Generation Planning & System Studies
Generation & Capacity Planning, Engineering and Construction
Toronto Hydro-Electric System Limited
500 Commissioners Street, 3rd Floor
Toronto, Ontario, M4M 3N7
Connection Impact Assessment
Solar Photovoltaic (PV) Generation – 500 kW
Dundee Industrial Solar Limited Partnership
700 Ormont Drive,
North York, Ontario, M9L 2W6
FIT Project # FIT-GPHRDTM
Finch, Bus J, Feeder 55-M31
July 24, 2014
Generation Planning & System Studies Department
Engineering and Investment Planning Division
Table of Contents
Connection Impact Assessment
1.
2.
3.
4.
5.
6.
7.
8.
Connection Impact Assessment Disclaimer ............................................. 2
Connection Impact Assessment Findings .............................................. 3
Requirements and Recommendations ................................................... 4
Warning Signs and Diagrams ................................................................. 5
Commissioning and Witnessing Requirements ...................................... 5
Metering Requirements .......................................................................... 6
Monitoring and Control Requirements .................................................... 7
Connection Impact Assessment Summary ............................................. 7
Appendices
1. FIT Connection Application Form
2. Impact Assessment Generator Form
3. Single Line Diagram
4. Equipment Brochures – Inverter and Communication Devices
Page |1
1. Connection Impact Assessment Disclaimer
This Connection Impact Assessment (“CIA”) report dated July 24, 2014, has been
prepared for the sole purpose of the impact of the proposed Distributed Generation
connection at 700 Ormont Drive, North York, M9L 2W6, under the Feed-in Tariff
program on the Toronto Hydro distribution system. The technical review addresses the
protection of Toronto Hydro's facilities. The Generator should satisfy itself any
requirement for the protection of its own equipment and facilities.
Modifications to the incoming supply arrangement, as necessary, need to comply with
the following specification in the Conditions of Service: “Toronto Hydro Requirements
for Design and Construction of Customer-Owned Substation High Voltage Substations”.
It is the Generator‟s responsibility to ensure that all requirements are met. Additional
requirements may be necessary to address unique situations, and the Generator facility
will be advised of any additional requirements at the appropriate final stage.
Toronto Hydro accepts no responsibility or liability for any of the information provided in
this report. Meeting these requirements does not necessarily constitute an acceptable
facility design. Toronto Hydro reserves the right to amend this report and will use its
best efforts to advise any such change. It is the responsibility of the applicant to ensure
that the latest version of this report is used.
Notes:
a) This report considers the issues related to the Toronto Hydro distribution system.
The Generator is responsible for designing, commissioning, operating and
maintaining the embedded generation facility in accordance with good utility
practice. The interface protection design and settings will be reviewed during the
implementation phase of the project, as required.
b) This CIA report was performed by Toronto Hydro using Toronto Hydro‟s
Conditions of Service and based on the system conditions at the time the CIA
was performed under the assumptions and key project connection data
contained in this CIA report.
c) Any future modifications to the Conditions of Service and/or the key project
connection data could affect the CIA results, and a new CIA may need to be
performed at the Generator‟s expense.
d) Any material revisions to the design, planned equipment or plans for the
embedded generation facility shall be filed with Toronto Hydro and a new CIA will
be prepared as per Distribution System Code (DSC) section 6.2.15.
e) This report is valid for a period of twelve months. If the Distributed Generation
has not received a Notice to Proceed (NTP) from the OPA within this timeframe,
a new Connection Impact Assessment will be required before connection will be
allowed to the Toronto Hydro Distribution System.
Page |2
2. Connection Impact Assessment Findings
This Connection Impact Assessment (CIA) studies the impact of the proposed 500
kW Solar Photo Voltaic – Inverter power distributed generation (DG) facility at 700
Ormont Drive, North York, M9L 2W6 on the Toronto Hydro Electric Services Limited
(THESL) distribution system. This CIA is in compliance with the requirements
outlined in the Distribution System Code (DSC) section 6.2.4 and the transmitter
(Hydro One) has been advised by copy of this document as per 6.2.14A of the DSC.
The attached check list on the proposed DG facility for FIT connection provides the
findings. Based on the findings, the following conclusions are reached:
The distributed generation project
a) shall be considered for connection and will not have a material adverse impact on the
Toronto Hydro distribution system, if the generator fulfills the requirements and
recommendations as listed below in section 3.
b) will export power generated at 700 Ormont Drive, North York, M9L 2W6 to the
electricity distribution grid via Finch TS feeder 55-M31
c) will not result in thermal overloading of existing distribution facilities.
d) will not increase the fault level significantly at the station switchgear that will be
connected to Finch TS feeder 55-M31
e) will be an acceptable capacity to connect within the allocated capacity of the feeder.
Page |3
3. Requirements and Recommendations
The Generator shall:
1.
Assume the connection cost of upgrading, if applicable, the size of service cables
and/or the utility transformer;
2.
Confirm that the disconnect switch available for THESL operation is accessible,
visible, lockable and contains a viewing window;
3.
Provide communication facilities for metering as necessary. Requirements for
metering are attached herewith;
4.
Provide monitoring and control of the DG facilities as necessary. Requirements for
monitoring and control are attached herewith;
5.
Perform a test on site that confirms that upon operating the main exterior
disconnect open, all inverters connected upstream on the project will automatically
shut down due to the anti-islanding feature of the inverter being enabled. Toronto
Hydro personnel must be present to witness this test
Customer is to provide test results to Toronto Hydro prior to full settlement of
account;
6.
Perform tests to confirm that individual, "N" quantity of inverters, and total
operation (i.e. one inverter on, two inverters on and all Quantity "N" inverters on at
a time) does not in any way compromise the stability or reliability of the connection
point. Parameters to be tested and reported on will include at a minimum:
a.
b.
c.
d.
e.
f.
Power Factor
Harmonics
Phase Rotation
Voltage Regulation
Synchronization
Over and Under Frequency Protection
All of the above requirements and recommendations must adhere to Toronto
Hydro‟s utility requirements for connection - Conditions of Service Reference #3:
Distributed Generation Requirements.
