Download - 2020 Long-term Transmission Plan - AESO
2020 Long-term Transmission Plan Stakeholder Information Session
February 5, 2020
Public
Dennis Frehlich, P. Eng.
Vice-President, Grid Reliability
Agenda
1
• Welcome & housekeeping
• AESO 2020 Long-term Transmission Plan
(2020 LTP) Highlights
• Transmission Planning Process
• AESO 2019 Long-term Outlook (2019 LTO)
– Input to the 2020 LTP
• 2020 LTP
– Near-term developments (within 5 years)
• Distributed Energy Resources (DER) and
Energy Storage
• 2020 LTP
– Longer-term developments (5 -20 years)
• Generation Integration Capabilities
• Questions & Answers Public
2020 LTP Highlights
2
• Defines a flexible future plan:
– Meets near-term needs while being flexible by adopting
scenario-based planning utilizing the 2019 LTO
– Considers staged transmission developments, using
milestones
• Identifies 20 near-term transmission developments:
– All require further regulatory approval
– Total $1.4 billion
– Potentially increase average transmission rates by about
$0.50—$0.70 per megawatt hour, starting in 2025
• Incorporates expanded generation integration capability
assessments to include all regions of the province,
providing guidance to assist developers
• Includes the consideration of emerging technologies
and the potential future impacts to the grid Public
Transmission Planning Process
2020 LTP Stakeholder Consultation
AESO Stakeholder Engagement
Framework
Ata Rehman, P. Eng.
Director, Grid Planning & Ops Eng.
Planning Process
5
Need Drivers
Need Assessment
Develop and Screen
Alternatives
Recommended Alternative
• Reliability
Ensure:
• Energy Only Market
Support:
• Future generation development
Enable:
• Future load Growth
Serve:
• Legislated requirements
Meet:
System
Studies
• Capacity requirement
• Congestion forecasts
• Need dates
Result in high level:
• Technology
• Termination
points
• Capacity
Specify:
• Relative costs and
losses impact
• High-level land /
environmental impact
• Long-term nature of
asset
• Asymmetric risk of
building too late vs.
too early
• Stakeholder input
• Staging / milestones
• Construction /
integration schedules
Considerations:
1
2
3
n
• Technical
• Economic
• Environmental
Relative:
Projects identified in the 2020 LTP require regulatory approval
• Approach:
– Consultation meetings
– Engagement through Public Involvement Programs (PIP) for transmission
development projects
• Timing
– Q1-Q2 2019: review LTP planning process & obtain input for consideration
– Q3-Q4 2019: update on transmission development plans
Stakeholder Consultation
6 Public
• Objectives:
– Ensure LTP accurately captures transmission
needs for Alberta
• Stakeholders:
– Transmission facility owners, distribution facility
owners, industry associations, regional
municipalities (council and/or administration)
AESO 2019 Long-term Outlook (LTO)
2020 LTP Near-term developments
Peter Huang, P. Eng.
Senior Engineer, System Planning
2019 LTO Scenarios
10 * Not studied by the 2020 LTP
Public
Load Scenarios
Generation
Scenarios /
Sensitivity
High-Level Description
Reference Case • AESO’s main corporate forecast
Reference Case Alternate
Renewables Policy • Tests higher renewable target or policy
High Cogeneration
Sensitivity
• Tests increased cogeneration adoption
at existing and future oil sands sites
Low Growth Low Growth • Tests lower economic and generation
growth due to limited oil sands growth
High Growth High Growth • Tests higher economic and generation
growth due to strong oil sands growth
Diversification* Diversification*
• Tests greater penetration of new
technologies in an economy not driven
by oil sands
Northwest Region
14
• Staged developments to enable
long-term growth
• Fox Creek 240 kV developments
to support transfer into the NW
– Load: thermal
• Grande Prairie area
developments to support growth
in the area – Load: thermal
• Grande Cache area
developments for voltage support – Load: voltage
• Additional 240/144 kV
transformation at Little Smoky – Load: thermal
Northwest Region (cont.)
