2014 system capacity plan - hydro ottawa...2014 system capacity plan annual planning report...

2014 System Capacity Plan Annual Planning Report

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2014 System Capacity Plan Annual Planning Report

Executive Summary Hydro Ottawa’s system capacity is lagging behind the load growth – currently 15% of substations are above

their specified planning rating. Over the next 20 years significant investment will be necessary to ensure that

sufficient and reliable supply is maintained throughout the city to support the 1050 MVA of forecasted load

growth over this period.

Growth in the city is currently being driven by new residential development in previously rural areas, infill

and intensification in many established areas, as well as major projects like the Ottawa Light Rail Transit

(OLRT) system. Investment of approximately $230 Million in capacity upgrades will be required over the next

20 years to supply the growing demand within HOL’s service territory.

The forecasts, on which this recommendation is based, have been

developed by drawing from developer and City of Ottawa plans

and forecasts, as well as historical growth patterns. System

capacity needs have been identified through internal regional

study, and full system studies such as the ongoing Ottawa Region

Planning Study being completed with participation from Hydro

Ottawa Limited, Hydro One Networks Incorporated – Distribution

and Transmission, the Ontario Power Authority and the

Independent Electrical System Operator.

Hydro Ottawa’s 2014 System Capacity Plan identifies milestones for required system upgrades. This plan has

identified the need to upgrade 13 existing substations, build two new substations and invest in five (5)

transmission upgrades over the next 10 years. These upgrades include projects which are currently being

completed such as the construction of the Terry Fox MTS substation that will supply growth in Kanata and

Stittsville and the expansion of Hinchey TH substation to meet the needs in the core in combination with new

load as the result of the OLRT. Failure to meet these milestones has the potential to increase outage duration

because of the operational challenges created by inadequate supply and operability. Also, such capacity

deficits may cause accelerated equipment deterioration due to overloading at system peak.

If the identified increases in capacity investment are achieved, HOL will be able to keep pace with the City’s

significant growth, while maintaining our high standards of system reliability, safety and operability.

An investment of $230

Million is required to

accommodate an anticipated

load growth of 1050 MVA

over the next 20 years

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Contents Executive Summary .................................................................................................................................. 3

1 Background ...................................................................................................................................... 6

2 System Performance and Statistics .................................................................................................... 7

2.1 Key Measures ....................................................................................................................................... 7

2.2 System Statistics ................................................................................................................................... 8

2.3 System Demand and Energy Statistics ................................................................................................. 9

3 System Study .................................................................................................................................. 11

3.1 Outlook ............................................................................................................................................... 11

3.2 System Evaluation: Method and Criteria ........................................................................................... 13

3.3 13kV System ....................................................................................................................................... 14

3.4 South 28kV ......................................................................................................................................... 18

3.5 South-East 28kV ................................................................................................................................. 20

3.6 East 8kV & 28kV ................................................................................................................................. 22

3.7 West 28 kV ......................................................................................................................................... 24

3.8 Nepean Core 8 kV ............................................................................................................................... 26

3.9 West Nepean 8 kV .............................................................................................................................. 28

3.10 West 8 kV ........................................................................................................................................... 30

3.11 West 12 kV ......................................................................................................................................... 32

3.12 Citywide 44 kV .................................................................................................................................... 33

4 Distributed Generation Capacity ..................................................................................................... 39

4.1 Core 13kV ........................................................................................................................................... 40

4.2 East 13kV ............................................................................................................................................ 41

4.3 West 13kV .......................................................................................................................................... 42

4.4 South 28kV ......................................................................................................................................... 43

4.5 South-East 28kV ................................................................................................................................. 43

4.6 East 8kV & 28kV ................................................................................................................................. 44

4.7 West 28kV .......................................................................................................................................... 44

4.8 Nepean Core 8kV ............................................................................................................................... 45

4.9 West Nepean 8kV ............................................................................................................................... 45

4.10 West 8kV ............................................................................................................................................ 46

4.11 West 12kV .......................................................................................................................................... 46

4.12 City Wide 44kV ................................................................................................................................... 47

5 Bulk System Investments ................................................................................................................ 48

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5.1 Kanata Area ........................................................................................................................................ 48

5.2 South Nepean ..................................................................................................................................... 49

5.3 Downtown Core ................................................................................................................................. 49

5.4 Orleans ............................................................................................................................................... 50

6 Hydro One Networks CCRA ............................................................................................................. 51

6.1 Kanata MTS Phase 1 (2001)................................................................................................................ 52

6.2 Kanata MTS Phase 2 (2003)................................................................................................................ 52

6.3 2005 Hawthorne 115 kV Lines ........................................................................................................... 52

6.4 2008 Cyrville MTS ............................................................................................................................... 52

6.5 2010 Ellwood MTS .............................................................................................................................. 52

6.6 2012 Hinchey TH ................................................................................................................................ 52

6.7 2013 Terry Fox MTS............................................................................................................................ 53

6.8 2013 Marchwood MTS ....................................................................................................................... 53

6.9 2014 Limebank MTS ........................................................................................................................... 53

6.10 2015 Epworth DS ................................................................................................................................ 53

6.11 2016 Lisgar TL ..................................................................................................................................... 53

6.12 2017 Merivale DS ............................................................................................................................... 53

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1 Background

Hydro Ottawa routinely assesses the capability and reliability of the distribution system in an effort to

maintain adequate and reliable supply to customers. Where gaps are found, appropriate plans for additions

and modifications consistent with all regulatory requirements and with due consideration for safety,

environment, finance and supply system reliability/security are developed.

In this regard, the supply needs in the City of Ottawa have been assessed to determine if additions and/or

modifications are required to maintain an adequate and reliable/secure system capacity.

The Hydro Ottawa distribution system is composed of several subsystems, which are segregated by operating

voltage, geographical boundaries, and historic political boundaries. This document summarizes the results of

these studies.

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15% of substations above planning

rating

97.4% of energy purchases

delivered

3.2% of circuits above

planning rating

TABLE 2.1 - KEY PERFORMANCE MEASURES

Measure Target 2009 2010 2011 2012 2013

Stations Exceeding Planning Capacity

≤ 5% 23% (21)

26% (23)

24% (22)

20% (18)

15% (14)

Feeders Exceeding Planning Capacity

≤ 10% - 3.5% (28)

3.4% (27)

3.3% (26)

3.2% (23)

Stations Approaching Rated

Capacity zero

1.1% (1)

4.4% (4)

2.2% (2)

2.2% (2)

3.3% (3)

Feeders Approaching Rated

Capacity zero -

0.4% (3)

0.5% (4)

0.5% (4)

0.3% (2)

System losses ≤ 4% 2.88% 3.12% 3.13% 3.60% 2.63%

2 System Performance and Statistics

2.1 Key Measures

System capacity is currently trailing load growth in the city; this has resulted in fifteen percent of the stations

owned by HOL operating above their planning rating. This planning rating is set to ensure adequate capacity

is reserved for reliable operation during system contingency.

In 2013, three stations were

loaded above their equipment

ratings at system peak:

Richmond North DS, Nepean

TS and Hawthorne TS. Work to

increase capacity at Richmond

South DS is scheduled to begin

in 2015 and will allow for

better load balancing between

Richmond North and South to

alleviate the overload

condition. The Hawthorne TS

units are currently planned for

replacement by Hydro One

and load balancing at Nepean

TS should resolve the slight

overload seen in 2013. There is

a positive trend being shown

in the data: as capacity

projects progress the system is

seeing less stress since 2009.

Losses remained within the acceptable range of between 2% to 4%. Hydro Ottawa continues to work to

reduce system losses through better system planning and the updating or replacement of equipment.

Feeders exceeding their planning ratings are within target (≤ 10%), but careful review and planning is being

undertaken to ensure adequate backup is maintained to allow for secure and reliable delivery of power for

Hydro Ottawa Limited’s Customers.