Page |4
4. Warning Signs and Diagrams
The following warning sign shall be posted on the point of disconnection, generator
feeder cell and switch room door to warn people of the presence of embedded
generation:
WARNING
TWO POWER SOURCE
PARALLEL SYSTEM
As well, a single line, permanent and legible diagram of the switching arrangement shall
be placed at the Customer‟s control room and the switch room to indicate the position
of the embedded generator and isolation point with their locking and interlocking
arrangements, if any available.
Operating designations will be assigned to the switching equipment of the generation
system as required by Toronto Hydro. The Customer shall update the single line
electrical diagram and operating diagram to include the assigned operating
designations, and the switching equipment shall be identified by the operating
designations as well.
5. Commissioning and Witnessing Requirements
a) The Customer shall apply for ESA electrical inspection and provide Toronto
Hydro with the Certificate of Inspection once requirements are satisfied.
Following this, Toronto Hydro will also receive a copy of the Authorization to
Connect from ESA.
b) As per Section 4.7.4 of „Toronto Hydro – Distributed Generation Requirements‟,
Toronto Hydro has the right to witness the commissioning and testing of the
connection of generation facilities greater than 10kW to its distribution system.
The Customer shall notify Toronto Hydro no later than fifteen working days prior
to scheduled commissioning tests to enable Toronto Hydro to witness the
commissioning tests.
c) A commissioning verification report certified by a Professional Engineer shall be
provided to Toronto Hydro for all projects greater than 10kW. The commissioning
report shall be submitted for approval before the operation of the distribution
generation facility
Page |5
6. Metering Requirements
Toronto Hydro Electric System Limited (THESL) requires telephone line communication
capability with all DG‟s which are connected to its grid.
Communication requirements for metering:
1. Installation of ½ EMT conduit between the revenue metering cabinet and the
Telecom room with a 2 pair/4 conductor telephone cable and a RJ11 (4 pin)
telephone jack. The telephone jack is to be left at the bottom of the meter cabinet
with enough telephone cable to allow mounting the jack anywhere in the cabinet. The
telephone cable terminating in the telecom room is to be clearly labeled TORONTO
HYDRO METERING.
2. Toronto Hydro will arrange to have the telephone line activated. Customer owned
telephone lines or customer shared telephone lines are not acceptable.
3. Installation of a 120V duplex receptacle at the bottom right corner of the meter
cabinet. The receptacle is to be connected to an uninterruptible power supply (UPS),
if possible.
4. THESL shall be provided with the name and phone number of an on-site contact
person.
Page |6
7. Monitoring and Control Requirements
At this current time, all Distributed Generation (DG) facilities ≥ 50kW will be required to
have Monitoring and Control installed and operational prior to connection to the grid.
7.1 Control Requirements
All generators connected to Toronto Hydro‟s distribution system are required to provision for
real time control to Toronto Hydro. Provision will include, but is not limited to, the following:
1. The ability to remotely dispatch the generator (on/off)
Option A: Trip Command is sent from RTU to the inverter(s) communication board
Option B: Dry Contact is sent from RTU to inverter(s) auxiliary contact
Option C: Dry Contact is sent from RTU to a separate disconnecting means (ie.
contactor, circuit breaker, contactor switch, etc.)
Available Option
No. of Inverters
A
B
C
1
2
≥ 3†
† Daisy chaining of inverters is not allowed
7.2 Monitoring Requirements
7.2.1 Monitoring
All generators connected to Toronto Hydro‟s distribution system are required to provision for
real time monitoring to Toronto Hydro. Provision will include, but is not limited to, the following:
1. Analogue Quantities which include the following:
a) Apparent Power (KVA) output and Power Factor and direction for each unit or
total for the DG Facility;
b) Frequency (Hz);
c) Phase to phase voltage (V); and
d) Three phase currents (A).
2. Device Statuses:
a) Status of consolidated DG units; and
3. Unsolicited response will be sent to Toronto Hydro when:
a) Voltage or frequency has reached +/-6% of nominal value
b) Current or apparent power has reached 105% of max generation or -1% of max
generation
c) Power factor of the DG Facility has fallen below 0.9 or over 1.1
d) Status of DG facility has changed
Page |7
7.2.2 Telemetry Requirements
The telemetry Reporting Rates shall be:
Function
Performance
Data measurements
Equipment status change
Scan period for data
measurements
Scan period for equipment
status
Less than 10 seconds from
change in field monitored quantity
Less than 10 seconds from field
status change
Minimum 4s
Minimum 4s
7.2.3 Options
Depending on the number of inverters at the DG site, there are two options to satisfy the
monitoring requirements:
Option A: Monitoring quantities are obtained directly from the inverter(s).
Option B: Monitoring quantities are obtained from a Power Quality (PQ) meterΨ.
Ψ The PQ meter will, at a minimum, meet the following specifications:
Accuracy:
o PQ meter accuracy must be ANSI C12.20 Class 0.2
o CT and PT accuracy must be Class 1.0 (1% accuracy)
Power Quality:
o IEC 61000-4-30 power quality accuracy for voltage, current, power
Harmonic Metering:
o Individual voltage and current up to 15th order
o THD
Display: LCD display showing all parameters.
Available Option
No. of Inverters
A
1
2
≥ 3†
† Daisy chaining of inverters is not allowed
Page |8
B
7.3 Real Time Control and Monitoring
7.3.1 Reliability
1. The delivery of real-time data at the communication demarcation point shall have a:
a) MTBF (Mean Time between Failure) of four (4) years; and
b) MTTR (Mean Time to Repair) of seven (7) days.
2. The DG Owner may be required to disconnect the DG Facility until problems are
corrected if the failure rates or repair time performance in item 1) above fails to achieve
their targets by the following significant amounts:
a) less than 2 years MTBF; or
b) MTTR greater than 7 days.
3. If the DG Facility is involved in a Special Protection System (SPS) or automated
dispatch, the Telecommunication Mean Time to Repair (MTTR) requirement shall be 24
hours.