15
• Voltage support at Kinuso or new
transformer at High Prairie area
– Load: voltage
• Increase line rating in the Rainbow
Lake area
– Load: thermal
21 - High Prairie
26 - Swan Hills
19 - PeaceRiver
25 - FortMcMurray
9L56
(to
Brin
tnel
l87
6S)
9L913 (to North
Barrhead 69S)
9L40 (
to L
ouis
e
Cre
ek 8
09S
)
7L237L30
7L31
6L73
6L96 (to Sarah
Lake 743S)
6L99
6L57
6L
97
(to
Ed
ith
La
ke
73
9S
)
7L61 (to
Lubicon
780S)
7L497L162
NIPISI796S
KINUSO727S
MITSUE732S
WABASCA720S
OTAUWAU729S
SWANRIVER735S
SLAVE LAKE745S
A.E.C. MILL844S
NARROWSCREEK 858S
SlaveLake
(SLP1)
HouseMountain(HSM1)
NW RegionSolutions
This diagram contains a simplified versionof the system configuration. Technical
detail has been simplified for illustrationpurposes. It does not indicate
geographical locations of facilities.
Gas Generator
Other Generator
69 or 72 kV Substation
138 or 144 kV Substation
240 kV Substation
69/72 kV
138/144 kV
138/144 kV Double Circuit
240 kV
TransmissionReinforcements
AESO Planning Areas
Currency Date: 2019-11-27
1L
35
7
Rainbow#5 (RB5)
FortNelson(FNG1)
Rainbow Lake#1 (RL1)
Wescup
ZAMA795S
MEIKLE905S
BASSETT747S
HAMBURG855S
PetroCanKLC
ARCENIEL930S
KEG RIVER789S
HOTCHKISS788S
RING CREEK853S
KEMPRIVER797S
FORTNELSON
FNG
HAIG RIVER748S
RAINBOWLAKE 791S
SULPHURPOINT828S
RAINBOWCOGEN 850S
HarvestEnergy FNC
CHINCHAGARIVER 779S
7L64
7L133 (to HighLevel 786S)
7L63 (toLubicon780S)
7L59 (to High
Level 786S)
7L
58
7L
81
7L113
7L120
7L138
7L93
7L72
7L
29
76
2L
7L1227L109
7L
10
6/7
L1
31
(to W
esle
yC
reek 8
34S
)
7L
51
(to
Westp
ea
ce
A7
93
S)
1L359
7L82
17 - Rainbow Lake
19 - PeaceRiver
BritishColumbia
Gas Generator
138 or 144 kV Substation
138/144 kV
138/144 kV Double Circuit
TransmissionReinforcements
AESO Planning Areas
NW RegionSolutions
This diagram contains a simplified version of the system configuration. Technical detail has been simplified for illustration purposes.It does not indicate geographical locations of facilities.
Currency Date: 2019-11-27
Public
Edmonton Region
17 Public
• Additional 500/240 kV transformation for the
Keephills/Ellerslie/Genesee (KEG) Loop
– Generation: thermal
• Increase line rating for 138 kV lines north of
Edmonton
– Load: thermal
• Increase line rating for 138 kV line and new
voltage support device near Leduc
– Load: thermal and voltage
• Additional transmission reinforcement for the
Fort Saskatchewan area 138 kV system
– Load: thermal
• Reinforcements for the City of Edmonton
system
– Load: thermal
Edmonton Region (cont.)
18
729L
1045L909L
1203L
919L/989L
(to Sagitawah 77S)
973L/974L(to Bickerdike 89S)
1083
L/9
14L
(to
Red
Deer
63
S)
1055L
10
45
L
913L
1045L
1046
L
190L
/903
L (
to
Ben
alto 1
7S