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2.2 System Statistics

TABLE 2.2 - SYSTEM SUPPLY STATISTICS

2009 2010 2011 2012 2013

Service Area (km2) 1,104 1,104 1,104 1,104 1,104

Total Metered Customers 296,007 300,664 305,059 309,543 314,866

Total Un-Metered Supply Points 55,791 57,619 58,281 59,019 58,973

Total # of Substations Used by HOL

HOL Owned/Co-owned

Used & not owned/co-owned

92

841

8

92

84

8

93

852

8

93

853

8

93

854

8

Total # of Station Transformers

Transmission

Sub-Transmission

166

255

141

166

25

141

167

25

1426

169

277

142

169

298

1409

Notes: 1, 5

Cyrville MTS Energized (2 transmission transformers) 2,6

Janet King DS 28kV Energized (1 sub-transmission transformer)3, 7

Ellwood MTS Energized (2

transmission transformers) & Uplands DS Decommissioned (1 transmission transformer) 4,8,9

Kilborn UP Decommissioned (2 sub-transmission transformers) & Terry Fox MTS Energized (2

transmission transformers)

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2.3 System Demand and Energy Statistics System Load has remained relatively constant over the last five years. The system wide actual summer peak

has grown at an average rate of 1.2% annually since 2009, while winter actual peak has increased at an

average rate of 0.3% annually over the same period. The weather normalized summer peak has shown

modest average annual increase from 2009 to 2013 of roughly 0.1% and the weather normalized winter peak

is in line with the winter actual, showing an average increase of 0.2% over the five year period. The overall

Hydro Ottawa system peak occurs in the summer.

Despite continued increases in connected distribution generation capacity on the system, the contributions

to system energy and peak demand have not grown (Table 2.3).

FIGURE 2.1 –ACTUAL AND WEATHER CORRECTED PEAK DEMAND

FIGURE 2.2 - ANNUAL ENERGY CONSUMPTION

1,000

1,100

1,200

1,300

1,400

1,500

1,600

2009 2010 2011 2012 2013

Pe

ak D

em

and

in M

We

Summer Actual Summer Weather Normalized

Winter Actual Winter Weather Normalized

7,000

7,100

7,200

7,300

7,400

7,500

7,600

7,700

7,800

7,900

2009 2010 2011 2012 2013

GW

Ho

urs

Total Energy Purchased from Bulk System

Total Energy Supplied to HOL Customers

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TABLE 2.3 - SYSTEM DEMAND AND ENERGY STATISTICS

2009 2010 2011 2012 2013

Peak Load-Summer (MW) 1,364 1,518 1,502 1,459 1,427

Peak Load-Winter (MW) 1,268 1,239 1,306 1,242 1,283

Total Energy Supplied to HOL Customers

(Sold, GWh)

7,560 7,595 7,608 7,570 7,519

Total Energy Purchased from Bulk System

(Purchased, GWh)

7,785 7,840 7,851 7,856 7,722

Capacity Utilization 78% 84% 83% 77% 76%

Load Factor 63% 57% 58% 59% 60%

Total Embedded Generation Connected (MW) 29 30 31 55 58

2.3.1 Definitions Peak Load (MW) is defined as the peak electrical demand of the system (in MW).

Total Energy Supplied to HOL Customers (GWh) is the cumulative electrical energy supplied by the

distribution system to the load as measured at the supply point each year.

Total Energy Purchased from Bulk System (GWh) is the cumulative electrical energy purchased by HOL as

metered at the designated supply points each year.

Capacity Utilization (System Peak MW/ Total Station Transformer MVA) is defined as the peak electrical

demand of the system (in MW) divided by the total combined station transformation capacity (in MVA). The

total combined transformation capacity is the sum of all energy delivery points.

Load Factor (Avg. MW/Peak MW) is defined as the average electrical demand of the system (in MW) divided

by the annual system peak demand (in MW).

Total Distributed Generation Connected (MW) is defined as the coincidental peak electrical supply (in MW)

from distributed generation within Hydro Ottawa Limited’s service territory.

% Distributed Generation Supplying Peak is defined as the ratio between the coincidental peak electrical

supply (in MW) from distributed generation within Hydro Ottawa Limited’s service territory and the peak

electrical demand of the system (in MW).

Embedded Generation Energy Production (GWh) is defined as the cumulative electrical energy supplied (in

GWh) from distributed generation within Hydro Ottawa Limited’s Service Area.

% Distributed Generation Energy Production is defined as the ratio between the Distributed Generation

Energy Production (in GWh) and the Total system energy supplied (in GWh).

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3 System Study

3.1 Outlook Overall, the City of Ottawa continues to grow in population and

developed lands, primarily focused in five regions: the downtown

core, Nepean & Riverside South, South Kanata & Stittsville, the

village of Richmond and Orleans. This growth is being seen

through the development of new mixed commercial/residential

communities and intensification of existing communities. Moving

forward, significant investment in capacity for the system, at both

the station and distribution level, will be to catch up to and

maintain pace with the growth in system load. The sidebar

indicates the required station capacity investments over the next

20 years. In addition, there are a number of required distribution

expansions which will be required to bring power from the

substations to the customer site.

There are several necessary upgrades of transmission interties

within the City which will be necessary over the next 20 years to

maintain adequate and reliable supply from the bulk system.

Hydro Ottawa is currently involved in a joint planning study with

Hydro One Networks Inc. (HONI), the Independent Electricity

System Operator (IESO) and the Ontario Power Authority (OPA) to

evaluate the transmission capacity and infrastructure

requirements within the Ottawa region. Preliminary findings

indicate required upgrades to the transmission system in all four

regions of the City: west to Terry Fox MTS, south to Richmond

South DS and Fallowfield DS or a new station, east to supply a

new HONI station (Orleans TS), and to the downtown core to

support load growth across the central 13kV substations.

Figure 3.1 shows the forecasted spending requirements based on

identified system need date. This outlook may not represent

actual annual budgeting and includes forecasted distribution,

station and transmission capacity investments.

2014

•Hinchey TH - 57 MVA

•Limebank MS - 40 MVA

•Startop MS - 5 MVA

•Terry Fox MTS - 100 MVA

•Borden Farm DS - 8 MVA

•Orleans TS (HONI) - 16 MVA

2016

•Lisgar- 53 MVA

•Leitrim MS - 5 MVA

•Overbrook TO - 55.6 MVA

2017 •Merivale MS - 12 MVA

2018 •Uplands DS - 40 MVA

•Bayshore T1- 5 MVA

2019

•Richmond South DS - 67 MVA

•King Edward TK - 56 MVA

•New South 28 kV - 100 MVA

2021 •Limebank MS - 46 MVA

•Bells Corners DS - 4 MVA

2022 •Bridlewood MS - 50 MVA

•Marchwood MS - 33 MVA

2024 •Russell TB - 67 MVA

2026 • QCH DS - 4 MVA

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FIGURE 3.1 - PROJECTED CAPACITY UPGRADE INVESTMENTS

$0

$5

$10

$15

$20

$25

$30

$35

$40

$45

2013 2015 2017 2019 2021 2023 2025 2027 2029 2031

Mill

ion

s

Stations New Capacity Bulk System Line Extensions

Voltage Conversion Levelized

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3.2 System Evaluation: Method and Criteria

Hydro Ottawa plans system capacity based on contingency peak loading and single (N-1) Contingency. The

station and area contingency is considered to be the loss of the largest element, typically either substation

transformer or supply circuit. Under a single contingency, the system is planned to maintain the loading

within the remaining equipment’s top rating (either 10 day Limited Time Rating (LTR) or allowable Flat

Rating).

Each substation supplying Hydro Ottawa customers is forecasted separately using the previous year’s

summer coincident peak as the starting point for the forecast. An average annual load growth rate is

calculated using the station’s historic load level. This rate is used to predict the baseline load growth over the

next twenty years and reflects typical addition of new customers and the load maturation of existing

customers. Additional adjustments are made to the forecast to account for known City of Ottawa and

developer plans, forecasted load transfers and other local knowledge. Loading is weather normalized and a

one in ten year heat wave adjustment is used as a worst case planning scenario.

The supply territory has been divided into separate regions of study based on distribution voltage and

geographic constraints as shown in Figure 3.2. The substation load forecasts are amalgamated to develop

the regional study area forecasts.

Figure 3.2 - Regional Study Areas

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FIGURE 3.3 - 13KV SUPPLY AREA

3.3 13kV System 3.3.1 Study Area The Hydro Ottawa Limited (HOL) 13kV supply region is composed of 3 main areas:

1. The West 13kV supply region covers from Bayview Yards and west of Preston Street to Bayshore Drive, north of Baseline Road. This region is supplied by Hinchey TH, Carling TM, Woodroffe TW and Lincoln Heights TD. Hinchey TH also supports the Core 13kV supply region.