4. Upon loss of telecommunications, the DG Owner is required to immediately report the
failure cause and estimated repair time to Toronto Hydro.
5. Mean Time to Repair time shall start from the time when the communications was lost
and not from when it was discovered.
6. The DG Owner shall coordinate any planned interruption to the delivery of real time data
with Toronto Hydro.
7.3.2 Communication Point
1. Toronto Hydro will connect with only one point for communication per Toronto Hydro
supply point.
2. The communication and control point shall be located at the same location in close
proximity to the revenue metering for the DG.
3. Customer will interface to Toronto Hydro radio modem with a straight-through DB9 male
to male cable
4. Customer shall provide surge protection for the RTU and other miscellaneous
equipment.
7.3.3 Medium and Protocol
1. The DG Owner shall provide real-time operating information to Toronto Hydro as
specified in Section 7.2 directly from the station(s) as described below in item (2).
2. Real time operating information provided to Toronto Hydro may be from a RTU device at
the DG Facility‟s station to Toronto Hydro‟s control centre using Distributed Network
Protocol (DNP 3.0 protocol).
3. Further provision to accommodate IEC 61850 is also required.
4. Toronto Hydro will connect to the generation facility via SD9 transit radio. Generation
facility must also be equipped with fibre Ethernet port (single mode, LC connector), in
the event of a medium change.
Page |9
7.3.4 RTU Specifications
1. RTU must be equipped with a fibre Ethernet port (single mode, LC connector).
2. Enclosure containing RTU will be pad locked by THESL in order to prevent non-THESL
access upon successful commissioning of system.
3. TCP/IP connections to the RTU will not be permitted.
4. Only one (1) Serial DB9-232 or DB9-485 connection to the RTU is allowed for customer
use. Access will be Read-Only over Modbus protocol. No other connections to the
RTU will be permitted for the customer.
5. Unused ports on RTU must be disabled.
7.3.5 Uninterruptible Power Supply (UPS) Requirements
An Uninterruptible Power Supply (UPS) is required to power the RTU Gateway device during a
utility outage. UPS must be supplied by a 120V circuit outlet that is GFCI protected.
7.3.5.1 UPS Specifications
The UPS shall:
a. have adequate capacity to ensure that all protection functions operate when the main
source of power fails.
b. remain operational for a minimum of 10 minutes (600s) after the main source of power
fails, in order for the protection functions to operate properly and disconnect the DG from
Toronto Hydro‟s distribution system.
c. be capable of sustaining continuous telemetry about the DG connection status.
d. be equipped with two (2) outlets for Toronto Hydro use.
7.4 Implementation
7.4.1 DG Monitoring and Control Procedure
1. Generator reviews Monitoring and Control Requirements.
2. Generator proposes Monitoring and Control design in Connection Impact
Assessment (CIA) application.
3. Toronto Hydro reviews proposed design and CIA application.
4. Toronto Hydro completes CIA and approves Monitoring and Control design.
5. Toronto Hydro provides necessary information in CIA for Generator to complete
programming and installation of Monitoring and Control design.
6. Generator purchases, installs and configures equipment according to Toronto Hydro
CIA specifications.
7. Generator provides „Monitoring and Control Submission Form‟ to Toronto Hydro.
8. Generator commissions Monitoring and Control design. Toronto Hydro
representative present to witness commissioning.
9. Upon verification of Step 8, the Generator will be permitted to connect to the Toronto
Hydro electrical distribution grid and SCADA system.
P a g e | 10
7.5 3rd Party SCADA RTU Gateway Configuration
7.5.1 Setup
1. The 3rd Party SCADA RTU Gateway shall act as a Serial DNP Server
2. The 3rd Party SCADA RTU Gateway shall be configured as follows
Server DNP Address**
11465
Client DNP Address**
Serial Communications Port Type
4
EIA232
9600
Baud Rate
Data Bits
8
Parity Bit
None
Stop Bit
1
Full Duplex
FALSE
Allow Unsolicited Messages
TRUE
Unsolicited Messaging Retries
3
UTC Offset
0
FALSE
DST Enabled
**Values are subject to change. Confirm with THESL prior to programming of RTU
7.5.2 SCADA Mapping
1. The SCADA points shall be, but is not limited to, mapped as follows
Monitoring (Analog Input)
Monitoring (Digital Input)
From RTU
Definition
From RTU
Definition
0
Voltage AB
0
On/Off Status
1
Voltage BC
2
Voltage CA
3
Current Ia
From SCADA
Definition
4
Current Ib
0
On/Off Command
5
6
Current Ic
Apparent Power
7
Power Factor
8
Frequency
P a g e | 11
Control (Digital Output)
2. The configuration of these SCADA points shall be, but is not limited to, as follows:
Zero
Deadband
Max Value
Min Value
18
10
636
564
1
18
10
636
564
V
1
18
10
636
564
Current Ia
A
1
25
5
505
-5
Current Ib
A
1
25
5
505
-5
Current Ic
Apparent
Power
Power Factor
A
1
25
5
505
-5
KVA
1
25
5
500
-5
0.01
5
110
-110
Frequency
Hz
1
1.8
63.6
56.4
Definition
Unit
Scale Deadband
Voltage AB
V
1
Voltage BC
V
Voltage CA
10
3. Alternatives may be considered upon submission of proposals.
4. The Digital Output to control the RTU shall be
i. latch off to disconnect and;
ii. latch on to connect.
5. The Digital Input On/Off status of the DG from the RTU shall be
i. 0 or FALSE for Off Status;
ii. 1 or TRUE for On Status.
P a g e | 12
8. Connection Impact Assessment Summary
Distributed Generation (DG) of Solar PV only
1
1.1
1.2
1.3
2
Project Information
FIT Project No
FIT Contract ID No.