)
809L
767L
790L
10
44
L
1044L909L
SPRUCEGROVE
595S677L
10
44
L
90
8L
902L
10
56
L
921L
76
1L
33 - Fort Saskatchewan
700L
FORTSASK. 54S
76
7C
L
QUEENSLAND301S
1325
L W
AT
L (
to
Lang
don
102
S)
910L
914L
91
0L
91
0L
91
4L
WOLFCREEK288S
91
4L
421L422L
10
83
L
10
55
L
452L
1043L
27 - Athabasca /Lac La Biche
26 - SwanHills
30 - DraytonValley
430L
732A
L
446L
453L
HARRYSMITH367S 1
139
LSAUNDERSLAKE 289S
454L455L
1112L
1140
L 780L174L
174L
12L44 (to
Liv
ock
939S
)
1045A
L
Riverview
STRATHCONA
DOME
DEVON14S
BARDO197S
NISKU149S
MARION21S
LEDUC325S
BILBY105S
JASPER805S
CARVEL432S
BUFORD538S
ERVICK542S
PONOKA331S
WABAMUN19S
ONOWAY352S
BRETONA45S
BIGSTONE86S
KINGMAN299S
VISCOUNT92S
GENESEE330p
ACHESON
305S
BLACKMUD155S
CHERHILL338S
ELLERSLIE89S
SUNDANCE821S
WABAMUN2739S
SUNDANCE310P
WETASKIWIN40S
ENTWISTLE235S
BROADMOOR420S
KEEPHILLS320P
SUNNYBROOK510S
CLOVERBAR 987S
BELLAMY
PIGEONLAKE 964S
NORTHCALDER 37S
NELSON LAKE429S
PETROLIA
EASTCAMROSE
285S
COOKINGLAKE 522S
VICTORIA
N.W. CARDIFF191S
SHERWOODPARK 746S
NORTHBARRHEAD 69S
NORTH ST.ALBERT 99S
FIBERGLASS
NEW ROSEVALLEY 635S
KEEPHILLS/SUNDANCEMAKE-UP866S & 868S
TRUWELD GRATING6500S
FORT ASSINIBOINE234S
STONYPLAIN434S
POUNDMAKER
SOUTHMAYERTHORPE
443S
T.M.P.L.GAINFORD 165S
337S
SUNDANCEBLOW-DOWN
867S
CASTLEDOWNS
ARGYLL
INLANDCEMENT
Genesee #1-3(GN1-GN3)
Keephills 1-3(KH1-KH3)
Cloverbar1-3 (ENC1)
Sundance #3-6(SD3-SD6)
905L
913L (
to
Mitsue
732
S)
156L
1202L
729L
174L (to NorthHolden 395S)
7L230 (to SarahLake 743S)
723L (toWestlock 438S)
739L
1209L
726L (toLamoureux 71S)
919L989L
973L974L
805L
672L (
to M
oon
Lake 1
31S
)
910L
914L
799L (to
Sagitawah 77S)
761L (to
Lamoureux 71S)
744L (to Paddle
River 106S)
883L
896L
1206
L/12
12L
(to
Hea
rtla
nd 1
2S)
858L
897L
730L
133L
767LWESTWOOD
422S
834L (
to K
eysto
ne 3
84S
)
522L
780L
920L/921L (to
Lamoureux 71S)
922L/9
26L
(to B
enalto 1
7S
)
712L
837L
874L
908L909L
1046
L
930L
91
5L
94
7L
838L632L
804L
858L
124L
792L
711L
888A
L
746BL
1098L
79
0A
L
15
6B
L
52
2L
739L
729L (
to
Cly
de 1
50S
)
838L
1202L1203L
739L838L
898L747L
746A
L
1238L1239L
240
BA
2
240
BA
3
729A
L
240
CV
5
636L
521AL
803L804L
522AL
767AL
604L
632L
834L
522L
747L
123L
909L
234L
732L
512L
920L
40 - Wabamun
31 - Wetaskiwin
60 - Edmonton
731L746L
707L (to Dow ChemicalFort Saskatchewan 166S)
70
9L (
to S
he
rritt
Go
rdo
n 7
21
S)
694L
706L (to Josephburg 410S)
174L
CRG1CamroseGenerator
Edmonton Region - SolutionsThis diagram contains a simplified versionof the system configuration. Technicaldetail has been simplified for illustrationpurposes. It does not indicate geographicallocations of facilities. For clarity theCity of Edmonton and East Edmontonare shown as insets.
