costs estimates. (in millions 2003$)
By Modified PSAC Area
Area 3Area 3
Area 4Area 4Area 5Area 5
Area 7Area 7
•Source: PSAC 2004 Well Cost study (2003 dollars) and PSAC 2002 Well Cost study
(2001 dollars)
2002 2004
0.78
0.610.53
0.66
0.85
0.640.52
0.75
13.2%
-2.1%4.3%
9.0%
increase in costs (in percentage, over 2 years)
77.0
71.6
63.764.6
67.3
67.3
67.5
72.272.9 73.3
60
65
70
75
80
1995 1996 1997 1998 1999 2000 2001 2002 2003 2004C
en
ts
Exchange Rate
5.34.4
2.7
1.6
4.1
5.5
1.5
3.5
2.3
2.7
7.207.60
6.807.60
9.70
8.30
7.20
9.509.20
7.60
0
2
4
6
8
10
12
1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Pe
rc
en
ta
ge
Real GDP Growth Unemployment Rate
2.7
1.62.2
1.60.9
1.7
2.62.2
2.81.9
4.04.2
7.3
6.46.1
6.65.8
8.7
5.04.7
0
2
4
6
8
10
12
1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Pe
rc
en
ta
ge
Inflation Rate Prime Rate on Loans
Figure 1.6. Canadian economic indicators
0.0
1.0
2.0
3.0
4.0
5.0
6.0
7.0
8.0
9.0
1995 1998 2001 2004 2007 2010 2013
Per
cen
t
Unemployment Rate Inflation Rate Real GDP Growth Rate
Figure 1.7. Alberta GDP growth, unemployment & inflation rates
Actual Forecast
Figure 2.1. Alberta’s three oil sands areas
0
5
10
15
20
25
30
Initial Reserves Remaining Reserves
109 m
3
Crude Oil Crude Bitumen
Figure 2.2. Comparison of Alberta’s crude oil and crude bitumen reserves
Figure 2.3. Bitumen pay isopachs for the Athabasca
Wabiskaw-McMurray deposit at 6 mass per cent cutoff and greater than 1.5
metres
Figure 2.4. Net pay isopachs for recoverable
bitumen within the Athabasca Wabiskaw-
McMurray at 6 mass per cent cutoff and greater than
10 metres
ATHABASCA
COLD LAKE
PEACE RIVER
2.517.5
41.4
111.7
Figure 2.5. Production of bitumen in Alberta2004 103 m3/d
Mined Bitumen
In Situ
0%
20%
40%
60%
80%
100%
1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Per
cen
tag
e
Conventional Crude Oil & Pentanes Plus SCO & Bitumen
Figure 2.6. Alberta crude oil and equivalent production
Figure 2.7. Alberta crude bitumen production
0
50
100
150
200
250
300
350
400
450
1995 1997 1999 2001 2003 2005 2007 2009 2011 2013
103 m
3 /d
ForecastActual
Surface Mining
In Situ
0
2000
4000
6000
8000
1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Num
ber o
f Wel
ls
0
20
40
60
80
Pro
du
ctio
n (1
03 m
3/d)
Producing Wells Production
Figure 2.8. Total in situ bitumen production and producing bitumen wells
Figure 2.9. Alberta synthetic crude oil production
0
50
100
150
200
250
300
1995 1997 1999 2001 2003 2005 2007 2009 2011 2013
103 m
3 /d
ForecastActual
Synthetic Crude Oil
Figure 2.10. Alberta Demand and Disposition of Crude Bitumen and SCO
0
50
100
150
200
250
300
350
400
1995 1997 1999 2001 2003 2005 2007 2009 2011 2013
103 m
3 /d
ForecastActual
SCORemovals from Alberta
Nonupgraded Bitumen Removals from Alberta
Alberta Demand (mainly SCO)
Figure 3.1. Remaining established reserves of crude oil
0
100
200
300
400
500
600
700
800
1979 1983 1987 1991 1995 1999 2003
106 m
3
Light-medium
Heavy
Figure 3.2. Annual changes in conventional crude oil reserves