Project address
FIT-GPHRDTM
F-003676-SPV-211-508
700 Ormont Drive, North York, Ontario, M9L 2W6
Connection Details
Transmission Station Level
2.1
2.2
2.3
Transformer Station
Bus ID
Feeder number
2.4
2.5
Municipal Station
Municipal Feeder number
Finch
J
55-M31
Municipal Station Level
2.6
2.7
2.8
2.9
3
3.1
3.2
3.3
3.4
3.5
4
4.1
4.2
4.3
4.4
4.5
4.6
4.7
4.8
5
5.1
5.2
Distribution Level
Distribution System (Network/Radial)
Service Type (OH, UG, OH to UG)
Connection Type (Primary/Secondary)
a) Transformer Capacity (kVA)
b) Primary Voltage (kV)
c) Secondary Voltage (V)
Transformer
d) Transformer Configuration
e) Transformer Location. No:
f)
Transformer Ownership
RADIAL
UG
SECONDARY
1-2000
27.6/16kV
600/347V
1-3 Phase Delta Wye
CO-ST584
CUSTOMER
Distribution System Availability Test
Threshold CIA by HONI (HONI Project ID)
Threshold CIA End Date (dd/mm/yyyy)
DG capacity to be connected under this project (kW)
Available Thermal Capacity for DG connection on the Bus (MW)
Available Short Circuit Capacity for DG connection on the Bus (MVA)
17470
N/A
500
Yes
Yes
Inverter and Communication Details
Nameplate Capacity
500
kW
Number of Inverters
1
Inverter Voltage
480
V
Phase (1 PH or 3 PH)
3
Minimum Power Factor
0.9
PV Inverter Manufacturer/Catalog #
Advanced Energy / AE500TX
PV Inverter Certification (circle or highlight all applicable)
IEEE 1547 / UL1741/ CSA 107.0-01
Communications and control interface (RS485 / Modbus, RS232, Ethernet)
All
DNP 3.0 enabled and optical port interface
Yes
3rd Party SCADA System: RTU Gateway
SEL - RTAC3530
Monitoring and Control Voltage
600
V
Intermediate (Step-Up) Transformer
Yes
Single Line Diagram Details
SLD Drawing No.
SLD Date (dd/mm/yyyy)
P a g e | 13
E-2
Rev
02/06/2014
2
Appendices
1 FIT Connection Application Form
2 Impact Assessment Generator Form
3 Single Line Diagram
4 Equipment Brochures – Inverter and Communication Devices
P a g e | 14
LOCATION OF INVERTER PAD
A
SITE PLAN
N.T.S.
PROPOSED PV SYSTEM LOCATION
500KW AC
1815 SILANTIS 330W MODULES(599KW DC)
LOCATION OF EXISTING AND FUTURE
ELECTRICAL EQUIPMENT AND METERING
PAD MOUNTED SUPPLY TRANSFORMER
LOCATION (PCC)
24x36 TITLE BLOCK
126 Mississaga Street East
Orillia, Ontario, L3V 1V7
Phone: (705) 325-5400
Fax: (705) 325-8400
1
No.
yyyy.mm.dd
2014-02-05
Remarks
ISSUED FOR CIA
Revisions
Initials
A.R.
Seal:
KEY PLAN
Issued:
B
NOTE: THESE DRAWINGS MUST BE CHECKED BY THE CUSTOMER OR CONTRACTOR. ANY ERRORS OR OMISSIONS MUST BE REPORTED IN WRITING TO STEENHOF BUILDING SERVICES GROUP, PRIOR TO COMMENCEMENT OF CONSTRUCTION.
Aprvd by:
Drawn by:
C.L.
A.R.
Design by:
Scale:
A.R.
NTS
Site Plan
Date:
700 Ormont Drive, Etobicoke, ON, M9L 1M2
Drawing Title:
2013-12-10
500KW Solar Photovoltaic
(PV) System Installation
Project:
PROJECT SITE LOCATION
N.T.S.
REV.
Drawing No.
File:
Modbus DIP switches
Ethernet Port
24V Power supply terminals
Remote disable terminal block
Termination DIP switches
24x36 TITLE BLOCK
126 Mississaga Street East
Orillia, Ontario, L3V 1V7
Phone: (705) 325-5400
Fax: (705) 325-8400
2014-02-05
2014-06-20
2014-07-24
ISSUED FOR CIA
REVISED RTAC CONNECTION TO MODBUS RS485
REVISED FOR CIA
2
3
A.R.
R.C.
A.R.
Initials
NOTE: CAPABLE OF FIBER CONNECTION OR
ETHERNET. DNP3 & IEC61850 PROTOCOL.
(SINGLE MODE FIBRE LC CONNECTOR)
yyyy.mm.dd
INTERGRATED DATA
ACQUISITION
Remarks
RS-485 CONNECTION
(MODBUS)
1
AC
No.
DC
A.R.
R.W.
Drawn by:
Aprvd by:
Design by:
Scale:
A.R.
NTS
Date:
2013-12-10
MONITORING AND CONTROL
700 Ormont Drive, Etobicoke, ON, M9L 1M2
Drawing Title:
500KW Solar Photovoltaic
(PV) System Installation
REALTIME CONTROLLER(SEL-3505)
REV.
Drawing No.
ADVANCED ENERGY
AE 500TX INVERTER
Revisions
SECURE DNP3
PROTOCAL
Project:
SCADA OPERATIONS
NETWORK
Seal:
TORONTO HYDRO
SCADA DEPARTMENT
THESL SD9
RADIO UNIT
Issued:
TORONTO HYDRO
NOTE: THESE DRAWINGS MUST BE CHECKED BY THE CUSTOMER OR CONTRACTOR. ANY ERRORS OR OMISSIONS MUST BE REPORTED IN WRITING TO STEENHOF BUILDING SERVICES GROUP, PRIOR TO COMMENCEMENT OF CONSTRUCTION.
File:
700 ORMONT DR
JULY 24 2014
804-14
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• Ideal for Solar Power or other applications where transformer loading
varies widely and electricity rates are high
ULLTRA-H1E™ – Harmonic Mitigating Transformer
In applications where non-linear loading is expected to be severe, the
ULLTRA-H1E combines the proven harmonic mitigating properties of Mirus’
Harmony™ HMT line with superior energy efficiency, low inrush and low
audible noise found in the ULLTRA design.
