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0
2000
4000
6000
8000
10000
12000
14000
16000
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
Pe
tajo
ule
s
actual forecast
Hydro, wind, and other renewables
NGLs
Coalbed methane
Conventional natural gas
Mined and in situ bitumen
Conventional heavy oil
Conventional L&M oil
Coal
Figure 1. Total energy production in Alberta
Figure 2
Figure 3. same as 3.23
Figure 4 same as 5.27. Total gas production in Alberta
0.0
50.0
100.0
150.0
200.0
250.0
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
109m
3
Conventional marketable gas Coalbed methane
Process gas from upgrading bitumen Gas from bitumen wells
actual forecast
Figure 5. Alberta Conventional Crude Oil Production and Price
0
100
200
300
400
1938 1943 1948 1953 1958 1963 1968 1973 1978 1983 1988 1993 1998 2003
tho
ud
sa
nd
cu
bic
me
tre
s p
er
da
y
$0
$50
$100
$150
$200
$250
$300
$350
$400
$450
Cd
n$
/cu
bic
me
tre
Alberta Production Alberta Crude Oil Price
Source: Prices - CAPP Statistical Handbook
EUB Prorationing Plan (restricted production)
Major Oil Field Discoveries1947 – Leduc1948 – Redwater1949 – Golden Spike1952 – Bonnie Glen1953 – Pembina1957 – Swan Hill1959 – Judy Creek1959 – Swan Hill South1965 - Rainbow
Major Events Affecting Price1973 – Oil Embargo1979 – Iranian Revolution1980 – Iran / Iraq War1986 – OPEC Crumbles1990 – Gulf War1998 – Asian Econ. Crisis2001 – 9 / 112003 – Iraq War
1938 - Petroleum and Natural Gas ConservationBoard (EUB) created to enforce productionstandards
Export Pipelines1950 – Interprovincial Pipeline (Enbridge)1953 – Trans Mountain Pipe Line
0
50
100
150
1967 1970 1973 1976 1979 1982 1985 1988 1991 1994 1997 2000 2003 2006
tho
usa
nd
cu
bic
e m
etre
s p
er d
ay
Mined Bitumen SCO Production
$0
$100
$200
$300
$400
$500
SCO Price
Figure 6. Alberta mined bitumen and synthetic crude oil production and price
Cd
n$/
cub
ic m
etre
Great Canadian Oil Sands (Suncor) Startup Syncrude
Startup
Alberta Oil Sands Project Startup
0
20
40
60
80
100
1967 1970 1973 1976 1979 1982 1985 1988 1991 1994 1997 2000 2003 2006
tho
usa
nd
cu
bic
met
res
per
day
0
50
100
150
200
250
300
In Situ Production Bitumen Price
Cold Lake Pilot Production Cold Lake Phases 1-6 Cold Lake Phases 7-13
Shell Peace River Startup
First SAGD ProductionAEC (EnCana) Foster Ck.
Amoco (CNRL)Wolf Lake &Primrose Startup
Figure 7. Alberta in situ bitumen production and price
Cd
n$
/cu
bic
me
tre
s
Figure 8. Historical natural gas production and price
0
50
100
150
200
250
1962 1966 1970 1974 1978 1982 1986 1990 1994 1998 2002 2006
bill
ion
cu
bic
met
res
$0
$2
$4
$6
$8
$Cd
n/G
J
Gas production Alberta plant gate price
Gas prices as a by-product of oil production. Price less than replacement cost
Arbitration awardsprice increase
Regulated gas pricetied to oil prices.
Surplus built up
Price deregulation
Surplus gas drivesdown prices
PGT expansion
Late 1998: Northern Border/TCPL expansion 2000: Alliance Pipeline
Hurricanes Katerina and Ritahit U.S. Gulf Coast
Foothills Pipe Lines built for gas exports to California and the mid-western U.S.