2. The Core 13kV area follows the Rideau River to the East and covers to LeBreton Flats in the West. This region is supplied by King Edward TK, Slater TS, Lisgar TL, Hinchey TH, and Riverdale TR. Riverdale TR and King Edward TK also support the East and Core 13kV supply regions. Hinchey TH also supports the West 13kV supply region.

3. The East 13kV supply region includes the eastern portion of the Old City of Ottawa. This region is supplied by the Russell TB, Albion TA, Ellwood TS, Overbrook TO, Riverdale TR and King Edward TK. Riverdale TR and King Edward TK also support the East and Central 13kV supply regions.

Much of the residential load in this region is not directly supplied from the 13kV system, but rather from a

total of thirty-five 4kV substations, which are supplied from the 13kV system.

1

.

2

3

.

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Capacity Projects

Committed:

(a) Hinchey TH – 57MVA (2014)

Proposed:

(b) Lisgar TL – 53MVA (2016)

(c) Overbrook TO – 55.6MVA (2016)

(d) King Edward TK – 56MVA (2019)

(e) Slater TS – 50MVA (2025)

3.3.2 Forecasted Growth Through the Official Plan, the City of Ottawa is promoting new growth by means of intensification. This

impacts the 13kV system as it covers mostly established areas. Many new developments are trading in low-

rise apartments for larger high density condos. This will reduce the load of the 4kV through conversion onto

the 13kV system but may be taxing with the requirement of new transmission supply.

The majority of the load growth on the 13kV is from new infrastructure projects and City driven community

intensification plans:

The West 13kV new loads include the Ottawa Light Rail Transit (OLRT), Tunney’s Pasture, Bayview Yards, Centrepointe, Richmond Road, and Preston-Carling Area Design Charette.

The Core 13kV is seeing large new loads such as the Ottawa Light Rail Transit (OLRT), the Cliff Street Heating/Cooling Plant (CHCP), Lansdowne Park, LeBreton Flats, Bayview Yards and Transit Oriented Development (TOD).

The East 13k new loads include the Ottawa Light Rail Transit (OLRT), the reconstruction of Rockliffe CFB, Transit Oriented Intensification (TOD), the Bank Street CDP and the Beechwood CDP.

In the short term, there is a requirement for capacity upgrades and the construction of station

interconnections to transfer load at opportune times in order to manage the growth. Longer term planning

will deal with transmission upgrade plans.

3.3.3 Distribution System Analysis Areas of concern for circuit capacity within the region are:

West

New infill projects such as Bayview Yards, LeBreton Flats, Centrepointe and Algonquin College;

Intensification of Richmond Road, Carling-Champagne, Preston-Carling Area; and

West OLRT stations

FIGURE 3.4 - CORE 13KV LOAD FORECAST

800

900

1000

1100

1200

1300

1400

2014 2017 2020 2023 2026 2029 2032

Current LTR Rating Proposed LTR Rating

Forecast Average Growth

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Core

The lack of distribution interconnection points from Hinchey TH and Riverdale TR to other stations in

this area;

New infill projects such as Bayview Yards, LeBreton Flats, Main Street, Lansdowne Park, and Lees

TOD will stress existing circuit capacity; and

Intensification of Rideau Street and Catherine Street.

East

Overbrook TO has limited distribution interconnections limiting system operability and the ability to

manage station loading;

Existing Circuit ties to north east Langs Road area is at capacity; and

Existing Circuit supply to the south east area is approaching capacity (Ages and Hawthorne road

area).

In the short term, there is a requirement for capacity upgrades and the construction of distribution station

interconnections to transfer load at opportune times in order to manage the growth. Longer term planning

will deal with transmission upgrade plans.

3.3.4 System Needs In the short term, there is a need to increase the capacity in the east and core stations to support new

developments and to transfer load from the downtown stations. To perform the required load transfer to

the west, new feeder expansions and inter-station ties will be required.

3.3.5 Major Infrastructure Upgrades

Hinchey TH Expansion

The capacity expansion of Hinchey TH substation began in 2012. The two transformers at Hinchey TH will

have their tertiary winding brought out and allow for the installation of a new bus. The capacity at Hinchey

TH will increase from 42 MVA to 99 MVA and will provide 12 new breaker positions. The project is expected

to be completed in 2014. Feeder expansions out of Hinchey TH will also be required to transfer load from

Lisgar TL to accommodate new growth. Currently 4 feeder expansions are planned for 2014-2015, more will

proceed as necessary.

Hinchey TH is currently limiting generation connection capacity based on its minimum load. This expansion

will allow for increased generation capacity by providing the ability to transfer more load to the station, plus,

the nature of the power transformers will allow some reverse flow capability.

Lisgar TL Upgrade

To accommodate the new load to the west of downtown, upgrading the capacity at Lisgar TL is required to

support Hinchey TH. This project will increase the limited time rating (LTR) capacity from 83 MVA to 133

MVA. Project completion, based on proposed timelines, is expected by 2016.

This upgrade will allow for increased generation capacity availability by upgrading the equipment capacity

which currently has a thermal restriction for any new generation connections.

Overbrook TO Upgrade

The total transformer capacity at Overbrook TO will be upgraded to 144MVA from 82MVA. The transmission

supply to the substation will need to be upgraded to facilitate the increased capacity of this station. This is

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currently being studied under the Joint Regional Supply Study being conducted by HONI, HOL and the OPA.

This upgrade will be required in or about 2016.

King Edward TK Upgrade

The two transformers at King Edward TK substation are currently mismatched in capacity, limiting the overall

available capacity. This project would see the replacement of the undersized transformer thereby increasing

the available LTR of the station from 80 MVA to 136 MVA. The increased capacity will relieve Slater TS and

support the Light Rail Transit (LRT) project. The timelines for this project may be affected by the on-going

joint planning study with the OPA and Hydro One. The study is currently reviewing the A4K 115kV

transmission line which has been identified as having a thermal overload in N-1 contingency loss of the A5RK.

The project need has been identified for 2021.

King Edward TK is currently limiting generation connection capacity based on its minimum load. This

expansion will allow for increased generation capacity by providing the ability to transfer more load to the

station. Also, generation connection capacity can be increased if the power transformers are specified for

reverse flow capability.

Russell TB Upgrade

Russell TB will need to be upgraded to 144MVA from the current 77MVA. There are no known transmission

limitations that should cause delays in this project and will be required in or about 2024.

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3.4 South 28kV 3.4.1 Study Area The South 28kV supply region

includes the southern portions

of Nepean. This region is

supplied by the Fallowfield DS

and Longfields DS 28kV

substations as well as two

feeders from Limebank MS

28kV substation. Despite the

physical barrier of the river

between Nepean and

Gloucester, the Limebank MS

station plays an essential role

in supplying both sides of the

river.

3.4.2 Forecasted Growth Growth in the south supply

region is driven by the ongoing

expansion of suburban

residential developments, the

Nepean Town Centre and the

Strandherd Business Park. In

addition, rural areas south of

the Jock River which are currently fed by the 8KV system will be transferred to the 28kV system as 28kV

feeders are introduced in the area to supply new suburban developments.

Based on the projected load growth, an additional station is required to supply the expected load in the South 28kV area.

Capacity Projects

Proposed:

(a) Added Capacity from Limebank- 16MVA(2016)

(b) New 28kV Station – 100 MVA (2019)

FIGURE 3.5-SOUTH NEPEAN 28KV STUDY AREA

FIGURE 3.6-SOUTH NEPEAN 28KV LOAD FORECAST

(a)

(b)

0

50

100

150

200

2013 2016 2019 2022 2025 2028 2031

MV

A

Current Rating Proposed Rating Forecast

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3.4.3 Distribution System Analysis Overall, the existing south 28kV area is supplied by a strong network of trunk feeders. However, there is the

need to expand the system to cover areas seeing growth, as well as strengthen the interconnections to the

south of the Jock River. These issues will be addressed by the introduction of a new substation that will

support the growth in the Fallowfield DS supply area for the expected load growth.

3.4.4 System Needs There is a need in the short term for a new 28KV station in this region. Based on the forecasted growth it is

proposed to build the new station with 2 X 75 MVA transformers. The proposed new station will solve the

overloading issues in normal operating conditions as well as the N-1 contingency situations to the end of the

study period. Currently, capacity in this area is being evaluated under the Bulk Supply study which will

determine the location of the new station.