-30
-20
-10
0
10
20
30
40
50
60
1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
106 m
3
Additions Revisions
Figure 3.3. Annual changes to waterflood reserves
-10
-5
0
5
10
15
20
25
106 m
3
1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
New Waterflood Waterflood Revisions
Fig. 3.4. Distribution of oil reserves by size(103m3)
% Total Number of Pools
>1000
100-999
30-99
'1-29
% Initial Reserves
% Remaining Reserves
0
50
100
150
200
250
300
350
1970 1975 1980 1985 1990 1995 2000
Initi
al E
stab
lishe
d R
eser
ves
(106 m
3 )
Average Median
Figure 3.5. Oil pool size by discovery year
Figure 3.6. Initial established crude oil reserves based on various recovery mechanisms (106 m3)
Primary 1599
Primary273
Waterflood106
Waterflood572
Solvent flood107
Gas flood8
Light-medium Heavy
Figure 3.7. Geological distribution of reserves of conventional crude oil
0
200
400
600
800
1000
1200
1400
UpperCretaceous
LowerCretaceous
Jurassic Triassic Permian-Belloy Mississippian Upper Devonian MiddleDevonian
Rese
rves
(10
6 m3 )
Initial established reserves Remaining established reserves
2004 Initial established reserves2664.9 106 m3
2004 Remaining established reserves249.2 106 m3
258
17
478
49
1193
75
384
45
17614159
45
Fig. 3.8. Regional distribution of Alberta oil reserves
(106 m3)
2
21
Figure 3.9. Alberta’s remaining established oil Reserves versus cumulative production
0
200
400
600
800
1000
1200
1400
500 1000 1500 2000 2500 3000 3500
Cumulative Production (106 m3)
Rem
aini
ng E
stab
lishe
d Oi
l Res
erve
s (1
06 m
3 )
Year 1970
Figure 3.10. Growth in initial established reservesof crude oil
1700
1850
2000
2150
2300
2450
2600
2750
2900
3050
3200
1970 1980 1990 2000 2010 2020 2030 2040
Actual as of December 31,2004
3130Ultimate potentiial
106 m
3
Figure 3.11. Alberta successful oil well drilling
By Modified PSAC Area
62
12
350
679
2
2003 Wells Drilled = 2345
2004 Wells Drilled = 1949
41
8
557389
323
8
616
149 178
534386
Figure 3.13. Initial operating day rates of oil wells placed on production,
2004 By Modified PSAC Area
17.9(112)
12.7(80)
7.3(46)
4.8(30)
7.3(46)
5.5(34)
10.5(66)m3/day/well
(bbl/day/well)Total = 1910 wells
326
3
410 368
609
Figure 3.12. Oil wells placed on production, 2004
By Modified PSAC Area
150
44
0
40
80
120
160
1995 1997 1999 2001 2003
103 m
3 /day
PSAC 8
PSAC 7
PSAC 5
PSAC 4
PSAC 3
PSAC 2
PSAC 1
Figure 3.14. Conventional crude oil productionBy Modified PSAC Area
0
5000
10000
15000
20000
25000
30000
35000
40000
1973 1976 1979 1982 1985 1988 1991 1994 1997 2000 2003
Num
ber o
f Wel
ls
0
50
100
150
200
250
Pro
du
ctio
n (1
03 m
3/d)
Producing Wells Production
Figure 3.15. Total crude oil production and producing oil wells
0
5000
10000
15000
20000
25000
0.0-2.0 2.1-5.0 5.1-8.0 8.1-20.0 20.1-50.0 50.1-100.0 100.1+
Production Category (m3/d)
Nu
mb
er o
f W
ell
s
0
20
40
60
80
100
120
140
160
m3/
d
Producing Wells Average Rate
Figure 3.16. Crude oil well productivity in 2004
0
40
80