1956: TransCanada Pipelinesbuilt to take Alberta gas to central Canada and the U.S. after debate over its charter in Parliament
0
5
10
15
20
25
1971 1976 1981 1986 1991 1996 2001 2006
Inven
tory
(m
illi
on
to
nn
es)
0
20
40
60
80
100
120
140
US
$/t
on
ne
Gas Processing Plants Oil Sands Plants FOB Vancouver (US$/tonne)
Figure 9. Sulphur closing inventories in Alberta and price
0
5
10
15
20
25
30
35
40
45
1882 1893 1904 1915 1926 1937 1948 1959 1970 1981 1992 2003
mill
ion
tonn
es
Subbituminous Bituminous Thermal Bituminous Metallurgical
1898
– E
xpan
sion
of r
ailw
ay n
etw
ork
(coa
l and
oil
fired
ste
am e
ngin
es)
and
grow
th o
f pop
ulat
ion
1952
– B
egin
ning
of c
hang
e to
die
sel-e
lect
ric tr
ains
1960
– S
team
rail
era
ends
Late
1960
’s –
Beg
inni
ng o
f exp
orts
to J
apan
for s
teel
indu
stry
1970
’s –
incr
ease
in c
oal-f
ired
elec
tric
gen
erat
ion
1950
’s –
Cru
de o
il an
d na
tura
l gas
repl
ace
coal
as
ener
gy s
ourc
e of
cho
ice
Coal remained “King Coal” until huge reservoirsof crude oil and natural gas were discovered
0
10
20
30
40
50
60
US
$ p
er t
on
ne
Australian-Japan contract price for thermal coal
Figure 10. Historical coal production and price
Australian-Japan contract price for thermal coal ( Australian Bureau of Agricultural and Resource Economics - ABARE)
Late
199
0’s
– m
ine
clos
ures
an
d re
duce
d co
al e
xpor
ts
due
to d
epre
ssed
coa
l pric
es
Figure 1.1 OPEC crude basket reference price 2006
50
55
60
65
70
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
$US
/bb
l
Figure 1.3 Price of WTI at Chicago
0
20
40
60
80
100
1988 1990 1992 1994 1996 1998 2000 2002 2004 2006 2008 2010 2012 2014 2016
$US
/bb
l
0
100
200
300
400
500
600
$US
/m3
actual forecast
High
Low
Figure 1.4 Average price of oil at Alberta wellhead
0
20
40
60
80
100
1988 1990 1992 1994 1996 1998 2000 2002 2004 2006 2008 2010 2012 2014 2016
$Cd
n/b
bl
0
100
200
300
400
500
600
$Cd
n/m
3
actual forecastHigh
Low
Figure 1.5 2006 Average monthly reference prices of Alberta crudes
0
20
40
60
80
100
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Cd
n$/
bb
l
Light-medium Heavy Bitumen
Figure 1.5 2006 average monthly reference prices in Alberta
Figure 1.7 Average price of natural gas at plant gate
0
2
4
6
8
10
12
1996 1998 2000 2002 2004 2006 2008 2010 2012 2014 2016
$C
dn
/gig
ajo
ule
actual forecasthigh
low
Figure 1.8 Alberta Wholesale Electricity Prices
0
25
50
75
100
125
150
2000 2002 2004 2006 2008 2010 2012 2014 2016
$C
dn
/MW
h
actual forecast
67.5
72.2
67.3 67.3
64.6
63.771.6
77.0
82.5 88.2
60
65
70
75
80
85
90
1997 1998 1999 2000 2001 2002 2003 2004 2005 2006
Ce
nts
Exchange rate
2.9
5.54.2 4.1
5.2
1.8
1.83.3 2.9 2.7
6.37.2
7.77.28.36.8
7.69.1
7.6 6.8
0
24
6
810
12
1997 1998 1999 2000 2001 2002 2003 2004 2005 2006P
erc
en
tag
e
Real GDP growth Unemployment rate
2.21.81.6 0.9
2.7 2.62.8
1.9
2.2 2.0
5.8
4.04.25.86.6 7.3
4.75.0 6.4 4.4
02468
1012
1997 1998 1999 2000 2001 2002 2003 2004 2005 2006
Pe
rce
nta
ge
Inflation rate Prime rate on loans
Figure 1.10 Canadian economic indicators
