IESO Expedited System Impact Assessment
NORMAN T1 REPLACEMENT AND SUBSTATION UPGRADE
2013-EX670
FINAL REPORT
Executive Summary
Conditional Approval for Connection
H2O Power LP (the “connection applicant”) is proposing to replace the main output transformer T1 at
Norman GS, add a new HV circuit breaker and replace the existing HV disconnect switch.
This assessment concluded that the proposed changes are expected to have no material adverse impact
on the reliability of the IESO-controlled grid. Therefore, the IESO recommends that a Notification of
Conditional Approval for Connection be issued for Norman T1 replacement and other proposed
substation upgrades, subject to implementation of the requirements outlined in this report.
The connection applicant shall satisfy all applicable requirements and standards specified in the Market
Rules and the Transmission System Code. The following requirements summarize some of the general
requirements that are applicable to the proposed project, and presented in detail in section 2 of this
report.
Requirements
Voltage
The connection applicant shall ensure that the 115 kV equipment is capable of
continuously operating between 113 kV and 132 kV, as specified in Appendix 4.1 of the Market Rules.
Protective relaying must be set to ensure that transmission equipment remains in-service for voltages
up to 5% above the maximum continuous value.
Appendix 2 of the Transmission System Code states that the maximum rated interrupting time for the
115 kV breakers must be ≤ 5 cycles. Thus, the connection applicant shall ensure that the installed
breakers meet the required interrupting time specified in the Transmission System Code. Fault
interrupting devices must be able to interrupt fault currents at the maximum continuous voltage of 132
kV.
Protections
The connection applicant shall ensure that the protection systems are designed to
satisfy all the requirements of the Transmission System Code and any additional requirements identified
by the transmitter. New protection systems must be coordinated with the existing protection systems.
Reactive Power
The proposed facility shall inject or withdraw reactive power continuously (i.e.
dynamically) at a connection point up to 33% of its rated active power at all levels of active power
output except where a lesser continually available capability is permitted by the IESO.
Fault Levels
The connection applicant shall ensure that the new equipment at the facility be
designed to withstand the fault levels in the area. If any future system changes result in an increased
fault level higher than the equipment’s capability, the connection applicant is required to replace the
equipment with higher rated equipment capable of withstanding the increased fault level, up to
maximum fault level specified in Appendix 2 of the Transmission System Code.
Final Report
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Norman T1 Replacement and Substation Upgrade
2013-EX670
Connection Equipment Design The connection applicant shall ensure that the connection equipment is
designed to be fully operational in all reasonably foreseeable ambient temperature conditions. The
connection equipment must also be designed so that the adverse effects of its failure on the IESOcontrolled grid are mitigated.
Telemetry
If applicable according to Section 7.3 of Chapter 4 of the Market Rules, the connection
applicant shall provide to the IESO the applicable telemetry data listed in Appendix 4.15 of the Market
Rules on a continual basis. The data shall be provided with equipment that meets the requirements set
forth in Appendix 2.2, Chapter 2 of the Market Rules, in accordance with the performance standards set
forth in Appendix 4.19, subject to Section 7.6A of Chapter 4 of the Market Rules. The whole telemetry
list will be finalized during the IESO Facility Registration/Market Entry process.
As part of the IESO Facility Registration/Market Entry process, the connection applicant must also
complete end to end testing of all necessary telemetry points with the IESO to ensure that standards are
met and that sign conventions are understood. All found anomalies must be corrected before IESO final
approval to connect any phase of the project is granted.
Revenue Metering
If revenue metering equipment is being installed as part of this project,
the connection applicant should be aware that revenue metering installations must comply with Chapter
6 of the IESO Market Rules. For more details the connection applicant is encouraged to seek advice
from their Metering Service Provider (MSP) or from the IESO metering group.
Facility Registration/Market Entry
The connection applicant must complete the IESO Facility
Registration/Market Entry process in a timely manner before IESO final approval for connection is
granted.