120
160
1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Th
ou
san
ds
of C
ub
ic M
etre
s P
er D
ay
2004
2003
2002
2001
2000
1999
1998
1997
1996
1995
Pre-1995
7%
11%
Figure 3.17. Total conventional crude oil Production by year placed on production
4%
6%
3%7%
42%
Percent of totalproduction fromoil wells
6%
6%4%
3%
0
500
1000
1500
2000
2500
3000
3500
4000
1950 1955 1960 1965 1970 1975 1980 1985 1990 1995 2000
10
3 bb
l/dFigure 3.18. Comparison of crude oil production
Texas Onshore
Louisiana OnshoreAlberta Crude Oil
0
1000
2000
3000
4000
5000
1995 1997 1999 2001 2003 2005 2007 2009 2011 2013
Nu
mb
er
of
We
lls
$0$10
$20$30
$40$50
$60$70
US
$/b
bl
Well placed on production WTI @ Chicago
Figure 3.19. Alberta Crude Oil Price and Well Activity
Actual Forecast
Figure 3.20. Alberta daily production of crude oil
0
40
80
120
160
200
1995 1997 1999 2001 2003 2005 2007 2009 2011 2013
Prod
uctio
n (1
03 m
3 /d
)
ForecastActual
Light-Medium Crude Oil
Heavy Crude Oil
0
5000
10000
15000
20000
25000
30000
35000
Imperial, Edmonton
Petro-Canada, Edmonton
Shell, Scotford
Husky, Lloydminster
Parkland, Bowden
Figure 3.21. Capacity and location of Alberta refineries
Re
fin
ery
Cap
aciti
es -
m3/d
Figure 3.22. Alberta demand and disposition of crude oil
0
40
80
120
160
200
1995 1997 1999 2001 2003 2005 2007 2009 2011 2013
103 m
3 /d
ForecastActual
Alberta Demand
Crude Oil Removals from Alberta
Figure 3.23. Alberta supply of crude oil and equivalent
0
50
100
150
200
250
300
350
400
450
1995 1997 1999 2001 2003 2005 2007 2009 2011 2013
103 m
3 /d
ForecastActual
Light-Medium
Heavy
Pentanes Plus
SCO
Nonupgraded Bitumen
Figure 4.1. Alberta successful gas well drilling – coalbed methane
By Modified PSAC Area
2004 Wells Drilled = 1174
151
613
3
407
0
5
10
15
20
2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014
Figure 4.2. Expected coalbed methane production10
9 m3
0
20
40
60
80
100
120
140
160
180
1974 1977 1980 1983 1986 1989 1992 1995 1998 2001 2004
109
m3
Additions Production
Figure 5.1. Annual reserves additions and production of marketable gas
0
200
400
600
800
1000
1200
1400
1600
1800
2000
1975 1977 1979 1981 1983 1985 1987 1989 1991 1993 1995 1997 1999 2001 2003
109
m3
Figure 5.2. Remaining marketable gas reserves
Total = 72 109m3
22
6
Figure 5.3. Alberta unconnected gas reserves,2004
By Modified PSAC Area
4
43
2
16
* Numbers not to scale
15
-20
0
20
40
60
80
100
109 m
3
1999 2000 2001 2002 2003 2004
New Development Revisions
Figure 5.4. New, development, and revisions to marketable gas reserves
Total = 145.9 109m3
12.0 -3.7
Figure 5.5. Marketable Gas Reserves Changes,
2004By Modified PSAC Area 109m3
3.7
0.0 4.9
71.0
17.9
40.1
* Numbers not to scale
Fig. 5.6. Distribution of Gas Reserves by size
(109m3)
% Total Number of Pools
>1500
300-1499
100-299
31-100
'1-30
% Initial Reserves
% Remaining Reserves
0
50
100
150
200
250
300
350
1965 1969 1973 1977 1981 1985 1989 1993 1997 2001
Esta
blis
hed
rese
rves
(106 m
3 )
Average Median