• Voltage distortion (flat-topping) is minimized by cancelling zero
sequence fluxes within the secondary windings and eliminating
circulating currents in the primary windings
• Treats triplen harmonics (3rd and 9th) within the transformer and 5th and
7th upstream
• The highest efficiency harmonic mitigating transformer from the company
that first introduced HMT’s to the market in the early 1990’s
75kVA Transformer
Comparison under
Linear Load
ULLTRAtm Series
Efficiency
Sizes
Primary
Style
Weight 
lbs [kg]
15
30
45
75
112.5
150
225
300
500
750
MT2
MT2
MT3
MT3
MT4
MT4
LT1
LT2
LT3
LT3
250 [115]
375 [170]
500 [227]
850 [386]
1000 [454]
1200 [544]
1800 [820]
2500 [1135]
3175 [1440]
4250 [1928]
kVA Case
 Approximate Values
Linear
35% Load*
50% Load
97.90%
98.25%
98.39%
98.60%
98.74%
98.81%
98.95%
99.00%
99.09%
99.16%
97.96%
98.35%
98.45%
98.65%
98.82%
98.85%
99.00%
99.07%
99.20%
99.28%
* NEMA Premium & CSL3 specs
Impedance
K-13
Non-Linear No-Load
50% Load** Losses (W)
97.0%
97.5%
97.7%
98.0%
98.2%
98.3%
98.5%
98.6%
98.7%
98.8%
75
115
150
225
320
400
560
710
1100
1550
ULLTRA H1E
Zero Sequence
Zo
Xo
3 Phase
Short Circuit
<0.95%
<0.95%
<0.95%
<0.95%
<0.95%
<0.95%
<1.0%
<1.0%
<1.5%
<2.0%
<0.3%
<0.3%
<0.3%
<0.3%
<0.3%
<0.3%
<0.5%
<0.5%
<0.5%
<1.0%
2.0-3.5%
2.0-3.5%
2.0-3.5%
2.0-3.5%
2.5-5.0%
2.5-5.0%
3.0-6.0%
3.0-6.0%
4.5-7.0%
5.0-8.0%
** Equivalent to NEMA TP-1
'MT' Style Enclosure
'LT' Style Enclosure
W
W
D
D
General Specifications:
Primary
3-Phase, 3 wire, 60Hz
Secondary
3-Phase, 4-wire, 60Hz
Operating Temp. Rise
115oC
Insulation Class
220oC
Primary Taps
15kVA (and all 208V):
+ 1 x 5%
30kVA - 300kVA: +2 x 2.5%, - 4 x 2.5%
500kVA - 750kVA: + 2 x 2.5%
K-Factor Rating (at 150oC rise)
13
Neutral Bus Ampacity
200% of phase current
Energy Efficiency (
H
H
Mtg.
W
Mtg.
D
Mtg.
W
Front View
Side View
Front View
Mtg.
D
Side View
†
see table )
Linear Load: Meets and/or exceeds
the US Department of Energy
Candidate Standard Level 3 (CSL-3)
efficiency requirements by ensuring
losses are 30% lower than NEMA TP-1.
Non-Linear Load: Exceeds NEMA
TP-1 efficiency requirements.
Magnetizing Inrush
< 8 times FL RMS
Winding Material
Copper
Dimensions
Case
Style
MT1
MT2
MT3
MT4
LT1
LT2
LT3
H (Height)
inches [mm]
29.00 [737]
38.00 [965]
45.00 [1143]
51.50 [1308]
59.00 [1499]
66.00 [1677]
75.00 [1905]
W (Width)
inches [mm]
16.75 [425]
21.50 [546]
26.00 [661]
32.00 [813]
39.50 [1003]
44.00 [1118]
48.50 [1232]
Mtg. Center W Mtg. Center D
D (Depth)
inches [mm]
inches [mm] inches [mm]
13.75 [349]
13.00 [330]
15.00 [381]
17.00 [432]
17.50 [445]
19.50 [495]
21.50 [546]
19.00 [483]
21.00 [534]
23.50 [597]
23.50 [597]
25.50 [648]
24.00 [610]
32.00 [813]
30.00 [762]
26.00 [660]
36.00 [915]
34.00 [864]
27.50 [699]
41.00 [1041]
39.00 [991]
Insulating Varnish Impregnation
Polyester Resin
Audible Sound Level
3dB to 5dB below NEMA ST-20
Enclosure
Type: Nema-3R, ventilated
Paint: Polyester powder coated
Colour: ANSI 61 Grey
Electrostatic Shield
Single, [double]
Product Code:
Transformer Type Secondary
Ultra Low Loss
L-L Voltage
Transformer
208, 480, 600
Applicable Standards
Electrostatic Shield
S = Single shield (Std. for ULL)
SS = Double shield
Options
ULL - dd - hhh - xxx - kVA - S - TRx - t - (o)
Angular
Primary
Primary kVA
Temperature
Displacement L-L Voltage
15, 30, 45, 75, Rise
30 (Std. for ULL)
208, 480, 600 112.5, 150, 225, TRB* = 115oC (Std.)
[ * Leave blank for TRB]
00 (Std. for Type H1E)
300, 500, 750
Type
H1E = Harmonic
Mitigating
[Leave blank for Std. ULL]
NEMA Premium, NEMA ST20,
NEMA TP1, NEMA TP2, CSA C9,
CAN/CSA-C802.2, DOE CSL-3
Options:
Over-Temp. Sensors
[170oC], [200oC]
Solid Bottom Plate
Available for 'MT' case only
C
Mirus International Inc. All specifications subject to change without notice.
MIRUS International Inc.
31 Sun Pac Blvd., Brampton, ON, Canada L6S 5P6
Tel: 905.494.1120 Fax: 905.494.1140
Toll Free: 1-888 TO MIRUS (888.866.4787)
www.mirusinternational.com
R
ULL-PS01-A7
Effective: August 2012
MIRUS International Inc.