Figure 1.11 Alberta real investment
0
20
40
60
80
100
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
billio
ns o
f 1997$
Non-conventional oil extraction and upgradingConventional oil and gas extractionPipelines, natural gas distribution, storage, electricity generation and transmission linesPetrochemicalsGovernmentResidentialBusiness (non-residential/non-energy)
actual forecast
ATHABASCA
COLD LAKE
PEACE RIVER
4.3 26.6
47.6
120.9
Figure 2.7.Production of Bitumen in Alberta, 2006 103 m3/d
Mined Bitumen
In Situ
0%
20%
40%
60%
80%
100%
1997 1998 1999 2000 2001 2002 2003 2004 2005 2006
Pe
rce
nta
ge
Conventional crude oil & pentanes plus SCO & bitumen
Figure 2.8. Alberta crude oil and equivalent production
Figure 2.9. Alberta crude bitumen production
0
100
200
300
400
500
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
103 m
3 /d
Surface mining
In situ
actual forecast
0
2000
4000
6000
8000
10000
1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006
Nu
mb
er o
f pro
du
cin
g w
ells
0
20
40
60
80
Producing Wells Production
Figure 2.10. Total in situ bitumen production and producing bitumen wells
Pro
du
cti
on
(1
03 m
3 /d
)
Figure 2.11. Alberta synthetic crude oil production
Synthetic Crude Oil
0
100
200
300
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
103 m
3 /d
Synthetic crude oil
actual forecast
Figure 2.14. Alberta oil sands upgrading coke inventory
Synthetic Crude Oil
0
10
20
30
40
50
60
1975 1977 1979 1981 1983 1985 1987 1989 1991 1993 1995 1997 1999 2001 2003 2005
mill
ion
tonn
es
Oil Sands Plants – Coke Inventory
Figure 2.15. Alberta demand and disposition of crude bitumen and SCO
Synthetic Crude Oil
0
100
200
300
400
500
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
103 m
3 /d
Alberta demand (mainly SCO)
actual forecast
SCO removals from Alberta
Nonupgraded bitumen removals
from Alberta
Figure 3.1. Remaining established reserves of crude oil
0
100
200
300
400
500
600
700
800
1979 1981 1983 1985 1987 1989 1991 1993 1995 1997 1999 2001 2003 2005
10
6 m3
Heavy
Light-medium
Figure 3.2. Annual changes in conventional crude oil reserves
-30
-20
-10
0
10
20
30
40
50
1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006
10
6 m3
Additions Revisions
Figure 3.3. Annual changes to waterflood reserves
-10
-5
0
5
10
15
20
25
1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006
106 m
3
New waterflood Waterflood revisions
Figure 3.4. Distribution of oil reserves by size
Remaining reserves
(103m3)
Total number of pools
(103m3)
Initial reserves
(103m3)
0
50
100
150
200
250
300
350
1970 1975 1980 1985 1990 1995 2000 2005
Init
ial e
sta
blis
he
d r
es
erv
es
(1
06 m3 )
Average Median
Figure 3.5. Oil pool size by discovery year
Figure 3.7. Geological distribution of reserves of conventional crude oil
0
200
400
600
800
1000
1200
1400R
eser
ves
(10
6 m3 )
Initial established reserves Remaining established reserves
2006 Initial established reserves2730.8 106 m3
2006 Remaining established reserves250.1 106 m3
Fig. 3.8. Regional distribution of Alberta oil reserves (106 m3)