Coal Generator
Gas Generator
Future 240 kV Substation
69 or 72 kV Substation
138 or 144 kV Substation
240 kV Substation
500 kV Substation
HVDC Line
Future 69/72 kV
Future 240 kV
Normally Open Line
69/72 kV
69/72 kV Double Circuit
69/138 kV Double Circuit
138/144 kV
138/144 kV Double Circuit
240 kV
240 kV Double Circuit
500 kV
500 kV Double Circuit
TransmissionReinforcements
AESO Planning Areas
Currency Date: 2019-11-27
City of Edmonton Inset(U/G = Underground Line)
915L
947L
1059L
1059AL
947L
1057L908L
1059
L
908L
731L
865L
YASA286S
BRETONA45S
BERNESE293S
ELLERSLIE89S
BASELINE317S
BRETVILLE185S
LAMBTON
CLOVERBAR 987S
SUMMERSIDE657S
EASTEDMONTON
38S
KNIGHTSBRIDGE216S
STELCOEDMONTON
133S
IMPERIAL OILEDMONTON 95S
PETRO-CANADAEDMONTON 184S
ATPLASTIC
5RS
ATPLASTIC
4RS
EASTINDUSTRIAL
1206
L/1
212L
(to
Hea
rtla
nd 1
2S
)
737L
738L
946L
908L
215L
605L
72LH8 (toHardisty)
731L (toBroadmoor
420S)
736L
780L
897L
874L (to CookingLake 522S)
947L
72LS24 (toStrathcona)
897L
705L
78
0L (
to
Co
okin
gL
ake
52
2S
)
738A
L
761L (
toLam
oure
ux
71S
)
741L
606L
1058
L
921L
1057L
91
5L
94
6L
908AL
822L
822AL
East EdmontonInset
72CK12 (U/G)
921L (toLamoureux 71S)
240B
A2
(U/G
)
240B
A3
(U/G
)
72RG1 (U/G
)72
RV
6 (
U/G
)
72
RV
2 (
U/G
)
(Normally Open Pointwithin Substation)
(Normally Open Pointwithin Substation)
1058
L (
toS
um
mers
ide
657S
)
1059L (to EastEdmonton 38S)
CASTLEDOWNS
920L (toLamoureux 71S)
920L (to NorthCalder 37S)
915L (to East
Edmonton 38S)
1044
L
(to
Pe
tro
lia)
1056
L (
to
Elle
rslie
89
S)
947L (to
Ellerslie 89S)
Blatchford
Fu
ture
69 k
V
(to
Dom
e)
Cloverbar #1-3(ENC1-ENC3)
University ofAlberta #1 & 2
(UOA1-2)
JASPER805S
NAMAO
VICTORIA511S
LAMBTON
CLOVERBAR 987S
GARNEAU
BELLAMY
HARDISTY
ROSSDALE
KENNEDALE
WOODCROFT
STRATHCONA
MEADOWLARK ARGYLL
72CN10 (U/G)
72R
W3
(U
/G)
72CH9 (U/G)
240C
V5
(U/G
)
72CH11 (U/G)
1045
L (
to
Sun
dance 3
10P
)
72LS24
72MG16 (U/G)
72JM18 (U
/G)
72NK23 (U/G)
72NW15 72CK13 (U/G)
72JW19 (U/G)
1055
L
(to
Pe
tro
lia)
72LH
8
72V
N21 (
U/G
)
72
RV
4(U
/G)
1098L (toPoundmaker)
72RG7 (U/G
)
Public
Central Region
20
• Central East Transfer-out (CETO)
– To strengthen transfer-out capability for integrating new generation
– Generation: thermal
Public
Central Region (cont.)
21
• Voltage support devices at
Strome, Foster Creek,
and St. Paul substations
– Load: voltage
– To mitigate load driven
N-1 violations
Public
South Region: AIR & CRPC
22
• Alberta–British
Columbia intertie
restoration (AIR)
– Intertie
• Chapel Rock–to–
Pincher Creek (CRPC)
area transmission
reinforcement
– To provide additional
transfer out capability
for integrating new
generation in SW
region
– Generation: thermal
South Region (cont.)
23
• Increase line rating and provide additional voltage support in the
Lethbridge area
– Load: thermal and voltage
• Expand the existing
138 kV Tilley
substation to 240 kV,
tapping onto nearby
240 kV line
– Load: thermal and
voltage
• New voltage support
device at Warner
substation
– Load: voltage
Public
Calgary Region
24
• Downtown Calgary short-
circuit mitigation
– Load: short circuit
• New 138 kV transmission
line between Janet and
Chestermere substations
– Load: thermal and
voltage
44 -Seebe
752L
2.8
3L
2.83L
771L
54.81L
918L
1.8
0L
693L916L
10
37
L1
03
8L
(to
SC
1
26
6S
)
611L
611L
26.81L
10
64
L10
65
L
646L
434L
727L
90
6L
92
8L
631L
Bow RiverHydro
(BOW1)
925L (
to R
ed D
eer
63
S)
41.84L
CHESTERMERE419S
691L
STRATHMORE151S
733L
NAMAKA428S
HUSSAR431S
733L (toGleichen
179S
886L
6 - Calgary
57 - Airdrie
46 - HighRiver
39 - Didsbury
45 - Strathmore/ Blackie
42 -Hanna
752L
90
6L
/928
L
(to
Be
na
lto 1
7S
)
850L (toCarseland 525S)
91
8L (
to
Jo
hn
son
281S
)
12
01
L (
toB
C Inte
rtie
)
753L (toBlackie 253S)
7.8
4L
90
1L (
to R
ed
Dee
r 63
S)
50L
812L
925L
901L
932L
929L
2.8
3L
3L (to Seebe 245S)2.