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FIGURE 3.8 - SOUTH EAST LOAD GROWTH

(a) (b) (c)

(d)

(e)

0

50

100

150

200

250

2014 2017 2020 2023 2026 2029 2032

MV

A


Capacity Projects

Committed:

(a) Limebank MS –40MVA (2014)

Proposed:

(b) Leitrim (2nd Tx) – 5 MVA (2016)

(c) Uplands (2nd Tx) – 40MVA (2018)

(d) Limebank MS – 46MVA (2021)

(e) South 28kV Support (2026)

3.5 South-East 28kV 3.5.1 Study Area The South-East 28kV supply region includes

the southern portions of Gloucester. This

region is supplied by the Limebank MS,

Uplands MS and Leitrim MS 28kV

substations, as well as a small pocket of 8kV

currently supplied from the Hydro One

South Gloucester substation. Despite the

physical barrier of the river between

Nepean and Gloucester, the Limebank MS

station plays an essential role in supplying

both sides of the river, creating

interdependence between the South 28kV

and the South East 28kV systems.

3.5.2 Forecasted Growth New Load growth in this area is driven by

commercial development in the land

surrounding the airport and residential and

mixed-use developments in the Riverside

South and Leitrim community areas.

FIGURE 3.7 - SOUTH EAST 28KV SUPPLY AREA

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3.5.3 Distribution System Analysis Both Uplands MS and Leitrim MS substations have single supplies and single transformers. With such

configurations it is paramount that sufficient distribution circuit ties are maintained to transfer load to

adjacent stations under contingency. Circuit ties exist for Uplands MS, although station capacity is currently a

limitation to adequately backup capacity for the loss of transformers or supply at Uplands MS.

Given the long reach of the Leitrim MS circuits, back up from Limebank MS or Uplands MS would be a

challenge to maintain voltage at the end-of-line within proper limits. This will be addressed through the

addition of voltage regulators to maintain end-of-line voltage within appropriate limits. The increase of

capacity at Limebank MS will also help in this respect, as it will increase the capability to offload feeders

during contingency.

3.5.4 System Needs Regional capacity will require significant increase in order to keep pace with forecasted growth. Upgrades are

currently underway at Limebank MS to add a third transformer and make provisions for a 4th transformer,

currently projected to be required between 2018 and 2021. In or about 2018, Uplands MS will require an

additional transformer to support growth in the region as well. Supply capacity in the region is anticipated to

lag growth through the second half of the planning period. The load growth during this period is expected to

be met by planned additional upgrades in the South 28kV Region.

While it only results in minor increases to the overall firm capacity in the area, additional transformers are

required at both Leitrim MS and Uplands MS in 2016 and 2018 respectively. These units will improve the

specific region contingencies and station capacity. As load continues to grow in the Leitrim MS supply area

the potential of creating a new transmission connected substation should be evaluated as the existing 44kV

supply is limited and it will be costly to add a second 44kv supply.

Capacity in the South 28kV and the South-East 28kV is currently under study as part of the Bulk System

Supply Study currently underway (see Section 5). This study will impact the final location where new capacity

is located. It is anticipated that the final solution will include increased capacity on the West Side of the river

which will ultimately help support the stations on the East side.

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FIGURE 3.9 - EAST 8KV & 28KV STUDY AREA

3.6 East 8kV & 28kV 3.6.1 Study Area The East 28kV and 8kV supply

area is bounded by the old

Gloucester & Ottawa

municipal boundary and

Highway 417 in the south.

Supply to the region includes

28kV transmission connected

stations: Cyrville MTS, Bilberry

TS and Moulton MS as well as

44kV sub transmission

supplied 8kV substations:

Startop MS, Blackburn MS

and Beaconhill MS.

3.6.2 Forecasted Growth

The East 28/8kV system is

seeing two main pockets of

growth: the East Urban

Community, a combination of

residential and mixed-use

areas, and LRT related load

developing in the vicinity of

the split between highways

417 and 174.

FIGURE 3.10 - EAST 8KV & 28KV LOAD GROWTH

(a)

(b)

100

120

140

160

180

200

220

240

260

2014 2017 2020 2023 2026 2029 2032

MV

A


Capacity Projects

Committed:

(a) Startop MS – 5MVA (2014)

(b) Orleans TS – 16MVA (2014)

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3.6.3 Distribution System Analysis The 28kV & 8kV trunk network provides acceptable coverage of

the region; however, expansion of the Cyrville trunk to the east

(currently underway) will be required to supply the south of

Orleans as it develops.

3.6.4 System Needs From a regional point of view there is sufficient capacity to

address forecasted load growth. Minor changes to address

localized load growth will be required over the next 20 years.

Startop MS Transformer Upgrades

While overall regional capacity is sufficient for future load

growth, the local loading on the Startop MS substation is

currently above the station rating. Due to the distance between

substations this load cannot be effectively supplied from the

other 8kV stations in the area. The upgrade of these

transformers will be coordinated with primary protection

upgrades and automation work occurring on the 44kV

subtransmission in the east. The new station transformers will

increase the station capacity from 15MVA to 20MVA and will be

completed in 2014.

HONI Orleans TS Construction

HONI is constructing a new 28kV station in the vicinity of Mer

Bleue Road and Innes Road. HOL has requested ownership of a single circuit, providing for 16MVA of

capacity. The new Orleans TS feeder will tie into the system currently supplied from the Cyrville F1, reducing

the load on Cyrville MTS and possibly Bilberry TS. The new feeder will be tied into the Mer Bleue Road line

and open points introduced along Renaud Road and Navan Road. It is anticipated that this circuit will be in

service in 2014.

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3.7 West 28 kV 3.7.1 Study Area The West 28kV supply region

includes Kanata and Stittsville.

The region is bounded by

HOL’s service boundary in the

west, south and north.

Eagleson Road has been

utilized as the main boundary

to the east, with the exception

of the Bridlewood Area. The

majority of this service

territory is fed at 28kV;

however, there are pockets

fed at 12kV and 8kV. The 28kV

region is supplied by the

Kanata MTS, Marchwood MS,

Bridlewood MS, Alexander DS,

Janet King DS and the Terry

Fox MTS 28kV substations.


Growth in the west supply

region is driven by the

ongoing expansion of

suburban residential

developments, and associated

mixed-use centres.

Projected load growth in the

Kanata and Stittsville areas is

expected to be supplied from

the recent addition to the

system, Terry Fox MTS. Terry

Fox MTS is located on Michael

Cowpland Drive along the

230kV right-of-way and will mainly supply the areas of new growth, and act as a backup for Bridlewood MS

and Janet King DS. Terry Fox MTS will also be used to off-load the Stittsville load from the Hydro One owned

substation Alexander DS which will allow Hydro One to have available capacity for growth in their service

territory.

The anticipated growth in the Village of Richmond has prompted the upgrade and voltage conversion of the

Richmond South DS substation. Construction is anticipated to begin in 2016 and will increase capacity to

accommodate the expected growth and will increase the capacity of Richmond South DS by 1100%.

FIGURE 3.11 - WEST 28KV STUDY AREA

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FIGURE 3.12 - WEST 28KV LOAD GROWTH

(a)

(b)

(c)

(d)

100

150

200

250

300

350

400

450

2013 2016 2019 2022 2025 2028 2031

MV

A


3.7.3 Distribution System Analysis Overall, the existing west 28kV area is supplied by an adequate network of trunk feeders. There is however

the need to expand the system to cover areas seeing growth, as well as to off-load the Hydro Ottawa load on

Alexander DS. Back-up solutions are also required in the south section of the Stittsville community as well as

create a backup loop across the south-western part of the region including Richmond. These issues will be

addressed by the introduction of six feeders from Terry Fox MTS and the four new feeders planned from

Richmond South DS.

3.7.4 System Needs There is a need in the short term to increase capacity in the Richmond area as well as increase the

transformation at Bridlewood MS and Marchwood MTS to meet the N-1 planning criteria at the station level.