263
21
488
52
1196
78
424
43
182
11
157
40
6
20
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
1600
1800
2000
2200
2400
2600
2800
3000
3200
1970 1980 1990 2000 2010 2020 2030 2040
10
6 m3
Ultimate potential (3130)
actual forecast
Actual as of December 31, 2006
Figure 3.11.Alberta successful oil well drilling Bymodified PSAC area
2005 Wells Drilled = 2172
2006 Wells Drilled = 2146
33
483522
7
26
458 506
443
3
619
269 257
400292
Total wells = 1956
Figure 3.12.Oil wells placedon production, 2006by modified PSAC area 254
6
553 392
508
222
21
Figure 3.13. Initial operating dayrates of oil wells placed on production, 2006by modified PSAC aream3/day/well[bbl/day/well]
17.2[109]
12.3[77]
6.3[39]
11.5[72]
8.7[55]
5.0[32]
7.6[48]
Figure 3.14. Conventional crude oil production by modified PSAC area
0
20
40
60
80
100
120
140
160
1997 1998 1999 2000 2001 2002 2003 2004 2005 2006
10
3 m3 /d
ay
PSAC 8
PSAC 7
PSAC 5
PSAC 3
PSAC 4
PSAC 2
PSAC 1
0
10000
20000
30000
40000
50000
1973 1977 1981 1985 1989 1993 1997 2001 2005
Nu
mb
er 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
of
we
lls
0
40
80
120
160
200
m3 /d
Producing wells Average rate
Figure 3.16. Crude oil well productivity in 2006
Figure 3.17. Total conventional crude oil production by drilled year
% of totalproduction from oil wells
0
20
40
60
80
100
120
140
160
1997 1998 1999 2000 2001 2002 2003 2004 2005 2006
Pro
du
cti
on
(1
03 m
3 /d)
Pre-19972006
20052004
20032001
20022000
19991998
1997
11%
45%
7%
5%
3%5%
4%
2%
4%
6%
7%
0
500
1000
1500
2000
2500
3000
3500
4000
1950 1955 1960 1965 1970 1975 1980 1985 1990 1995 2000 2005
tho
us
an
d b
arr
els
pe
r d
ay
Figure 3.18. Comparison of crude oil production
Texas onshore
Louisiana onshore
Alberta crude oil
Figure 3.19. WTI crude oil price and well activity
0
1000
2000
3000
4000
5000
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
Nu
mb
er
of
we
lls
$0
$20
$40
$60
$80
$100
US
$/b
bl
Wells placed on production WTI @ Chicago
actual forecast
0
30
60
90
120
150
180
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
Pro
duct
ion
(10
3 m3 /d
)
actual forecast
Figure 3.20. Alberta daily production of crude oil
Heavy
Light-medium
Figure 3.21. Capacity and location of Alberta refineries
0
5000
10000
15000
20000
25000
30000
35000
Imperial Edmonton
Petro-Canada Edmonton
Shell Scotford
Husky Lloydminster
Parkland Bowden
Ref
iner
y ca
pac
ities
(m3 /d
)
0
30
60
90
120
150
180
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
103 m
3 /d
actual forecast
Figure 3.22. Alberta demand and disposition of crude oil
Crude oil removals from Alberta
Alberta demand
Figure 3.23. Alberta supply of crude oil and equivalent
0
100
200
300
400
500
600
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
103 m
3 /d
actual forecast
Non upgraded bitumen
Light-medium
SCO
Pentanes plusHeavy
Figure 3.24. Alberta crude oil and equivalent production
0%
20%
40%
60%
80%
100%
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
Pe
rce
nta
ge
Conventional crude oil & pentanes plus SCO & bitumen