Figure 5.7. Gas pools by size and discovery year
0
200
400
600
800
1000
1200
1400
1600
1800
2000
UpperCretaceous
LowerCretaceous
Jurassic Triassic Permian-Belloy Mississippian Upper Devonian MiddleDevonian
10
9 m3
Initial marketable reserves Remaining marketable reserves
Figure 5.8. Geological distribution of marketable gas reserves
0
200
400
600
800
1000
1200
1400
1600
1800
2000
1984 1986 1988 1990 1992 1994 1996 1998 2000 2002 2004
109 m
3
Sweet Natural Gas
Sour Natural Gas
Figure 5.9. Remaining marketable reserves of sweet andsour gas
Figure 5.10. Expected recovery of natural gas components
20
5060
9045
3530
10
100
35
15 10
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
Methane Ethane Propane Butanes Pentanes plus
Perc
entag
e of C
ompo
nent
Removed at Field Plants Removed at Straddle Plants Marketable Gas
1.5
2.0
2.5
3.0
3.5
4.0
4.5
5.0
5.5
6.0
6.5
7.0
1970 1975 1980 1985 1990 1995 2000 2005 2010 2015 2020 2025 2030 2035 2040
Figure 5.11. Growth of initial established reserves of marketable gas
Ultimate potential (6.52)10
12 m
3 at 3
7.4
MJ/
m3
Actual as of December 31, 2004
Figure 5.12. Gas ultimate potential
0
1000
2000
3000
4000
5000
6000
7000
1973 1975 1977 1979 1981 1983 1985 1987 1989 1991 1993 1995 1997 1999 2001 2003
Remaining reserves
Production
Ultimate potential based on 2004 study
10
9 m
3
Remaining established reserves1127 109 m3
Yet-to-be established reserves1729 109m3
338
43
403
643
155
272
52 109
48
95
52
197
61 36
169
Figure 5.13. Regional Distribution of Alberta Gas Reserves (109 m3)
183
1706
256
953
214
904
220
20490
Initial established reserves4547 109m3
Ultimate Potential: 2004 *1
6276 109 m3
Ultimate Potential: 1991 *2
5600 109m3
1122
439
2349
1176
1044
323 225
180
401 341
103151
889
Figure. 5.14. Regional Distribution of Alberta’s Ultimate Potential for
Conventional Natural Gas (109 m3)
434
315
2374
*1 as-is heating value*2 37.4 MJ/m3
Figure 5.15. Gas in place by geological period
2682
1695
322326
3249
1351
2158
1642
402296
4017
2068
0
500
1000
1500
2000
2500
3000
3500
4000
4500
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24
Geological Age Group
GIP
(109 m
3)
0
20
40
60
80
100
120
140
160
GIP
(T
cf)
1991 Undiscovered1991 Discovered2004 Undiscovered2004 Discovered
Upper Lower Jurassic Triassic Mississippian Devonian Cretaceous Cretaceous
Figure 5.16. Alberta successful gas well drilling - conventional
By Modified PSAC Area
477
243
1482
811
6567
85
2003 Wells Drilled = 12060
2004 Wells Drilled = 12960
469
163
346 357
2049 2562 1792
102
898
6609
0
2000
4000
6000
8000
10000
12000
14000
1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Drilled Connected
Figure 5.17. Successful conventional gas wells drilled and connected
Nu m
b er o
f Wel
ls
Figure 5.19. Initial operating day rates of connections,
2004 By Modified PSAC Area
7(0.25)
19(0.67)
5(0.18)
8(0.28)
5(0.18)
20(0.71)
65(2.30)
4(0.14)103m3/day/well
(MMcf/day/well)Total = 13 059 wells
7107 84
2111
1743 1080
