Post on 07-Apr-2018
8/6/2019 Naren Pattani - TX Presentation at APPrO-CanWEA-OWA Workshop, Jan 22 2009
1/13
1
Transmission & Distribution ConsiderationsFor Distributed Generation
Naren Pattani,Manager, Transmission & Connection Planning
January 22, 2009
8/6/2019 Naren Pattani - TX Presentation at APPrO-CanWEA-OWA Workshop, Jan 22 2009
2/13
2
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
8/6/2019 Naren Pattani - TX Presentation at APPrO-CanWEA-OWA Workshop, Jan 22 2009
3/13
3
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)
7.010.326.14Manitoulin (T3)
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
7.010.326.03Manitoulin (T4)
7.010.326.14Manitoulin (T3)
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
8/6/2019 Naren Pattani - TX Presentation at APPrO-CanWEA-OWA Workshop, Jan 22 2009
4/13
4
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
8/6/2019 Naren Pattani - TX Presentation at APPrO-CanWEA-OWA Workshop, Jan 22 2009
5/13
5
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)
8/6/2019 Naren Pattani - TX Presentation at APPrO-CanWEA-OWA Workshop, Jan 22 2009
6/13
6
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
8/6/2019 Naren Pattani - TX Presentation at APPrO-CanWEA-OWA Workshop, Jan 22 2009
7/13
7
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
8/6/2019 Naren Pattani - TX Presentation at APPrO-CanWEA-OWA Workshop, Jan 22 2009
8/13
8
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
8/6/2019 Naren Pattani - TX Presentation at APPrO-CanWEA-OWA Workshop, Jan 22 2009
9/13
9
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
8/6/2019 Naren Pattani - TX Presentation at APPrO-CanWEA-OWA Workshop, Jan 22 2009
10/13
10
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
Project NameIncrease in TX
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
8/6/2019 Naren Pattani - TX Presentation at APPrO-CanWEA-OWA Workshop, Jan 22 2009
11/13
11
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
Project NameIncrease in TX
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
8/6/2019 Naren Pattani - TX Presentation at APPrO-CanWEA-OWA Workshop, Jan 22 2009
12/13
12
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
8/6/2019 Naren Pattani - TX Presentation at APPrO-CanWEA-OWA Workshop, Jan 22 2009
13/13
13
Thank You / Questions