31 Sun Pac Blvd., Brampton, Ontario, Canada L6S 5P6
ULLTRA™ _
TECHNICAL DATA
ULTRA LOW LOSS TRANSFORMER (30% LESS LOSSES THAN NEMA TP1)
‘MT1’, ‘MT2’ ENCLOSURE DIM. - inches [mm]
GENERAL SPECIFICATIONS:
PRIMARY
3-phase, 3-wire, 60Hz
SECONDARY
3-phase, 4-wire, 60Hz
OPERATING TEMPERATURE RISE
115°C
INSULATION CLASS
220°C
PRIMARY TAPS
15kVA (and all 208V):
± 1 x 5%
30kVA - 300kVA: + 2 x 2.5%, - 4 x 2.5%
500kVA - 750 kVA:
± 2 x 2.5%
K-FACTOR RATING (at 150°C rise)
13
NEUTRAL BUS AMPACITY
DIMENSIONS - inches [mm]
B
C
D
CASE STYLE
A
MT1
MT2
29.00 [737]
38.00 [965]
200% of phase current
ENERGY EFFICIENCY (see table below)
Linear Load:
Meets and/or exceeds CSL-3
efficiency requirements by ensuring
losses are 30% lower than Nema TP1
Non-Linear Load:
Exceeds Nema TP1 requirements
16.75 [425]
21.50 [546]
15.00 [381]
19.50 [495]
19.00 [483]
23.50 [597]
E
F
13.75 [349]
17.00 [432]
13.00 [330]
17.50 [445]
‘MT3’, ‘MT4’, ‘LT’ ENCLOSURE DIM. - inches [mm]
MAGNETISING INRUSH
< 10 times FL RMS
WINDING MATERIAL
Copper
INSULATING VARNISH IMPREGNATION
Polyester Resin
AUDIBLE SOUND LEVEL
As per NEMA ST-20
15 - 45kVA:
75 – 150kVA:
225 – 300kVA:
500kVA:
750kVA:
ENCLOSURE
Type:
Paint:
Colour:
45dB
50dB
55dB
60dB
64dB
CASE STYLE
MT3
MT4
LT1
LT2
LT3
NEMA-3R, ventilated
Polyester powder coated
ANSI 61 Grey
ELECTROSTATIC SHIELD
Single, [double]
A
45.00 [1143]
51.50 [1308]
59.00 [1499]
66.00 [1677]
75.00 [1905]
DIMENSIONS - inches [mm]
B
C
D
26.00 [661] 21.00 [534]
25.00 [635]
32.00 [813] 25.50 [648]
29.50 [749]
39.50 [1003] 30.00 [762]
34.00 [864]
44.00 [1118] 34.00 [864]
38.00 [965]
48.50 [1232] 39.00 [991] 43.00 [1092]
E
F
21.50 [546] 19.00 [483]
23.50 [597] 23.50 [597]
24.00 [610] 32.00 [813]
26.00 [660] 36.00 [915]
27.50 [699] 41.00 [1041]
APPLICABLE STANDARDS
NEMA ST20, NEMA TP1, NEMA TP2
CSA C9, CAN/CSA-C802.2, DOE CSL-3
OPTIONS:
OVER-TEMPERATURE SENSORS
[170°C], [200°C]
SOLID BOTTOM PLATE (Case ‘MT’ only)
[yes], [no]
Sizes
Linear
kVA Case
Primary Style
15
30
45
75
112.5
150
225
300
500
750
MT2
MT2
MT3
MT3
MT4
MT4
LT1
LT2
LT3
LT3
Weight
lb [kg][1]
250 [115]
375 [170]
500 [227]
850 [386]
1000 [454]
1200 [544]
1800 [820]
2500 [1135]
3175 [1440]
4250 [1928]
Efficiency
K-13
35%
Load[2]
50%
Load
97.90%
98.25%
98.39%
98.60%
98.74%
98.81%
98.95%
99.00%
99.09%
99.16%
97.96%
98.35%
98.45%
98.65%
98.82%
98.85%
99.00%
99.07%
99.20%
99.28%
Impedance
ULLTRA H1E
Non-Linear No-Load Zero Sequence
@50%
Losses
Zo
Xo
Load[3]
Watts
97.0%
75
<0.95% <0.3%
97.5%
115
<0.95% <0.3%
97.7%
150
<0.95% <0.3%
98.0%
225
<0.95% <0.3%
98.2%
320
<0.95% <0.3%
98.3%
400
<0.95% <0.3%
98.5%
560
<1.0% <0.5%
98.6%
710
<1.0% <0.5%
98.7%
1100
<1.5% <0.5%
98.8%
1550
<2.0% <1.0%
3-Phase
Short
Circuit
Terminal Sizes
Primary
208V
480V
Secondary
600V
120/208V
2.0 - 3.5%
#2-#14
#6-#14
#6-#14
#6-#14
2.0 - 3.5%
2/0-#6
#2-#14
#2-#14
2/0-#6
2.0 - 3.5% 250MCM-#6
#2-#14
#2-#14
250MCM-#6
2.0 - 3.5% 600MCM-#4
2/0-#6
2/0-#6
600MCM-#4
2.5 – 5.0% 2x350MCM-#6 250MCM-#6
2/0-#6
2x350MCM-#6
2.5 – 5.0% 2x350MCM-#6 350MCM-#6 250MCM-#6 2x350MCM-#6
3.0 – 6.0% Copper Pad Copper Pad Copper Pad Copper Pad
3.0 – 6.0% Copper Pad Copper Pad Copper Pad Copper Pad
4.5 – 7.0% Copper Pad Copper Pad Copper Pad Copper Pad
5.0 – 8.0% Copper Pad Copper Pad Copper Pad Copper Pad
Neutral
2x#2-#14
2x2/0-#6
2x250MCM-#6
2x600MCM-#4
4x350MCM-#6
4x350MCM-#6
Copper Pad
Copper Pad
Copper Pad
Copper Pad
1. Approximate values.
2. NEMA Premium & CSL3 specifications.
3. Equivalent to NEMA TP-1.
4. Specifications are subject to change without notice.
5. For additional information refer to: Typical Specifications, Technical Guide, Internal Layout and Connection Diagrams.