Figure 5.18. Conventional gas well connections,
2004By Modified PSAC Area
263
253
418
0
20
40
60
80
100
120
140
160
180
1995 1997 1999 2001 2003
Connection Year
109
m3
PSAC 8
PSAC 7
PSAC 6
PSAC 5
PSAC 4
PSAC 3
PSAC 2
PSAC 1
Gas from OilWells
Figure 5.20. Marketable gas productionBy Modified PSAC Area
10%
6%
38%
18%
5%
12%
4%5%2%
0
20,000
40,000
60,000
80,000
100,000
1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
0
20
40
60
80
100
120
140
160
Producing gas wells Production
Figure 5.21. Conventional marketable gas production and the number of producing gas wells
109
m3
Num
ber o
f Wel
ls
0
10,000
20,000
30,000
40,000
50,000
60,000
0.0-2.0 2.1-5.0 5.1-8.0 8.1-20.0 20.1-50.0 50.1-100.0 100.1+
Production Category (103m3/d)
Nu
mb
er o
f W
ells
0
50
100
150
200
250
103 m
3 /d
Producing Wells Average Rate
Figure 5.22. Natural gas well productivity in 2004
Connection Year
0
20
40
60
80
100
120
140
160
180
1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Prod
uctio
n (1
09 m3 )
2004
2003
2002
2001
2000
1999
1998
1997
1996
1995
Pre 1995
Gas from OilWells
Percentage ofTotal Production from Gas Wells in 2004
26%
13%
16%
11%
9 %
5 %
Figure 5.23. Raw gas production by connection year
7 %
5 % 4 %
3 % 2%
0
5
10
15
20
25
1995 1996 1997 1998 1999 2000 2001 2002 2003
Connection Year
Pro
duct
ivity
(103 m
3 /d)
Average initial productivities for the provinceAverage initial productivities for the province excluding PSAC area 3Average initial productivities for PSAC Area 3
Figure 5.24. Average initial natural gas well productivity in Alberta
0
2000
4000
6000
8000
10000
12000
14000
16000
1995 1998 2001 2004 2007 2010 2013
Num
ber
of W
ells
$0
$1
$2
$3
$4
$5
$6
$7
$8
$9
$Can
/GJ
New Well Connections Alberta Plant Gate Price
Figure 5.25. Alberta Natural Gas Well Activity and Price
Actual Forecast
Figure 5.26. Disposition of conventional marketable gas production
0
50
100
150
200
1995 1997 1999 2001 2003 2005 2007 2009 2011 2013
Actual Forecast
1 09 m
3
Tcf
7.1
5.3
3.6
1.8
25% 23% 27% 36% 42%
Removals from Alberta Alberta Demand
Figure 5.27. Comparison of natural gas production
0
2
4
6
8
10
12
1956 1961 1966 1971 1976 1981 1986 1991 1996 2001
Tcf
Texas Onshore
Louisiana Onshore
Alberta
0
2000
4000
6000
8000
10000
12000
14000
1995 1997 1999 2001 2003 2005 2007 2009 2011 2013
Process Gas from Upgrading Operations Gas from Bitumen Wells
Figure 5.28. Gas production from bitumen upgrading and bitumen wells10
6 m
3
Actual Forecast
0
50
100
150
200
1995 1997 1999 2001 2003 2005 2007 2009 2011 2013
Conventional Marketable Gas Coalbed Methane
Process Gas from Upgrading Bitumen Gas from Bitumen Wells
Figure 5.29. Total gas production in Alberta10
9 m
3
Actual Forecast
Figure 5.30. Alberta natural gas storage injection/withdrawal volumes
-1000
-500
0
500
1000
1500
2000
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
2002 2003 2004
106 m
3
Figure 5.31. Alberta marketable gas demand by sector
0
10
20
30
40
50
60
1995 1997 1999 2001 2003 2005 2007 2009 2011 2013