As part of the IESO Facility Registration/Market Entry process, the connection applicant must provide
evidence to the IESO confirming that the equipment installed meets the Market Rules requirements and
matches or exceeds the performance predicted in this assessment. This evidence shall be either type
tests done in a controlled environment or commissioning tests done on-site. In either case, the testing
must be done not only in accordance with widely recognized standards, but also to the satisfaction of
the IESO. Until this evidence is provided and found acceptable to the IESO, the Facility
Registration/Market Entry process will not be considered complete and the connection applicant must
accept any restrictions the IESO may impose upon this project’s participation in the IESO-administered
markets or connection to the IESO-controlled grid. The evidence must be supplied to the IESO within 30
days after completion of commissioning tests. Failure to provide evidence may result in disconnection
from the IESO-controlled grid.
If the submitted models and data differ materially from the ones used in this assessment, then further
analysis of the project will need to be done by the IESO.
Final Report
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Norman T1 Replacement and Substation Upgrade
1.
2013-EX670
Project Description
H2O Power LP is planning to replace the main output transformer T1 at Norman GS, add a new HV
breaker, and replace the HV disconnect switch. All associated line, transformer, and LV bus protections
will also be replaced as part of the project.
The expected in-service date for the new equipment is August 2014.
1.1
Transformer
The technical specifications of the existing and replacement transformer are given in Table 1.
All values for replacement equipment are specified at the time of order. Actual values to be provided prior to in-service dates.
Transformer
Existing T1
Replacement T1
Configuration
Three phase
Three phase
Transformation (kV)
121.5/6.6
125/6.6
Winding Configuration
Delta/Wye-Grounded via 6.4 Ω
resistor
10.8 MVA ONAN
14.4 MVA ONAF
18.0 MVA ONAF
18.0MVA
Delta/ Wye-Grounded via 6.4
Ω resistor
10.0 MVA ONAN
13.3 MVA ONAF
16.6 MVA ONAF
16.6 MVA
18.54 MVA (summer)
24.66 MVA (winter)
Not applicable
To be provided
Positive Sequence Impedance
R= not available
X=7.8%
@ 10.8 MVA
R= to be provided
X= 7.8%
@ 10.0 MVA
Off-load tap-changer
Tap 1:
Tap 2:
Tap 3:
Tap 4:
Tap 5:
Tap 6:
Tap 7:
Tap 1:
Tap 2:
Tap 3:
Tap 4:
Tap 5:
In service off-load tap position
Tap 3: 121.5 kV
Thermal Rating
Continuous Thermal Rating (summer
35°C)
10-DAY Thermal Rating (summer 35°C)
15-MIN Thermal Rating (summer 35°C)
114.8 kV
118.2 kV
121.5 kV
124.9 kV
128.3 kV
132.6 kV
135.0 kV
118.75 kV
121.875 kV
125.0 kV
128.125 kV
131.25 kV
Tap 3: 125.0 kV
Table 1: Comparison of Existing and New Transformer Parameters at Norman GS
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Norman T1 Replacement and Substation Upgrade
1.2
2013-EX670
Connection Equipment
The specifications of the new HV circuit breaker are given in Table 2.
The specifications of the existing and replacement 115 kV disconnect switch are compared in Table 3.
HV Breaker Specifications (A1L2)
Maximum Continuous Operating Voltage 145 kV
Continuous Current Rating
1200 A
Short Circuit Symmetrical Current Rating
40 kA
Interrupting Medium
SF6
50 msec
Rated Interrupting Time
Table 2: New HV Breaker Specifications at Norman GS
The specifications of the existing and replacement 115 kV disconnect switch are compared in Table 3.
HV Disconnect Switch Specifications (A1L2-L)
Existing
Maximum Continuous Rated Voltage 138 kV
Load Interrupting Current
600 A
Replacement
145 kV
1200 A
Table 3: Existing and New HV Disconnect Switch Specifications at Norman GS
Appendix 4.1 of the Market Rules states that under normal operating conditions, the voltages in the 115
kV system in northern Ontario are maintained within the range of 113 kV to 132 kV. Thus, the IESO
requires that the 115 kV equipment in northern Ontario must have a maximum continuous voltage rating
of at least 132 kV.
Protective relaying must be set to ensure that transmission equipment remains in-service for voltages up
to 5% above the maximum continuous value specified in Appendix 4.1 of the Market Rules, to allow the
power system to recover from transient disturbances.