 Mirus International Inc. [2012-08-13]
1-888-TO MIRUS
www.mirusinternational.com
ULL-S001-A16
AE 500TX
(Formerly known as PVP500kW)
The complete inverter solution
for large commercial and
utility-scale projects
Leading the industry in reliability, performance, and innovation,
AE Solar Energy introduces the AE 500TX for large commercial
and utility-scale projects. New options include an integrated DC
circuit breaker subcombiner that enables low cost compliance
with NEC 2011 and improves serviceability. Subcombiner
monitoring, a revenue grade meter, and a performance monitoring
gateway can be factory installed for a completely integrated
solution. Communication interfaces, remote disable inputs, and
The AE 500TX is backed with an industry-leading, 10-year,
optional 24 V auxiliary power supply are housed in a dedicated
nationwide warranty and a comprehensive optional 20-year
low power compartment for safe and easy access. The entire
warranty; plus the most responsive service and support team in
system, including the isolation transformer, is contained within a
the business.
single NEMA 4 rated cabinet significantly reducing installation time
and expense.
Designed for DC loading up to 175%, the AE 500TX maximizes
energy harvest and accelerates payback with a 97% weighted CEC
efficiency, wide DC operating range, fast convergence MPPT, and
the ability to produce full power all the way to 55 °C. Uptime
and revenue generation are assured by superior built-in reliability
consisting of engineered busbar power connections, redundant
cooling system and power supply, card cage circuit board design,
and solder-free intelligent power modules.
Superior Reliability
• Redundant power supply and cooling system with
Smart Air Management
• Increased availability with >99% monitored fleet availability
• Rated for full power operation up to 55 °C
• Low parts count reduces potential failure points
• Engineered busbar power connections
• Card cage circuit board system minimizes electronic
interconnections
™
Exceptional Installability
Total integration, reliability, and utility-support functionality
•
•
•
•
•
make the AE 500TX the complete inverter solution for large
Easy to Maintain
commercial and utility-scale projects.
•
•
•
•
Advanced power controls provide essential utility support
functions including power factor and curtailment with controlled
ramp rate making it easy to comply with interconnection
requirements.
AE Solar Energy products built in the U.S. are fully compliant with the Buy
American Act and qualify for projects funded by the federal stimulus package.
No external transformer to connect in the field
Optional DC circuit breaker subcombiner
DC loading up to 175%
Bottom and side entry with bottom side chases, generous
bending area and oversized busbar landings
Exterior mounting flanges for fast and easy anchoring with
no pre-drilling
All maintenance and service via front and side access
Fast change circuit board system shortens service time
Optional load-break rated AC service disconnect
Dedicated performance monitoring section separate from AC
and DC modules
AE 500TX Summary Specifications
Physical
Weight
Construction
Environmental Rating
Mounting
Isolation Transformer
Integrated AC/DC Disconnect
AC and DC Surge Protection
Electrical
DC Inputs
Array Configuration
Maximum Operating Input Current
Maximum DC Input Voltage (VOC)
MPPT Voltage Range
Open-Circuit Turn-On Voltage
AC Outputs
Continuous Output Power (kW)
Nominal Voltage
Operating Voltage Range
Electrical Service Compatibility
Maximum Continuous Current
Short Circuit Fault Current
Nominal Frequency
Frequency Range
Total Harmonic Distortion
Efficiency
Efficiency: Peak / CEC
Standby Losses
Inverter Controls and Monitoring
Power Factor
Power Curtailment
Communication Interfaces and
Protocols
Environmental
Operating Ambient Temp. Range
Standby/Storage Ambient Temp. Range
Cooling
Relative Humidity
Elevation
Regulatory
Agency Approvals / Regulatory
Compliance
Inverter Warranty
8750 lbs
Powder Coated Steel
NEMA 4
Pad Mount
Integrated
Included
Included
Advanced Power
Controls
• Power Factor
• Curtailment
• Controlled ramp rate
• Remote enable/disable
Options
Positive or negative ground
1600 A
600 V
310-595 V
330 V
•
500 kW
480 Y
-12% / +10%
3 phase, 4 wire, grounded Wye
480: 608
480: 891 Arms @ 480 VAC, 60.3 ms
60 Hz
59.3 - 60.5 Hz, adjustable to 57.0 Hz
< 3% THD
• Integrated AC Disconnect
480: 97.8% / 97.0%
< 80 W
> 0.99, Adjustable to 0.9 leading or lagging
5 - 100%, 1% increments
RS-485, Ethernet, Modbus, TCP/IP
-30 °C to 55 °C
-40 °C to 60 °C
Forced Convection
0 to 95%, non-condensing
6000 ft
NRTL certified to UL 1741-2010 by CSA International
IEEE 519, 929, 1547/1547.1 NEC Article 690 (compatible)
10 Year
Subject to change without notice. Refer to user manual for detailed specification.
DC Subcombiner circuit
breakers: 8 - 20 inputs,
80 A - 400 A trips
(max. total of 3500 A)
• Subcombiner monitoring
(up to 16 inputs)
• Integrated data monitoring
• Integrated revenue grade meter
• Positive ground
• 24 V auxiliary power supply
• Preventative maintenance
program
• 20-year extended warranty
Performance
Monitoring
Increase uptime and reduce
maintenance costs with integrated
performance monitoring hardware
that enables connectivity to a variety
of software solutions from industry
leading monitoring partners. The tight
integration between Advanced Energy
and our monitoring partners creates a
superior service and support experience
while seamlessly delivering meaningful
data. Factory integration and testing
of our UL listed monitoring solution
ensures high reliability and significantly
reduces field installation costs.
Advanced Energy Industries, Inc. • 20720 Brinson Blvd • Bend, OR 97701 U.S.A.