109 m
3
Actual Forecast
Residential
Commercial
Industrial – Oil Sands
Industrial - Petrochemical
Other Industrial
Electricity Generation
Transportation
Re-processing Plant Shrinkage
Figure 6.1. Remaining established NGL reserves expected to be extracted and annual production
0
20
40
60
80
100
120
140
Ethane Propane Butanes Pentanes Plus
Liq
uid
vo
lum
e (1
06 m
3 )
Reserves Annual Production
Figure 6.2. Remaining established reserves of natural gas liquids
0
50
100
150
200
250
1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Esta
blis
hed
Res
erve
s (1
06 m3 )
Ethane Propane Butanes Pentanes plus
Figure 6.3. Schematic of Alberta NGL flows
Alberta Gas & NGL Market
Alberta Gas & NGL Market
- NGL Mix- Ethane- Propane- Butanes- Pentanes Plus
FieldPlantsField
Plants Marketable Gas
Raw Gas
Extraction Plant- Ethane- Propane- Butanes- Pentanes Plus
Chicago, IL
Other CanadianMarkets
Other CanadianMarkets
US MarketsUS Markets
AlbertaBorder
Crude
Oil
Fractionation Plants- Ethane- Propane- Butanes- Pentanes Plus
Propane
Butanes
Straddle Plants- NGL Mix- Ethane- Propane- Butanes- Pentanes Plus
Oil PoolsOil Pools RefineriesRefineries
Alliance High Pressure Pipeline
Gas PoolsGas
Pools
SulphurSulphur
BatteryBatteryBattery
Dry Gas
NGL MixSpec productRich gas
R
R
R
R Point royalties collected
Dry or rich gas
Figure 6.4. Ethane supply and demand
0
10
20
30
40
50
60
70
80
1995 1997 1999 2001 2003 2005 2007 2009 2011 2013
Supply Alberta Demand*
* excludes solvent flood volumes
103m3/d
Actual Forecast
Figure 6.5. Propane supply from natural gas and demand
0
10
20
30
40
1995 1997 1999 2001 2003 2005 2007 2009 2011 2013
Supply Alberta Demand*
103m3/d
Actual Forecast
* excludes solvent flood volumes
Figure 6.6. Butane supply from natural gas and demand
0
5
10
15
20
25
1995 1997 1999 2001 2003 2005 2007 2009 2011 2013
Supply Alberta Demand*
103m3/d
Actual Forecast
* excludes solvent flood volumes
Figure 6.7 Pentane supply from natural gas and demand
0
10
20
30
40
1995 1997 1999 2001 2003 2005 2007 2009 2011 2013
Supply Alberta Demand*
103m3/d
Actual Forecast
* excludes solvent flood volumes
0
2
4
6
8
10
1996 1998 2000 2002 2004 2006 2008 2010 2012 2014
Mill
ion
s o
f t
on
ne
s Figure 7.1. Sources of sulphur production
Sour Gas
Refining and Upgrading
Actual Forecast
0
100
200
300
400
500
600
700
2003 2004
Th
ou
sa
nd
s o
f to
nn
es
Syncrude Suncor Shell
Figure 7.2. Sulphur production from oil sands
0
500
1000
1500
2000
2500
3000
3500
4000
Australia Brazil China NewZealand
SouthAfrica
Others
Th
ou
sa
nd
s o
f to
nn
es
2003 2004
Figure 7.3. Canadian sulphur offshore exports
0
2
4
6
8
10
1996 1998 2000 2002 2004 2006 2008 2010 2012 2014
Millio
ns
of
to
nn
es
Figure 7.4. Sulphur demand and supply in Alberta
Alberta Demand
Removed from Province
Stockpile
Actual Forecast
0
5
10
15
20
25
30
35
40
1995 1998 2001 2004 2007 2010 2013
Subbituminous Thermal Bituminous Metallurgical Bituminous
Figure 8.1. Alberta Marketable Coal ProductionM
illio
n to
nnes
