Naren Pattani - TX Presentation at APPrO-CanWEA-OWA Workshop, Jan 22 2009

8/6/2019 Naren Pattani - TX Presentation at APPrO-CanWEA-OWA Workshop, Jan 22 2009

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Transmission & Distribution ConsiderationsFor Distributed Generation

Naren Pattani,Manager, Transmission & Connection Planning

January 22, 2009


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Providing Dynamic Voltage Support Requirements

Enabling Transformer Stations (TS) or Upgrade of Existing TSs

Addressing Short Circuit Limitations Additional Enabling Transmission & Distribution

Providing Network Bulk Transmission

Overview


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Estimated Cost of SVCs

*Installed cost, excluding contingency and overloads.

25010Low Voltage, + 2 / -2 MVAR14214.213.8 kV, + 60 / - 40 MVAR

14131.7115 kV, + 200 / - 25 MVAR

94.537.8230 kV, + 300 / - 100 MVAR( Excludes Coupling Transformer )

Unit Cost($K / MVAR )

Cost*($ M )Static VAR Compensator (SVC)

25010Low Voltage, + 2 / -2 MVAR14214.213.8 kV, + 60 / - 40 MVAR

14131.7115 kV, + 200 / - 25 MVAR

94.537.8230 kV, + 300 / - 100 MVAR( Excludes Coupling Transformer )

Unit Cost($K / MVAR )

Cost*($ M )Static VAR Compensator (SVC)

1Source: IESO CAA ID 2007-269

- MX+ MX

7.611.257.47Orangeville (T3/4 )

4.56.6344Orangeville (T1/2)

4.76.930.03Longueuil

7.010.326.03Manitoulin (T4)


6.39.251.94Picton

MVAR RequiredTotal DGMW

# of DGProjects

TS Name- MX+ MX

7.611.257.47Orangeville (T3/4 )

4.56.6344Orangeville (T1/2)

4.76.930.03Longueuil



6.39.251.94Picton

MVAR RequiredTotal DGMW

# of DGProjects

TS Name

Examples of MVAR Requirements 1

Need & Cost of Dynamic Voltage Support

For Reverse Power Flow > 10MW,each 1 MW of all reverse flow

requires +0.484/- 0.329 MVAR Dynamic Voltage Support

Several disadvantages with

relatively small, individually sizedequipment for dynamic support:

High cost due to lack of economy of scale

Each proponent has to planand commit SVCs

System Operator needs

oversight in real time aboutstatus of control


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Proposal for Integrated Planning for SVCIllustration of SVC Requirements / DG MW

Based on Integrated Planning

Hydro One & IESO can determinezone-based, optimum SVC size and

location to connect to TX On the basis of all eligible CIA

applications and supply forecasts

from OPAs IPSP Update

Planning effort has been initiated

Decision on committing the SVCinvestment based on cost recoveryunderstanding

Need to address method of allocatingenabled capacity for DG

Zone SVC MVAR Enables

DG ( MW )

SW Ontario 2 * +300 / -200 1,500 MWCentral 1 * + 300 / - 200 750 MW

East 1 * + 300 / -200 750 MW

North East 1* + 200 / -150 500 MW

North West 1* +200 / -150 500 MW


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Summary of DG Applications

SWO CO EO NWO NEO TOTAL

(i) Theoretical Maximum of Total DG Not Requiring SIA /DVAR (Perfect Dispersion - Reverse Flow By TS < 10 MW) 2137 1070 977 299 306 4789

(ii) Eligible Projects NOT Requiring SIA / DVAR

(Applied & Eligible DGs - Reverse Flow < 10 MW)1214 643 634 90 156 2737

(iii) Eligible Projects Requiring SIA / DVAR (Applied & Eligible DGs - Reverse Flow > 10 MW) 965 575 473 20 256 2289

(iv) Total Applied & Eligible Projects ((ii) + (iii)) 2179 1218 1107 110 412 5026

(v) Projects Requiring DVAR (Subset of (iv); more than (iii))(All Reverse Power, if Reverse Power > 10 MW) 1207 646 592 22 276 2743

DG (MW) By Ontario ZoneDescription

Estimate of DGs Requiring Dynamic Voltage Support(Based on Applications As of December 2008)


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Enabling Transformer Stations

Back-feed limitation constrains DGs atsome existing stations

Where economical, transformers can be replaced with large size

- Outage constraints and spacerequirements may make costs high

In some locations planning new

enabling TS may be more appropriate(generation and load on different TS)