1.3
Protections
Major new protection associated with the project includes


Transformer differential protection for T1
Line distance protection for 115 kV circuit K2M
All new protection will consist of redundant A and B protection relays with separate DC power supplies
in accordance with the NPCC requirements. The existing Remote Trip protection connecting Norman GS
with Kenora GS and Rabbit Lake TS will be retained.
The connection applicant shall ensure that the protection systems are designed to satisfy all the
requirements of the Transmission System Code and any additional requirements identified by the
transmitter. New protection systems must be coordinated with the existing protection systems.
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Norman T1 Replacement and Substation Upgrade
2.
Assessments
2.1
Reactive Power Capability
2013-EX670
The generation facility is directly connected to the IESO-controlled grid, and thus, the connection
applicant shall ensure that the facility has the capability to inject or withdraw reactive power
continuously (i.e. dynamically) at a connection point up to 33% of its rated active power at all levels of
active power output except where a lesser continually available capability is permitted by the IESO. If
necessary, shunt capacitors must be installed to offset the reactive power losses within the facility. If
generators do not have dynamic reactive power capabilities, dynamic reactive compensation devices
must be installed to make up the deficient reactive power.
The five generators at Norman GS provide a maximum generation of 13.2 MW. Table 4 presents the
ranges of reactive power output for G1 to G5 calculated at the HV bus at each transformer tap position.
The voltage on the Rabbit Lake bus was fixed at 124.433 kV which is the historical average voltage over
the past 2 years.
Norman GS Reactive Power Output
Qmin = -5.4 MVAR; Qmax = 8.0 MVAR
OLTC tap
Tap 1: 118.75 kV
Tap 2: 121.875 kV
Tap 3: 125.0 kV
(proposed I/S postion)
Tap 4: 128.125 kV
Tap 5: 131.25 kV
MVAR absorption at Norman bus
using 0.95 pu terminal voltage &
minimum generation of 0 MW
MVAR injection at Norman bus
using 1.05 pu terminal voltage &
maximum generation of 13.2 MW
(VRabbit Lake = 124.433 kV)
-5.7 MVAR
-5.7 MVAR
(VRabbit Lake = 124.433 kV)
0.9 MVAR
2.5 MVAR
-5.7 MVAR
5.6 MVAR
-2.7 MVAR
0.1 MVAR
6.1 MVAR
6.1 MVAR
Table 4: Reactive Power Outputs at the HV side of Norman GS
Table 4 indicates that the generation facility is capable of injecting and absorbing more than 33% of its
rated active power at all levels of active power output while on the proposed off load tap position #3,
thus meeting the reactive power capability requirements of the Market Rules. However, should the real
time operation require a different transformer tap position in the future, the IESO reserves the right to
request the off load tap position to be modified to a different value.
2.2
Transformer Thermal Assessment
At a power factor of 0.9, the maximum generator output is 14.44 MVA (13.2 MW, 6.3 MX) which is
within the continuous rating of the new transformer.
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Norman T1 Replacement and Substation Upgrade
2.3
2013-EX670
Short Circuit Assessment
The Transmission System Code requires the new equipment to be designed to withstand the fault levels
in the area where the equipment is installed. Thus, the connection applicant shall ensure that the new
equipment at the facility is designed to withstand the fault levels in the area. If any future system
changes result in an increased fault level higher than the equipment’s capability, the connection
applicant is required to replace the equipment with higher rated equipment capable of withstanding the
increased fault level, up to maximum fault level specified in the Transmission System Code. Appendix 2 of
the Transmission System Code establishes the maximum fault levels for the transmission system. For the
115 kV system, the maximum 3 phase and single line to ground symmetrical fault levels are 50 kA.
Appendix 2 of the Transmission System Code states that the maximum rated interrupting time for the
115 kV breakers must be ≤ 5 cycles. Thus, the connection applicant shall ensure that the installed
breakers meet the required interrupting time specified in the Transmission System Code. Fault
interrupting devices must be able to interrupt fault currents at the maximum continuous voltage of 132
kV.
The short circuit level of the Norman 115 kV bus is about 6.0 kA in the existing system, which is far
below the interrupting capability of the proposed circuit breaker. It is not expected that the T1
replacement has significant impact on the local short circuit level, thus, short circuit studies were not
conducted.
2.4
Protection System Assessment
Hydro One has confirmed that the line protection setting for K2M will not change.
- End of Document -
Final Report
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