AE Solar Energy: www.advanced-energy.com/solarenergy
877.312.3832 • sales.support@ aei.com • invertersupport@ aei.com
Please see www.advanced-energy.com for worldwide contact information.
Advanced Energy is a registered U.S. trademark of Advanced Energy Industries, Inc.
© Advanced Energy Industries, Inc. 2012
All rights reserved. Printed in U.S.A.
ENG-AE500TX-250-07 8/12
Real-Time Automation Controller (RTAC)
Available in a 1U half-rack, 1U full-rack, or 3U full-rack chassis, the SEL-3530 and SEL-3530-4
Real-Time Automation Controllers (RTACs) are powerful automation platforms, designed and
tested to provide years of service in tough substation and plant environments. The RTAC
combines an embedded microprocessor-based hardware platform, wide operating temperature
range, real-time operating system, and secure communications with flexible, feature-rich IEC
61131-compliant programmability. The RTAC can provide any degree of functionality from that
of a simple intelligent port switch to the sophisticated communication and data handling required
for advanced substation integration projects.The RTAC features secure communications,
advanced data concentration, high-speed logic processing, flexible engineering access, and
protocol conversion capabilities between multiple built-in client/server protocols. The RTAC
also gives integrators the necessary tools to easily integrate and concentrate information from the
wide variety of microprocessor-based devices found in today’s substations. The RTAC is
bundled with intuitive configuration software to quickly configure large automated systems. The
optional web-based HMI completes the RTAC as the perfect automation solution.The RTAC is
the only automation platform that combines an IEC 61131 logic engine and industry standard
communications with SEL Mirrored Bits® communications and IEEE C37.118 synchrophasors
for unmatched control and system monitoring. All these powerful features are included for the
base price ($4,500 for the full-rack SEL-3530 and $2,850 for the half-rack SEL-3530-4).
Budgetary Price: Starting at $2,850
Overview
Integrated Security
Make the RTAC the secure access point into your substation or plant using LDAP central
authentication, local role-based user authentication, access logs, and secure engineering access.
Map security tags into SCADA reports for industry-leading integration of security
technologies. Simple, Seamless Configuration
Quickly design an integrated substation system that includes protocol conversion, SCADA
communications, synchrophasors, time synchronization, data management, and custom
logic.IEC 61850 Available
Select the IEC 61850 GOOSE and MMS ordering options to integrate the IEC standard in your
control and automation schemes. Use IEC 61850 GOOSE to transmit and receive messages
between the RTAC and protection relays for fast Ethernet based control schemes. Poll datasets,
buffered reports, and unbuffered reports from MMS enabled IEDs with the RTAC using the
optional IEC 61850 MMS client.Optional Integrated Web HMI
Create web-based HMI one-lines, annunciator screens, and control scheme visualizations with
the optional acSELerator® Diagram Builder. This HMI development tool is so integrated with
the RTAC that you don't have to map tags or use protocol conversion to acquire RTAC data.
Enter the IP address of the RTAC and all tags are automatically imported into Diagram Builder.
Load the new HMI page into the RTAC and instantly view from any web browser on the
network.Complete System Control
Combine and convert protocol data from any port with the built-in client and server protocols.
These include SEL Fast Messaging, SEL ASCII, DNP3 Serial, DNP3 LAN/WAN, Modbus®
RTU, Modbus TCP, Mirrored Bits communications, and IEEE C37.118 for synchrophasors.
Easily convert tags between protocols using the tag processor in acSELerator RTAC™ SEL5033 Software for seamless system integration. Unified Substation Logic
Create your logic solutions in the embedded IEC 61131-3 logic engine that comes standard with
every RTAC. All system tags (including diagnostics, contact I/O, protocol data, and
communications statistics) are available for use in custom user logic, providing unparalleled
control flexibility. Renowned SEL Reliability and Support
The RTAC is designed and tested to meet or exceed IEEE 1613 and protective relay
specifications for harsh environments and to withstand vibration, electrical surges, fast transients,
and extreme temperatures.
Applications
Concentrate data from relays and other IEDs with the RTAC. Configure the RTAC to collect and
view station-wide event logs through various popular protocols.Remotely access and monitor the
RTAC via built-in Ethernet connectivity and your favorite web browser.Quickly build embedded
web-based HMI screens for visualization and control of any data in your system using the
optional acSELerator Diagram Builder software.Easily integrate synchrophasor information into
SCADA messages, allowing system-wide application of synchrophasor data.Perform complex
math and logic calculations on synchrophasor data within the RTAC using the built-in logic
engine.Reduce engineering and labor costs and eliminate costly equipment, breakers, interposing
relays, and wiring by making the RTAC the system master controller and SCADA
gateway.Employ integrated tools to scale values and create logic equations in a flexible IEC
61131-3 configuration environment.Secure your automation network with the RTAC and SEL
accessories. Apply user security profiles and employ intrusion detection, notification, and
logging to maintain system integrity.Integrate security options to ensure your system meets
NERC CIP requirements for auditing, logging, port control, web authentication, software patch
management, and password restrictions.
Options
SEL-3530 full-rack chassis:
• IEC 61850 GOOSE
• IEC 61850 MMS Client
• Integrated web-based HMI with acSELerator Diagram Builder
• 24 additional contact inputs and 8 additional outputs (3U chassis only)
• Rack or panel mounting
• 16 additional EIA-232/EIA-485 serial ports (3U chassis only)
• 1U or 3U chassis
• Two power supply options: 125/250 Vdc or 48/125 Vdc, 120 Vac
• Copper, fiber, or mixed Ethernet ports
• Conformal coated circuit boards
SEL-3530-4 four-port chassis:
• Integrated web-based HMI with acSELerator Diagram Builder
• IEC 61850 GOOSE
• IEC 61850 MMS Client
• Three power supply options: 125/250 Vdc; 48/125 Vdc, 120 Vac; or 24/48 Vdc
• Copper, fiber, or mixed Ethernet ports
• Conformal coated circuit boards
Accessories
Connect the RTAC easily to a telephone line with the SEL-9192 Modem.