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.

2020 LTP Planning Cycle

4 Public

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 Stakeholder Engagement Framework

7

AESO 2019 Long-term Outlook (LTO)

2020 LTP Near-term developments

Peter Huang, P. Eng.

Senior Engineer, System Planning

AESO 2019 Long-term Outlook (LTO)

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

2019 LTO Load Forecast

11 Public

Generation Capacity (2039)

12 Public

2020 LTP Near-term developments

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


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


138/144 kV



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.


Public

Northeast Region

16

• Voltage support in the Fort McMurray area - Load: voltage

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



240 kV Substation

500 kV Substation

HVDC Line

Future 69/72 kV

Future 240 kV

Normally Open Line

69/72 kV



138/144 kV


240 kV

240 kV Double Circuit

500 kV



AESO Planning Areas


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)


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 (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

City of Edmonton

19 Public

Central Region

20

• Central East Transfer-out (CETO)

– To strengthen transfer-out capability for integrating new generation


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


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



240 kV Substation

500 kV Substation

HVDC Line

Future 138/144 kV

69/72 kV


138/144 kV



240 kV


500 kV


AESO Planning Areas


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

Distributed Energy Resources &

Energy Storage

• 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

2020 LTP Longer-term developments

Public 30

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


• Significant 240 kV developments are required in NW areas for load

growth

High Cogen


• 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

Reference Case

32 Public

Alternate Renewables Policy (Faster-Pace Renewables)

33 Public

High Growth

34 Public

High Co-gen

35 Public

Generation Integration Capabilities

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)

/

Questions?

2020 long-term transmission plan - aeso

Documents