actual forecast
0
2
4
6
8
10
12
14
16
18
2005 2007 2009 2011 2013 2015
10
9 m3
Figure 4.4 Coalbed methane production forecast from CBM wells
actual forecast
0
20
40
60
80
100
120
140
160
180
1974 1979 1984 1989 1994 1999 2004
10
9 m
3
Additions Production
Figure 5.1. Annual reserves additions and production of conventional marketable gas
0
400
800
1200
1600
2000
1975 1980 1985 1990 1995 2000 2005
109
m3
Figure 5.2. Remaining conventional marketable gas reserves
-20
0
20
40
60
80
100
120
140
1999 2000 2001 2002 2003 2004 2005 2006
109
m3
New Development Revisions
Figure 5.3. New, development, and revisions to conventional marketable gas reserves
Figure 5.5. Distribution of conventional gas reserves by size
Remaining reserves
(109m3)
Total number of pools
(106m3)
Initial reserves
(109m3)
0
50
100
150
200
250
300
350
1965 196819711974 1977198019831986 198919921995 199820012004
Es
tab
lish
ed
re
se
rve
s (
10
6 m3 )
Average Median
Figure 5.6. Conventional gas pools by size and discovery year
0
400
800
1200
1600
200010
9 m3
Initial marketable reserves Remaining marketable reserves
Figure 5.7. Geological distribution of conventional marketable gas reserves
0
400
800
1200
1600
2000
1984 1986 1988 1990 1992 1994 1996 1998 2000 2002 2004 2006
109 m
3
Figure 5.8. Remaining conventional marketable reserves of sweet and sour gas
Sweet natural gas
Sour natural gas
25
50
60
9040
35
30
10
100
35
15
10
0%
20%
40%
60%
80%
100%
Methane Ethane Propane Butanes Pentanes plus
Per
cent
age
of c
ompo
nent
Removed at field plants Removed at straddle plants Marketable gas
Figure 5.9. Expected recovery of conventional natural gas components
0
1000
2000
3000
4000
5000
6000
7000
1973 1976 1979 1982 1985 1988 1991 1994 1997 2000 2003 2006
109 m
3
Ultimate potential based on 2004 study
Figure 5.11. Conventional gas ultimate potential
Remaining reserves
Production
0
500
1000
1500
2000
2500
3000
3500
4000
4500
UpperCretaceous
LowerCretaceous
Jurassic Triassic Mississippian Devonian
Gas
in p
lace
(10
9 m3 )
Ultimate potential Discovered gas in place
Figure 5.13. Conventional gas in place by geological period
0
2000
4000
6000
8000
10000
12000
14000
1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006
Num
ber o
f wel
ls
Drilled Connected
Figure 5.15. Successful conventional gas wells drilled and connected
Figure 5.18. Marketable gas production by modified PSAC area
0.0
20.0
40.0
60.0
80.0
100.0
120.0
140.0
160.0
180.0
200.0
1997 1998 1999 2000 2001 2002 2003 2004 2005 2006
10
9 m3
PSAC 6
PSAC 4
PSAC 5
PSAC 2
PSAC 3
PSAC 1
Gas from oil wells
PSAC 7
PSAC 8
% of totalproduction
Connection year
2%
4%3%
12%
4%
20%
39%
6%
10%
0
20000
40000
60000
80000
100000
120000
1990 1992 1994 1996 1998 2000 2002 2004 2006
Nu
mb
er o
f pro
du
cin
g w
ells
0
50
100
150
200
250
Pro
du
ctio
n (1
09 m
3 )
Producing wells Production
Figure 5.19. Conventional marketable gas production and number of producing wells
0
10000
20000
30000
40000
50000
60000
70000
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 pro
du
cin
g w
ells
0
100