Distribution transfer capabilities can however be maintained allowing station transformers to remain below

capacity in an N-1 situation delaying the need date for capacity upgrades. Due to the future anticipated

capacity demand expected from the Richmond area, Richmond South DS will require an upgrade with voltage

conversion to be capable of meeting this demand. The rebuild is proposed to replace the existing 8kV

transformer with two 28kV 45/60/75 MVA units. Based on the forecasted station growth and the assumed

ability to maintain feeder transfer during a station N-1 contingency it is proposed to completely rebuild the

Bridlewood MS substation by replacing the existing four transformers supplying both 8kV and 28kV, with two

75 MVA units supplying solely 28kV in 2019. In order to maintain supply capacity within the north 28 kV

supply territory it is proposed to replace the 33 MVA transformers at Marchwood MS with 30/40/50 MVA

units (with an assumed LTR of 66 – 1.33 x 50) by 2026.

It is also recommended to consider implementation of one of the

options brought up within the Joint Planning study being conducted

with the Ontario Power Authority and Hydro One Networks Inc. for

bringing a second 230 kV supply into Terry Fox MTS so that it can be

operated as a DESN station. With Terry Fox supplied solely from the

M29C it is not practical to utilize distribution ties to transfer all 6

feeders during a loss of supply. For similar practicalities, a second

supply to Richmond South DS will also be considered.

Capacity Projects

Committed:

(a) Terry Fox MTS – 100MVA (2014)

Proposed:

(b) Richmond South DS – 67MVA (2016)

(c) Bridlewood MS – 50MVA (2019)

(d) Marchwood MS – 33MVA (2022)

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3.8 Nepean Core 8 kV

3.8.1 Study Area The South 8kV supply

region includes the

northern portions of

Nepean. This region is

supplied by the

Manordale DS,

Centrepointe DS,

Woodroffe DS, Epworth

DS, Merivale DS,

Parkwood Hills DS,

Borden Farms DS and

Rideau Heights DS 8kV

substations.


Growth in the 8kV

Nepean supply region is

driven by ongoing

commercial developments and associated mixed-use centers, two major areas of development are the

Nepean Employment Area (located around Hunt Club Road between Merivale Road and Prince of Wales

Drive) and Centrepointe that involves the expansion of Algonquin College and the relocation of the existing

Transit Station.

FIGURE 3.13-NEPEAN CORE 8KV STUDY AREA

Capacity Projects

Proposed:

(a) Borden Farm DS – 8MVA (2015)

(b) Merivale MS – 12MVA (2017)

(c) New 27KV Feeders – 15MVA (2021)

FIGURE 3.14 - NEPEAN 8KV LOAD GROWTH

(a) (b)

(c)

0

20

40

60

80

100

120

140

160

2013 2016 2019 2022 2025 2028 2031

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Nepean Employment Area

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3.8.3 Distribution System Analysis The existing 8kV Nepean area is above the capacity limitations. The area of main concern is the Nepean

employment area in which the trunk feeders are approaching their capacity limitations and the existing

circuit interconnections are weak.

3.8.4 System Needs Over the next 20 years, significant growth is expected for the employment area in the Nepean region. The

expected growth will push the stations and feeders to their capacity limits. The transformers at Merivale DS

and Borden Farm DS are at the end of their useful lifetime, work at Borden Farm is currently in progress and

expected to be completed by 2015. By 2021, new 28KV feeders will need to be introduced in this area along

Hunt Club Road and Prince of Wales Drive where a high concentration of load is expected. In addition, major

circuit reconfiguration and new interconnection ties need to be built in order to maintain a reliable system

for this area.

Borden Farm DS Transformers Replacement The transformers at this station have reached the end of their life and are in need of immediate replacement.

In 2013, a project was started to replace the transformers and it will be completed by 2015. As mentioned in

this report, the exiting transformer size would not be able to supply the additional proposed load in the next

8 years. It is recommended that the transformation at the station be upgraded to 2 x 15MVA.

New Merivale DS Station

This station is at the end of its life and it is planned for replacement starting in 2014 with duration of 5 years

due to its complexity. The current physical conditions at the station would not allow replacing the

transformers and switchgear at the existing location. A new Merivale 8kV station would need to be rebuilt in

a more accessible location close to the 115kV transmission line. Additional capacity is required in order to

service the proposed additional load. It is proposed that the transformation be upgraded to 2x20 MVA

transformers and four feeders per bus.

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FIGURE 3.15- WEST NEPEAN 8KV STUDY AREA

3.9 West Nepean 8 kV

3.9.1 Study Area The West Nepean 8kV supply

region includes the north-west

portions of Nepean. This region

is supplied by the Bayshore DS,

QCH DS, Stafford Road DS and

Bells Corners DS 8kV

substations.

3.9.2 Forecasted Growth Growth in the 8kV West Nepean

supply region has been very slow

in the last couple of years. This

trend is expected to continue

since no major projects for this

area have been identified, except

for the Bayshore mall expansion

which is expected to bring an

additional demand of 2MVA in

the next 1-2 years.

3.9.3 Distribution System Analysis The existing 8kV West Nepean area is below the capacity limitations. No major issues have been identified in

this area of Nepean; however, the transformers at these stations are approaching end of life and will need

replacement during the duration of this study period.

Capacity Projects

Proposed:

(a) Bayshore T1 – 5MVA (2018)

(b) Bells Corners DS–

4MVA (2020)

(c) QCH DS – 4MVA (2026)

FIGURE 3.16 - NEPEAN 8KV LOAD GROWTH

(a) (b)

(c)

0

10

20

30

40

50

60

2013 2016 2019 2022 2025 2028 2031

MV

A


0.5% Average Growth Rate

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3.9.4 System Needs Over the next 20 years, very little growth is expected for the west area of the Nepean region. The expected

growth will not push the stations and feeders to their capacity limits. The transformers at Bayshore DS, Bells

Corners DS and QCH DS will reach the end of their useful lifetime during the length of the study period and

have been identified for replacement in the next 5-15 years.

Bayshore T1 The T1 transformer at this station will be reaching end of life by 2018. Currently, the transformers at this

location do not match in size. It is recommended that the transformation at the station be upgraded to

15MVA. The proposed capacity upgrade will improve the supply availability under a contingency scenario.

Bells Corners DS

The transformers at this station will be reaching end of life by 2020. It is recommended that the

transformation at the station be upgraded to 2 x 12MVA.

QCH DS

The transformers at this station will be reaching end of life by 2026. It is recommended that the

transformation at the station be upgraded to 2 x 12MVA.

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3.10 West 8 kV 3.10.1 Study Area The West 8 kV supply region

includes South Kanata, Stittsville,

The Village of Richmond and

Munster Hamlet. This region is

supplied by the Bridlewood MS,

Janet King DS, Munster DS,

Richmond North DS and

Richmond South DS 8 kV

Substations as well as by the 28

kV Substations Alexander DS,

Beckwith DS and Janet King DS

through the use of distribution

step-down transformers (28 kV

to 8 kV).

3.10.2 Forecasted Growth Growth in the west 8kV supply

region is driven primarily by the

growth in the Village of

Richmond. Based on the Village

of Richmond, City of Ottawa

plans and available information

from other agencies, the key

developments which will

continue to drive growth in this

supply region are all centered in

Richmond and detailed in the

Village of Richmond Community

Design Plan (CDP). The Village of

Richmond CDP outlines the

expansion of industrial and

commercial areas as well as an

increase of 2,850 – 3,950

dwelling units.

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Capacity Projects

Proposed Voltage

Conversions:

(a) Richmond South DS Reduction of 6 MVA (2016)

(b) Bridlewood MS Reduction of 8MVA (2019)


(a)

(b) -20

-10

0

10

20

30

40

2013 2016 2019 2022 2025 2028 2031

MV

A


3.10.3 Distribution System Analysis Overall, the existing west 8 kV area is supplied by an adequate network of trunk feeders. There is however

the need to expand the system to cover areas seeing growth. As there are very few 8 kV feeders (9) that span

a vast geographic region there are limits to capacity as well as the ability to restore under contingency.

3.10.4 System Needs Based on the load growth predicted in the Village of Richmond as well as

capacity demand for Trans Canada’s Energy East Pumping Station, there is a

need in the short term to increase capacity with voltage conversion at

Richmond South DS. The rebuild is proposed to replace the existing 8kV

transformer with two 28kV 45/60/75 MVA units.

Due to aging infrastructure in the Glen Cairn community and at Bridlewood

MS substation, reliability has been greatly impacted and has prompted a

station rebuild. This project is proposed to completely rebuild the substation

by replacing the existing four transformers supplying both 8kV and 28kV,

with two 75 MVA units supplying solely 28kV in 2019.