81L
765L
932L
38
.83L
24
.83L
11.82L
14.83L
929L (
to
Haze
lwo
od 2
87S
)
35
.81L
158L
9.83L
13L
24
.82L
7.8
2L
162.81L
150L (toGhost 20S)
6.8
0L
24.81L
16.63L
39.82L
110
6L
110
7L
31.84L
832L916L
2.8
2L
(U/G
)
36.8
1L
11.83L918L
924L/927L(to Milo 356S)
33
.83L
32
.83L
10
80
L110
9L
9.80L
26.83L
860L (toCochrane
291S)
3.8
4L
727AL
936L937L
37
.81L
22.81L
37
.82L
6.8
2L
13.60L 13.82L
15.6
0L
21.6
1L
40.81L
688L
16.61L
21
.80L
1.8
1L
1.84L(U/G)
752AL
833L
33
.84L
PCES02L
833L
916L
11.8
1L
98
5L
10
03
L
23.80L2.80L
150L3L
1114L
1.80L
901AL
16.60L21.61L
688AL
3.82L(U/G)
1.8
3L (
U/G
)
1.8
0L
(U/G
)
1.8
1L
(U/G
)
1.8
5L (
U/G
)
15.6
2L
16.6
0L
15.6
2L
21.6
1L
631L
812A
L
24.82L26.83L
20
.82L
28.80L
1.82L(U/G)
13
25
L W
AT
L (
toS
unn
ybro
ok 5
10
S)
JANET74S
SS-6
SARCEE42S
SS-54
SS-47
MAGCAN142S
SS-26SS-65
OKOTOKS678S
LANGDON102S
BENNETT510S
SHEPARDSS-25
CROSSINGS511S
HIGHRIVER
65S
DRYCREEK186S
EASTCALGARY
5S
NOSECREEK284S
SS-9
SS-2
BEDDINGTONSS-162
SS-3
SS-8
EAST AIRDRIE199S
SS-7
BEARSPAWPLANT 44S
BLACKDIAMOND
392S
SS-40
SS-22
SS-21
SS-13
EASTCROSSFIELD
64S
SS-11
SS-43
SS-33
SS-14
SS-23
SS-39
SS-37
SS-15
SS-32
SS-36
SS-24
SS-20
SS-38
SS-31
SS-41
SS-35
WESTCROSSFIELD
316S
CALGARY ENERGYCENTER CEC
BALZACCO-GEN
SS-28 SS-10
SS-16
SS-34
SS-12
SS-27
SS-1
TURBOBALZAC 391S
SS-5
HARTELL512S
SUMMIT653S
FOOTHILLS237S
Crossfield EnergyCentre #1-3 (CRS1-3)
ENMAX CEC (CAL1)
U of C DGGenerator(UOC1)
Nexen Inc#1-2 (NX01-2)
Shepard(EGC1)
This diagram contains a simplifiedversion of the system configuration.Technical detail has been simplifiedfor illustration purposes. It does notindicate geographical locations of facilities.(Underground lines are marked U/G)
Gas Generator
Hydro Generator
69 or 72 kV Substation
138 or 144 kV Substation
240 kV Substation
500 kV Substation
HVDC Line
Future 138/144 kV
69/72 kV
69/72 kV Double Circuit
138/144 kV
138/144 kV Double Circuit
138/240 kV Double Circuit
240 kV
240 kV Double Circuit
500 kV
TransmissionReinforcements
AESO Planning Areas
Currency Date: 2019-11-27
Calgary RegionSolutions
Public
Distributed Energy Resources &
Energy Storage
2020 LTP Longer-term developments
Generation integration capabilities
Amir Motamedi, P. Eng., Ph.D.