200
300
400
Pro
du
ctio
n (1
03 m
3 /d)
Producing wells Average rate
Figure 5.20. Natural gas well productivity in 2006
0
20
40
60
80
100
120
140
160
180
200
1997 1998 1999 2000 2001 2002 2003 2004 2005 2006
Pro
du
cti
on
(1
09 m
3 )
Pre - 1997
20062005
20042003
20012002
20001999
1998
1997
Gas from oil wells
Figure 5.21 Raw gas production by connection year
% of totalproduction from gas wells
3
Connection year
3
4
24
9
6
12
12
16
5
6
0
2
4
6
8
10
12
1956 1961 1966 1971 1976 1981 1986 1991 1996 2001 2006
Tc
f
Figure 5.22. Comparison of raw natural gas production
Texas onshore
Louisiana onshore
Alberta
0.0
5.0
10.0
15.0
20.0
25.0
1997 1998 1999 2000 2001 2002 2003 2004 2005
Pro
du
cti
vit
y (
103
m3 /d
)
AlbertaAlberta excluding PSAC Area 3PSAC Area 3 (Southeastern Alberta)
Figure 5.23 Average initial natural gas well productivity in Alberta
Figure 5.24. Alberta natural gas well activity and price
0
4000
8000
12000
16000
20000
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
Nu
mb
er o
f wel
ls
$0
$2
$4
$6
$8
$10
$Cd
n/G
J
New well connections Alberta plant gate price
actual forecast
Figure 5.25. Conventional marketable gas production
0
50
100
150
200
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
109 m
3
actual forecast
7.1
5.3
3.6
1.8
0
Tc
f
Figure 5.26. Gas production from bitumen upgrading and bitumen wells used for oil sands operations
0
2000
4000
6000
8000
10000
12000
14000
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
106 m
3
Process gas from upgrading bitumen Gas from bitumen wells
actual forecast
Figure 5.27. Total gas production in Alberta
0.0
50.0
100.0
150.0
200.0
250.0
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
109 m
3
Conventional marketable gas Coalbed methane
Process gas from upgrading bitumen Gas from bitumen wells
actual forecast
-1500
-1000
-500
0
500
1000
1500
2000
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
106 m
3
2004 2005 2006
Figure 5.28. Alberta natural gas storage injection/withdrawal volumes
0.00
10.00
20.00
30.00
40.00
50.00
60.00
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
10
9 m3
Figure 5.31. Alberta marketable gas demand by sector
Reprocessing plant shrinkage
Transportation
Electricity generation
Other industrial
Industrial - petrochemical
Industrial – oil sands
Residential
Commercial
actual forecast
0
100
200
300
400
1997 1998 1999 2000 2001 2002 2003 2004 2005 2006
109
m3
Figure 5.32. Historical volumes “available for permitting”
0
5
10
15
20
25
30
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
10
9 m3
actual forecast
Mining and Upgrading
In Situ
In Situ Cogeneration
Mining and Upgrading Cogeneration
Figure 5.33. Purchased natural gas demand for oil sands operations
Figure 5.34. Gas demand for bitumen recovery and upgrading
0
5
10
15
20
25
30
35
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
10
9 m3
actual forecast
Purchased gas
Produced gas from bitumen
Process gas from upgrading*
* Some 1.0 109m3 of process gas not shown on this chart is used for electricity generation (2007-2016).