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Capacity Projects

None


0

5

10

15

20

25

2013 2016 2019 2022 2025 2028 2031

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0.5% Average Growth Rate

3.11 West 12 kV 3.11.1 Study Area The West 12 kV supply region is

located in central Kanata,

including the communities of

Katimavik and Beaverbrook. This

region is supplied by the

Beaverbrook MS, and South March

MS substations.

3.11.2 Forecasted Growth The West 12 kV area is bounded

by 28kV supplied areas on all sides

and is anticipated that all future

growth will be supplied from 28 kV

sources.

3.11.3 Distribution System Analysis

Overall, the existing West 12 kV

area is supplied by an adequate

network of trunk feeders and can

be recovered in N-1 contingency

circumstances.

3.11.4 System Needs Based on only infill load growth

predicted in the west 12kV supply

area, the system will only require

regular inspection and maintenance to continue providing the demanded capacity.

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3.12 Citywide 44 kV 3.12.1 Study Area The 44 kV system spans the entire service area and is supplied from three stations: Hawthorne TS, Nepean TS

and South March TS. The following map outlines the trunk circuit routing from each of these three stations.

FIGURE 3.19 - 44KV STUDY AREA

Each station area is essentially independent of the others with limited connections between South March TS

and Nepean TS and between Hawthorne TS and Nepean TS.

The following figures outline the trunk feeder network as well as the substations supplied by the three 44 kV

stations.

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FIGURE 3.20 - HAWTHORNE TS STATION SUPPLY AREA

Stations supplied by Hawthorne TS:

Beaconhill MS – 44 / 8.32 kV

Blackburn MS – 44 / 8.32 kV

Borden Farm DS – 44 / 8.32 kV

Leitrim MS – 44 / 27.6 kV

Startop MS – 44 / 8.32 kV

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FIGURE 3.21 - NEPEAN TS STATION SUPPLY AREA

Stations supplied by Nepean TS:

Barrhaven DS – 44 / 8.32 kV

Bayshore DS – 44 / 8.32 kV

Bells Corner DS – 44 / 8.32 kV

Jockvale DS – 44 / 8.32 kV

Longfields DS – 44 / 27.6 kV

Merivale DS – 44 / 8.32 kV

Parkwood Hills DS – 44 /8.32 kV

Q.C.H. DS – 44 / 8.32 kV

Rideau Heights DS – 44 /8.32 kV

Stafford Road DS – 44 /8.32 kV

Woodroffe DS – 44/8.32 kV

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FIGURE 3.22 - SOUTH MARCH TS STATION SUPPLY AREA

Stations supplied by South March TS:

Alexander DS – 44 / 27.6 kV

Beaverbrook MS – 44 / 12.4 kV

Bridlewood MS – 44 / 8.32 kV & 44 / 27.6 kV

Janet King DS – 44 / 8.32 kV & 44 /27.6 kV

Munster DS – 44 /8.32 kV

Richmond North DS – 44 /8.32 kV

South March MS – 44 / 12.4 kV

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Capacity Projects

Proposed:

(a) Hawthorne TS – 51MVA (2016)

There are no capacity issues

forecasted at Nepean TS. The

load forecast shows a

decreasing trend based on the

conversion of 8kV load (fed

from 44/8kV stations) to the

28kV system.

There are no capacity issues

forecasted at South March TS

during the study period. The

load forecast shows a

decreasing trend based on

load transfers to transmission

connected stations.

3.12.2 Forecasted Growth Based on the vast area that these stations cover and their independent nature, they have been studied as

separate stations as opposed to as a single region. Through the Joint Planning Study currently under way with

the OPA and HONI, the load forecast for each of the stations has been developed.

FIGURE 3.23 - HAWTHORNE TS LOAD GROWTH

0

50

100

150

200

2013 2016 2019 2022 2025 2028 2031

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A


FIGURE 3.24 - NEPEAN TS LOAD GROWTH

130

135

140

145

150

155

160

165

2013 2016 2019 2022 2025 2028 2031

MV

A


FIGURE 3.25 – SOUTH MARCH TS LOAD GROWTH

0

20

40

60

80

100

120

140

2013 2016 2019 2022 2025 2028 2031

MV

A


(a)

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3.12.3 Distribution System Analysis In order to improve reliability performance in the East end of the city the loop of feeders from Hawthorne TS

will be automated, the details of which can be found in the Reliability Plan Report.

The Nepean TS 44kV system is built in a network configuration and at this time there are no significant issues

identified with the distribution arrangement.

The 44kV trunk network from South March TS is adequate, except for the single radial feeder (A9M3) that

runs south of Maple Grove Road. The radial section of A9M3 supplies three 44/8kV stations: Janet King DS,

Richmond North DS and Munster DS. In order to improve reliability performance the 22M25 out of Nepean

TS will be extended into the southern part of the West service territory to serve as a backup to these stations.

Construction is anticipated and to begin in 2015 and be operational in 2017.

3.12.4 System Needs Additional capacity is required at Hawthorne in the near term and at South March TS in the long term, after

the end of the study period. HOL must formally apply to HONI for additional capacity at Hawthorne TS, the

logistics of which will be jointly discussed. It is currently assumed that a total station capacity of 150 MVA is

feasible with a timeframe for completion around 2016. An additional 44kV station is being proposed in the

Richmond area which will create dual supplies to some of the rural 44kV supplied substations, create

additional feeder ties for contingency operability and will help off-load the heavily loaded feeders from South

March TS and Nepean TS.

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4 Distributed Generation Capacity System capacity to connect distributed generation can be limited by several factors such as:

1. Station loading – some station transformers have limited or no capability for reverse power flow. At these stations, total connected generation cannot exceed either 60% of top transformer rating plus minimum loading, or in the most restrictive case where there is no reverse flow capability, generation is limited to the minimum station loading.

2. Feeder Thermal Rating – the feeder ampacity rating must be respected to not overheat the conductors and connected equipment. Unlike when planning for N-1 feeder load restoration contingency, for distributed generation, the available thermal capacity is the full feeder ampacity rating less contingency.

3. Short Circuit Rating – connection of distributed generation will increase the available current that flows through the system during faults. The total available current during faults cannot exceed the system rating.

4. Power Quality – four concerns arise when connecting distributed generation: a. harmonics caused by inverter based generation; b. phase imbalance caused by single-phase generators; c. voltage instability caused by generators connected at various points along a feeder, or

by induction generators requiring reactive power; and d. flicker caused by generators intermittently turning on and off - they can affect the

voltage on the circuit impacting the quality of supply to Hydro Ottawa customers. The generation connected to both feeders and station must be managed to prevent adverse impact to HOL load customers.

Hydro Ottawa Limited’s Service Area was under a transmission constraint due to the short circuit rating of

115kV transmission breakers located at the Hydro One Networks Inc. (HONI) owned Hawthorne TS. As a

result, no generation project larger than 10kW was permitted to connect after FIT1.0. However, since HONI’s

breaker upgrade is largely completed and scheduled for final completion by June 2014, the OPA has allowed

for up to 150MW made available now for generation applications in the region. The remaining 150MW will

be made available upon project completion. Despite this, some stations remain restricted from any

generation connection regardless of size.

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4.1 Core 13kV The substations in the Core 13kV region are co-owned by Hydro Ottawa and Hydro One Networks

Incorporated. Currently, there are connection restrictions at the Slater TS, and one bus at Lisgar TS. Slater TS

is limited due to short circuit levels at the station, whereas Lisgar TS is currently limited by the minimum

normal loading on the station bus. The proposed upgrades at Lisgar TS substation will allow loading at this

station to increase which is anticipated to alleviate the current restriction at this location.

We are presently aware of over 29.35MW of proposed large generation within the Core 13kV region for

connection within the next three years. Ideally, for better utilization and load relief, this generation would

connect to the High Voltage Distribution Stations HVDSs in the Core rather than those in West 13kV.

Specifically, rather than connect to the capacity available Carling TS, connecting to Hinchey TS and Lisgar TS

would better benefit HOL’s Grid management. HOL is pursuing the options with HONI and the OPA.

Please note that the information in the tables in this section may change at any time as HOL may, for better

operational performance, reconfigure the Grid or offer Proponents alternate connections, or as a project

connection opportunity may expire. Also, micro-generation projects are not included in the “potential”

column given the 30% likelihood of connecting before contract offer expiry. The generation connected, in-

process or proposed may be of various energy source, capacity or connection/contract type.