Manager, System Planning
• To further understand the impact
of DER integration on available
transmission system capability,
the AESO studied the following
conditions:
– Focused on the three major urban
centres (Edmonton, Red Deer &
Calgary) and renewable rich areas
within Alberta
DER Assessment: Approach
27 Public
• Up to 25 per cent of homes are assumed to have rooftop solar PV in these
urban centres
• City of Calgary: approx. 300 MW
• City of Edmonton: approx. 300 MW
• City of Red Deer: approx. 70 MW
• 200 MW of DER in central east and southern Alberta
− DER modeled by scaling down loads in the distribution system
• DER integration in the Cities of Edmonton and
Red Deer does not impact transmission system
capability to integrate renewables
• There is a reduction of approximately 60 MW in
transmission system capability for renewable
integration for every 100 MW of DER integrated in
the City of Calgary
• Integration of 100 MW of DER in the south and
central east areas will reduce 100 MW of
transmission system capability for renewables in
these regions
• However, CETO and CRPC will also mitigate the
above concerns and help to enable integration of
DERs in Calgary, SE and CE regions
DER Assessment: Results
28 Public
• The AESO published an Energy Storage
Roadmap in August 2019:
– Sets out the AESO’s plan to facilitate the
integration of energy storage technologies
– Objective is to enable energy storage in
Alberta following guiding principles that
include treating energy storage as its own
unique asset class and removing barriers to its
integration
• The AESO is currently:
– Working with market participants and
stakeholders on integrating storage projects
– Evaluating storage as a transmission deferral
tool (e.g., in the Fort Saskatchewan area)
• Energy storage may be competitive for fast
frequency services needed for imports (loss
of intertie)
Storage
29 Public
Longer-term Developments
Scenario Transmission Developments
Reference Case
• PENV 240 kV conversion for additional renewable integration
capability
• MATL back-to-back HVDC converter (as part of AIR Block 3)
• Keephills to Sundance 500 kV line or 240 kV transmission line
upgrades in the Edmonton region
Alternate
Renewables
Policy (faster-
pace renewables)
• Including Reference Case developments
• Potential EATL bi-pole for additional transfer capability
High Growth
• Including Reference Case developments
• Significant 240 kV developments are required in NW areas for load
growth
High Cogen
• Including Reference Case developments
• 240 kV enhancements (Dover to Birchwood Creek substations) and
500 kV Fort McMurray East (FME) line between Heartland and
Thickwood Hills substations to enhance transfer capability to/from
Fort McMurray 31
South and Central Regions
37 Public
• These regions are rich in renewables
– However, the capabilities shown here are for renewable as
well as conventional generations
• The existing transmission system has approximately 450
MW of maximum remaining capability in southern and
central east areas
• Planned capability enhancements for PENV/CETO/CRPC
– PENV enables up to additional ~350 MW in the system
– CETO can provide additional 700 MW of integration
capability in SE and CE
– CRPC can provide additional 600 MW of integration
capability in the SW
– These capabilities could also be utilized by thermal
generation capacity additions
– Assumes optimized integration; 240 kV and optimal locations
Northern Regions
38
• The capability shown is
based on N-1
considerations
• The planned capability
requires the following
developments:
– 240 kV 9L74 upgrade between
Dover and Birchwood Creek
substations in the NE enables
300 MW (incremental to the
existing)
– 500 kV Fort McMurray East
transmission development
enables 1300 MW
(incremental to the existing)
– 240 kV Fox Creek area
transmission development
Public
FortMcMurray
PeaceRiver
Edmonton
Existing Substation
Future 500 kV Line
Future 240 kV Line
Existing 240 kV Line
Existing 500 kV Line
Northwest
Edmonton/Wabamun
Fort McMurray
Northwest Planning Region Capabilityis shown at individual substations.
FME & Fox Creek Project locationsare representative and do not reflectactual routes or locations.
Date Prepared: 2019-Dec-11
Wesley Creek250 MW 250 MW/
Little Smoky
300 MW 300 MW/
Mitsue
550 MW 550 MW/
Bickerdike
100 MW 300 MW (w/ Fox Creekdevelopments)
/
FOXCREEK
FME
9L74UPGRADE
Northern Alberta Regional Capabilities:Existing Planned/
Edmonton (Sundance,Keephills & Genesee)
2,400 MW 2,400 MW/
Louise Creek
1,000 MW 1,000 MW/
Fort McMurray
500 MW 800 MW (w/ 9L74 Upgrade)1,800 MW (w/ 500 kV FME)
/
Sagitawah
1,000 MW 1,150 MW (w/ Fox Creekdevelopments)
/