In view of specific (dedicated) natureof investments, need to address:

Method of allocating capacity

Planning assumptions to use totrigger investments

Risk of stranding Cost responsibility

Existing TS

Enabling TS

Transformer can be upgradedif necessary / possible

TX Line

LOAD


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Short Circuit Limitations

Outside GTA, five stations currently constrain DG due toshort circuit rating of the low voltage switchgear rating

o Jarvis TS , Caledonia TS, Port Arthur TS #1, Kingsville TS andBelleville TS

o Alternatives are to upgrade station equipment or to establish new

transmission stations if many DGs are proposed in the vicinityo Need to decide on signal to trigger the investments, and the

methods of allocating capacity and cost

Leaside TS, Manby TS and Hearst TS in Toronto limit DGdue to short circuit rating of switchgear

o Equipments at these stations near end of life hence replacement

can be advanced without significant penaltyo Hydro One expediting project development work


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TX and DX Connections to Enable DG

Planning & construction of facilities relatively simple

In view of specific (dedicated) nature of investments,some high level critical issues need to be addressed

o Appropriate signal to trigger line projects

o Expediting project approval to match relatively shorter timeline of placing DGs in-service

o Allocation of enabled capacityo Cost responsibility

o Risk of stranding if DG does not materialize


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Network Enhancements Underway

Project NameIncrease in TX

Capability(MW)

I/S Date EstimatedCost

Bruce x Milton 500 kV andSVCs in SWO 3,100 MW Dec. 2011 $ 1,000 M

Enhance N-S Transfer 800 MW Dec. 2010 $ 325 M

Cherrywood x Claireville

500 kV Circuits Unbundling1,250 MW Dec. 2010 $ 125 M

Hydro Quebec Intertie ( Incl. in above ) Apr. 2009 $ 125 M

Total 5,150 MW $ 1,550 M

Bulk transfer capacity increases from 1,500 MW to about 6,650MW (including 1,500 MW for refurbished Bruce units)

Up to 2,500 MW can be the eligible DG from ConnectionImpact Assessment queue, depending on spread / location


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Potential Short Term Enhancements

Bulk transfer capacity increases by 2,200 MW to about 8,850 MW

About 3,000 to 4,500 MW of DG can be incorporated, depending onspread/location and MWs of new TX-Connected Gens


Capability(MW)

ConceptualCost

3 SVCs at TSs to Support DGs Enables Reverse Power

Flow at TS$ 200 M

Targeted P&C Enhancements Enables DG in DX $ 90 M

Targeted DX Enhancements Enables DG in DX $ 90 M

Re-conductor / Uprate ExistingCircuits SWO / East 1,400 MW $ 250 M

Niagara Reinforcement ProjectResolution 800 MW Nearly Built

Total 2,200 MW $ 630 M


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Potential Medium Term Enhancements

Bulk transfer capacity increases by 3,050 to about 12,900 MW, of which up to about 8,000MW can be DG , depending on spread/location and MWs of new TX-Connected Gens


Capability(MW)

ConceptualCost

Additional 6 SVCs to Support DGsEnables Reverse

Power Flow at TS $ 400 MP & C Infrastructure Upgrade Enables DG in DX $180 M

DX System Upgrade and Enabling TSs Enables DG in DX $ 300 M

Additional TX Enablers for Renewables Connects GSs $ 800 M

Additional Voltage Compensation in SWOfor Increasing TX Transfer Capability 1,500 MW $ 250 M

Minor TX Reinforcements West of London Included in Above $ 200 M

Toronto Stations Upgrades for DG 250 MW $ 200 MPartial Replacement of Nanticoke MWs 1,250 MW $ 150 M

Total 3,050 MW $ 2,480 M


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Potential Long Term Enhancements

Provides adequate reliability to loads in Northwest Ontario, andenables Renewables in north, development of Darlington B GS

Patricia District Transmission Reinforcement in Northwest Ontario

Major North South Transmission Reinforcemento Sudbury to GTAo Pinard to Sudbury

o Sault St. Marie to Sudburyo East West Tie (series compensation and/or major line)

Major Transmission Reinforcement in Southo Bowmanville x Cherrywoodo West of London


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Thank You / Questions

Documents

Naren Pattani - TX Presentation at APPrO-CanWEA-OWA Workshop, Jan 22 2009