TABLE 4.1 – CORE 13KV EMBEDDED GENERATION CONNECTIONS

Station

Connected In-Process Proposed

Number of

Connections

Nameplate

Capacity

(MW)

Number of

Connections

Nameplate

Capacity

(MW)

Number of

Connections

Nameplate

Capacity

King Edward TK

JY bus 8 2.62 1 0.035 0 0

King Edward TK

QZ bus 8 0.074 0 0 1 0.135

Lisgar TL

JY bus 6 16.76 Restricted due to thermal constraint

Lisgar TL

QZ bus 11 0.0708 0 0 0 0

Slater TS

B1B2 bus 1 0.010 Restricted due to short circuit constraint

Slater T

J1J2 bus Restricted due to short circuit constraint

Slater TS

Q1Q2 bus Restricted due to short circuit constraint

Hinchey TH 19 2.13 0 0 0 0

Riverdale TR

JY bus 11 0.0789 1 0.050 0 0

Riverdale TR

QZ bus 25 0.194 0 0 1 0.050

Total 89 21.9377 1 0.05 2 0.185

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4.2 East 13kV There are currently no regional substation restrictions for the connection of distributed generation at the

East 13kV substations. The proposed upgrades at King Edward TK substation may lower the available

connection capacity due to increased available fault current from the larger substation transformers.

TABLE 4.2 - EAST 13KV EMBEDDED GENERATION CONNECTIONS

Station


Number of

Connections

Nameplate

Capacity

(MW)

Number of

Connections

Nameplate

Capacity

(MW)

Number of

Connections

Nameplate

Capacity

Russell TB

BY bus 8 0.343 2 0.400 2 0.350

Russell TB

QZ bus 11 0.540 6 0.580 1 0.750

Albion TA

BQ bus 13 0.117 0 0 1 0.100

Albion TA

JY bus 33 0.468 6 0.400 2 0.200

Ellwood TS 0 0 1 0.250 0 0

Overbrook TO

J1J2 bus 12 0.099 3 0.700 2 0.150

Overbrook TO

Q1Q2 bus 25 0.174 3 0.525 0 0

Riverdale TR

JY bus 11 0.0789 1 0.050 0 0

Riverdale TR

QZ bus 25 0.194 0 0 1 0.050

King Edward TK

JY bus 8 2.62 1 0.035 0 0

King Edward TK

QZ bus 8 0.074 0 0 1 0.135

Total 154 4.7079 23 0.05 10 1.735

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4.3 West 13kV Presently, the Lincoln Heights TS B1B2 bus pair is restricted to allow connection of only renewable micro-

generation.

The OPA has approved a 29.35MW large hydro generation facility in the downtown core. At the time of

project application, Carling TS was the readily available station with capacity. However, now that HONI and

HOL confidently project completion of the Hinchey TS transformer and switchgear upgrade by Q4, 2015, HOL

is pursuing normal connection of this new generation facility to Hinchey TS and perhaps one or two units on

occasion to Lisgar TS. This would provide HOL with greater benefit to its Grid management strategy. As per

the manufacturer’s recommendation, HONI is presently restricting reverse flow through the existing Hinchey

TH transformers to the minimum station load. The station upgrade will allow for more loading of Hinchey TS,

and reverse flow of 60% of the top transformer rating plus minimum load with the requirement to keep the

loading (with and without generation) on the secondary windings balanced. HOL has not yet included the

proposed new generation capacity in Table 3.3 below, but will included it in the appropriate generation table

once it receives a formal project application and confirms the connection station .

TABLE 4.3 - WEST 13KV EMBEDDED GENERATION

Station


Number of

Connections

Nameplate

Capacity

(MW)

Number of

Connections

Nameplate

Capacity

(MW)

Number of

Connections

Nameplate

Capacity

(MW)

Carling TS

KY bus 26 0.278 0 0 1 0.100

Carling TS

QZ bus 12 0.090 2 0.200 0 0

Hinchey TH 19 2.130 0 0 0 0

Lincoln Heights

TD

B1B2 bus

16 0.132 Restricted due to thermal constraint

Only micro-generation connections allowed

Lincoln Heights

TD

Y1Y2 bus

9 5.060 0 0 1 0.100

Woodroffe TW

BJ bus 6 0.051 0 0 0 0

Woodroffe TW

QZ bus 10 0.156 2 0.100 0 0

Total 98 7.897 4 0.300 2 0.200

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4.4 South 28kV Currently, half of Fallowfield MTS is restricted due to thermal limitations. Plasco Energy Demo and Energy

Ottawa’s Trail Road generation facilities are connected to this station and capacity for up to 16MW has been

reserved for a Plasco Energy production generation facility.

TABLE 4.4 - SOUTH 28KV EMBEDDED GENERATION

Station


Number of

Connections

Nameplate

Capacity

(MW)

Number of

Connections

Nameplate

Capacity

(MW)

Number of

Connections

Nameplate

Capacity

(MW)

Fallowfield DS

J bus 2 10.950 1 16

Restricted due to thermal

constraint

Fallowfield DS

Q bus 6 0.131 0 0 0 0

Longfields DS The HVDS is HONI’s South March TS - included in Section 4.12 City Wide 44kV.

Limebank MS

B1 bus 7 0.061 0 0 0 0

Limebank MS

B2 bus 19 0.313 0 0 0 0

Total 34 11.455 1 16 0 0

4.5 South-East 28kV There are currently no regional substation restrictions for the connection of distributed generation at the

South-East 28kV stations.

TABLE 4.5 - SOUTH-EAST 28KV EMBEDDED GENERATION

Station


Number of

Connections

Nameplate

Capacity

(MW)

Number of

Connections

Nameplate

Capacity

(MW)

Number of

Connections

Nameplate

Capacity

(MW)

Limebank

MS

B1 bus

7 0.061 0 0 0 0

Limebank

MS

B2 bus

19 0.313 0 0 0 0

Uplands MS 9 0.238 0 0 0 0

Leitrim DS The HVDS is HONI’s Hawthorne TS. included in Section 4.12 City Wide 44kV.

Total 35 0.612 0 0 0 0

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4.6 East 8kV & 28kV There are currently no regional station restrictions for the connection of distributed generation at the East

28kV & 8kV stations.

TABLE 4.6 - EAST 8KV & 28KV EMBEDDED GENERATION

Station


Number of

Connections

Nameplate

Capacity

(MW)

Number of

Connections

Nameplate

Capacity

(MW)

Number of

Connections

Nameplate

Capacity

(MW)

Cyrville MTS 7 65.80 3 0.7420 0 0

Bilberry Creek TS 23 0.7150 1 0.1000 0 0

Moulton MS

B1 bus 10 0.0794 0 0 0 0

Moulton MS

B2 bus 0 0 0 0 0 0

Total 40 66.5944 4 0.842 0 0

4.7 West 28kV There are currently no regional station restrictions for the connection of distributed generation at the West

28kV stations.


Station Connected In-Process Proposed

Number of

Connections

Nameplate

Capacity

(MW)

Number of

Connections

Nameplate

Capacity

(MW)

Number of

Connections

Nameplate

Capacity

(MW)

Kanata MTS 19 0.1690 2 0.942 0 0

Marchwood MS

J bus

13 0.1710 0 0 0 0

Marchwood MS

Q bus

2 0.0150 0 0 0 0

Bridlewood MS

B1 bus

6 0.0385 0 0 0 0

Bridlewood MS

Q bus

6 0.0535 1 0.150 0 0

Alexander DS HONI station. The HVDS is HONI’s South March TS - included in Section 4.12 City Wide 44kV.

Janet King DS The HVDS is HONI’s South March TS - included in Section 4.12 City Wide 44kV.

Terry Fox MTS

J bus

0 0 0 0 0 0

Terry Fox MTS

Q bus

0 0 0 0 0 0

Total 46 0.4470 3 1.092 0 0

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4.8 Nepean Core 8kV Connection of generation to one bus at Centrepointe DS is restricted due to short-circuit ratings, affecting 3

of the 6 feeders from this substation.

TABLE 4.8 - NEPEAN CORE 8KV EMBEDDED GENERATION

Station Connected In-Process Proposed

Number of

Connections

Nameplate

Capacity

(MW)

Number of

Connections

Nameplate

Capacity

(MW)

Number of

Connections

Nameplate

Capacity

(MW)

Manordale DS

B1 bus

3 0.0240 0 0 0 0

Manordale DS

B2 bus

4 0.0344 0 0 0 0

Centrepoint DS

B1 bus

4 0.0380 0 0 0 0

Centrepoint DS

B2 bus

3 0.0400 0 0 0 0

Woodroffe DS The HVDS is HONI’s Nepean TS - included in Section 4.12 City Wide 44kV.