0
5
10
15
20
25
30
35
40
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
10
9 m3
actual forecast
Process Gas for Mining/Upgrading
Produced Gas from Bitumen Wells for In situ Recovery
Purchased Gas for In situ Recovery
Purchased Gas forElectricity Cogeneration
Purchased Gas for Mining/Upgrading
Process Gas for Electricity Cogeneration
Figure 5.35. Total Purchased, Process and Produced Gas for Oil
Sands Production
0.0
50.0
100.0
150.0
200.0
250.0
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
109 m
3
Residential demand Commercial demand Other Alberta demand Alberta gas removals
actual forecast
10.7
7.1
5.3
3.6
1.8
0
Tc
f
Figure 5.36. Total marketable gas production and demand
25% 24% 28% 36% 44%
Figure 6.1. Remaining established NGL reserves expected to be extracted from conventional gas and 2006 annual production
0
30
60
90
120
150
Ethane Propane Butanes Pentanes Plus
Liq
uid
vo
lum
e (
10
6 m3 )
Reserves Annual production
Figure 6.2. Remaining established reserves of conventional natural gas liquids
0
50
100
150
200
250
1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006
Es
tab
lish
ed
re
se
rve
s (
10
6 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
20
40
60
80
100
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
Total Demand Alberta Demand* Potential Supply from Conventional Gas
* excludes solvent flood volumes
103m3/d
Actual Forecast
Figure 6.5. Propane supply from natural gas and demand
0
10
20
30
40
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
Supply Alberta Demand*
103m3/d
Actual Forecast
* excludes solvent flood volumes
Figure 6.6. Butanes supply from natural gas and demand
0
5
10
15
20
25
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
Supply Alberta Demand*
103m3/d
Actual Forecast
* excludes solvent flood volumes
Figure 6.7. Pentanes supply from natural gas and demand for diluent
0
10
20
30
40
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
Supply Alberta Demand*
103m3/d
Actual Forecast
* excludes solvent flood volumes
demand met by alternative sources and types of diluent
0
2
4
6
8
10
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
106 t
actual forecast
Figure 7.1. Sources of sulphur production
Sour gas
Refining and upgrading
0
2
4
6
8
1966 1971 1976 1981 1986 1991 1996 2001 2006
Pro
du
cti
on
(m
illi
on
to
nn
es)
Figure 7.2. Sulphur production from gas processing plants in Alberta
0
200
400
600
800
1000
2003 2004 2005 2006
10
3 t
Syncrude Suncor Shell
Figure 7.3. Sulphur production from oil sands
0
1000
2000
3000
4000
5000
Australia Brazil China NewZealand
SouthAfrica
Others
10
3 t
2003 2004 2005 2006
Figure 7.4. Canadian sulphur offshore exports
0
1
2
3
4
5
6
7
8
9
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
mil
lio
ns o
f to
nn
es
Figure 7.5. Sulphur demand and supply in Alberta
Alberta demand
Removed from Alberta
Stockpileactual forecast
StockpileWithdrawal
Total Demand
Production
0
10,000,000
20,000,000
30,000,000
40,000,000
50,000,000
1874 1885 1896 1907 1918 1929 1940 1951 1962 1973 1984 1995 2006
tonn
es
Figure 8.1 Total coal production
Subbituminous
Bituminous thermal
Bituminous metallurgical
0
5
10
15
20
25
30
35
40
45
50
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
mill
ion
tonn
es
actual forecast
Figure 8.3 Alberta marketable coal production
Subbituminous
Thermal bituminous
Metallurgical bituminous
0
5
10
15
20
1998 2000 2002 2004 2006 2008 2010 2012 2014 2016
Th
ou
san
d M
W
Coal Natural Gas Hydro Other
actual forecast
Figure 9.1. Alberta electricity generating capacity
0
25
50
75
100
1998 2000 2002 2004 2006 2008 2010 2012 2014 2016
Th
ou
san
d G
Wh
Coal Natural Gas Hydro Other
actual forecast
Figure 9.2. Alberta electricity generation
Figure 9.3. Alberta electricity transfers
0
500
1000
1500
2000
2500
3000
1997 1998 1999 2000 2001 2002 2003 2004 2005 2006
GW
h
Deliveries Receipts
Figure 9.4. Alberta electricity consumption by sector
0
25
50
75
100
1998 2000 2002 2004 2006 2008 2010 2012 2014 2016
Th
ou
san
d G
Wh
Industrial Industrial on site
Commercial Residential (including agriculture)
actual forecast
9.5. Alberta oil sands electricity generation and demand* Industrial – oil sands historical data on electricity demand was estimated using an assumption of 10 kWh/bbl for in situ oil sands projects that do not operate cogeneration units.
0
5
10
15
20
25
30
1998 2000 2002 2004 2006 2008 2010 2012 2014 2016
Th
ou
sa
nd
GW
h
actual forecast
Potential generation
Demand