Epworth DS

B bus

2 0.0190 0 0 0 0

Epworth DS

Q bus

2 0.0116 0 0 0 0

Merivale MS

B1 bus

1 0.0100 1 0.075 0 0

Merivale MS

B2 bus

2 0.0220 0 0 0 0

Parkwood Hills DS The HVDS is HONI’s Nepean TS - included in Section 4.12 City Wide 44kV.

Borden Farms DS The HVDS is HONI’s Nepean TS - included in Section 4.12 City Wide 44kV.

Rideau Heights DS The HVDS is HONI’s Nepean TS included in Section 4.12 City Wide 44kV.

Total 14 0.1364 0 0 0 0

4.9 West Nepean 8kV There are currently no regional station restrictions for the connection of distributed generation at the West

Nepean 8kV stations. All these stations are supplied from HONI HVDSs, either South March TS or Nepean TS.

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8kV stations.


Station


Number of

Connections

Nameplate

Capacity

(MW)

Number of

Connections

Nameplate

Capacity

(MW)

Number of

Connections

Nameplate

Capacity

(MW)

Bridlewood MS

Q bus 6 0.0535 1 0.150 0 0

Bells Corners

DS The HVDS is HONI’s Nepean TS – included in Section 4.12 City Wide 44kV.

Janet King DS The HVDS is HONI’s South March TS – included in Section 4.12 City Wide 44kV.

Munster DS The HVDS is HONI’s South March TS– included in Section 4.12 City Wide 44kV.

Richmond

North MS The HVDS is HONI’s South March TS– included in Section 4.12 City Wide 44kV.

Richmond

South DS 6 0.0510 1 0.250 0 0

Alexander DS HONI station. The HVDS is HONI’s South March TS– included in Section 4.12 City Wide 44kV.

Beckwith DS HONI station.

Total 12 0.1045 2 0.4 0 0


12kV stations.


Station


Number of

Connections

Nameplate

Capacity

(MW)

Number of

Connections

Nameplate

Capacity

(MW)

Number of

Connections

Nameplate

Capacity

(MW)

Beaverbrook

MS The HVDS is HONI’s South March TS - included in Section 4.12 City Wide 44kV.

South March

DS The HVDS is HONI’s South March TS - included in Section 4.12 City Wide 44kV.

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4.12 City Wide 44kV There are currently no regional station restrictions for the connection of distributed generation at the 44kV

Stations.

TABLE 4.11 - CITY WIDE 44KV EMBEDDED GENERATION

Station


Number of

Connections

Nameplate

Capacity

(MW)

Number of

Connections

Nameplate

Capacity

(MW)

Number of

Connections

Nameplate

Capacity

(MW)

Hawthorne

TS 32 10.81 10 0.460 0 0

Nepean TS 55 2.270 8 1.200 4 0.475

South March

TS 25 0.217 6 0.535 0 0

Total 112 13.297 24 2.195 4 0.475

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FIGURE 5.1 - KANATA AREA EXISTING TRANSMISSION ARRANGEMENT

5 Bulk System Investments A joint planning study of the bulk supply to the city is

currently underway with participation from the Ontario

Power Authority, Hydro One Networks Inc. transmission

and distribution, and the Independent Electricity System

Operator. This study began November 2010 and the

purpose was to evaluate the transmission system needs for

the next 20 years based on the forecasted load growth at

transmission connected distribution stations. Two scenarios

are being considered, a reference case and a high growth

case that assumes that load growth accumulates at a faster

rate. As the study is still ongoing, the following section

outlines the issues that have been identified through this study, but not the solutions currently in discussion.

The outcome of the study will be the optimal solution to resolve the issues, taking into consideration the

impacts to both the transmission and distribution systems. For the purposes of the study, four regions of

concern are being considered: Kanata, South Nepean, Downtown Core and Orleans.

5.1 Kanata Area The Kanata Area considers the load growth at five stations: Bridlewood MS (115kV connected transformers

BRDT1 & BRDT2), Kanata MTS, Marchwood MS, Terry Fox MTS and South March TS.

The issues identified for this

station grouping are the thermal

overload on the 115 kV S7M as

well as the violation of the

Ontario Resource and

Transmission Assessment Criteria

(ORTAC) load loss criteria (> 150

MW loss during contingency) for

the high growth case. Currently,

the S7M (115kV) supplies

Marchwood MS, Bridlewood MS,

Richmond South DS and

Fallowfield DS or approximately

25,000 customers, 9% of HOLs

customer base. With the 230kV

connection of Terry Fox MTS to

the single circuit M29C, an issue

was identified with the reliability

of the circuit, and contingency if and when maintenance is performed on this line. To address this issue,

solutions to bring a second 230kV line to Terry Fox MTS are under review.

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FIGURE 5.2 - SOUTH NEPEAN AREA EXISTING TRANSMISSION ARRANGEMENT

5.2 South Nepean The South Nepean area is defined by the grouping of nine stations: Fallowfield DS, Limebank MS, Uplands

MS, Nepean TS, Epworth DS, Manordale, Centrepointe DS, Richmond South DS and Manotick DS (HONI

owned). The driving issue in the South Nepean area is the sparse transmission supply and the amount of load

growth being seen in the area. There is a need to increase the capacity in the south to supply the new

developments, a number of options are being considered, including upgrades at Limebank MS, Fallowfield DS

and/or a new 28kV station, all of which require upgrades to the transmission system.

5.3 Downtown Core The stations in the downtown core were subdivided into three categories to align with the station

distribution territory and the transfer capabilities between them. The three areas are broken down as

follows:

Group “A” – Carling TM, Lincoln Heights TD and Woodroffe TW

Group “B” – Hinchey TH, Slater TS, Lisgar TL and King Edward TK

Group “C” – Russell TB, Overbrook TO, Albion TA, Ellwood MTS and Riverdale TR

Table 5.1 summarizes the needs in each of the three groups as well as at the transmission level.

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TABLE 5.1 - DOWNTOWN CORE NEEDS

Needs Reference Forecast High Growth Forecast

Transformation

Capacity Needs

Group A No need as a group No need as a group

Carling overloaded starting 2019

Group B Capacity shortfall in 2016

55 MW additional capacity needed

in 2030

Capacity shortfall in 2013

108 MW additional capacity

needed in 2030

Group C Capacity shortfall in 2026

20 MW additional capacity needed

in 2030

Capacity shortfall in 2018

80 MW additional capacity

needed in 2030

Circuit Needs A4K N-1 thermal overload on loss

of A5RK starting 2017

A4K N-1 thermal overload on

loss of A5RK starting 2015

M5G N-1 thermal overload on

loss of M4G starting 2030

5.3.1 Group “A” There are no major capacity concerns with this group; therefore there is no impact on the transmission

system that supplies these stations.

5.3.2 Group “B” The load pocket described as Group “B” is seeing significant load growth, and as such will require capacity

upgrades. The transmission in this area is currently constrained by thermal overload under N-1 contingency

and any upgrades at the station level will trigger transmission upgrades. A number of upgrade options were

considered and included possible capacity increases at Hinchey TH, Lisgar TL and/or King Edward TK. After

further review it was decided to start moving forward with transformer replacement at Lisgar TL to increase

the capacity.

5.3.3 Group “C” The load pocket described as Group “c” is seeing significant load growth, and as such will require capacity

upgrades. The transmission in this area is currently constrained by thermal overload under N-1 contingency

and any upgrades at the station level will trigger transmission upgrades. A number of upgrade options are

being considered and include possible capacity increases at Russell TB and/or Overbrook TO.

5.4 Orleans The Orleans area considers the load growth at four stations: Moulton MS, Cyrville MTS, Bilberry Creek TS and

a new HONI owned station being proposed – Orleans TS. The major concern in this pocket is creating a

reliable supply to Orleans TS. Currently, it is proposed to supply Orleans TS at two different voltages, one tap

off of 115kV and one tap from 230kV. In order to improve the reliability of this station a number of

transmission upgrades are being considered the impact on the supplies to both Bilberry Creek TS and

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