Embedded Generation
Technical Interconnection Requirements
Prepared by: Station Design & Standards – Embedded Generation
Revision: 0
Date: December 19, 2014
Preface
PowerStream’s Conditions of Service requires terms and conditions of interconnecting
generation facilities to the PowerStream distribution system. This reference document titled
“Embedded Generation Technical Interconnection Requirements” is to be read along with the
Conditions of Service.
The purpose of this document is to provide information on various types of generation
facilities interconnections available to the Customers, Consumers and Suppliers within
PowerStream’s service area and how the interconnection will be facilitated to such Customers,
Consumers and Suppliers. Further, it will outline the processes of interconnection and
settlement to the Customers, Consumers and Suppliers, whether OPA or PowerStream
managed program.
This reference document on Embedded Generation does not yet include generation facilities
owned and operated by PowerStream.
Limitation of Liability and Disclaimer
PowerStream Inc.’s (“PowerStream”) “Embedded Generation Technical Interconnection
Requirements”, including any updates of technical interconnection requirements in the form of
bulletins and/or amendments that are published periodically by PowerStream on its website
(the “TIR”), identifies minimum requirements for generation projects connecting to
PowerStream’s distribution system or the distribution system of Embedded LDCs. Additional
requirements may need to be met by the owner of the generation project to ensure that the final
connection design meets all local and national standards and codes and is safe for the
application intended. The requirements outlined in the TIR are based on a number of
assumptions, only some of which have been identified. Changing system conditions, standards
and equipment may make those assumptions invalid. Use of the TIR and the information it
contains is at the user’s sole risk. PowerStream, nor any person employed on its behalf, makes
no warranties or representations of any kind with respect to the TIR, including, without
limitation, its quality, accuracy, completeness or fitness for any particular purpose, and
PowerStream will not be liable for any loss or damage arising from the use of the TIR, any
conclusions a user derives from the information in the TIR or any reliance by the user on the
information it contains. PowerStream reserves the right to amend any of the requirements at
any time. Any person wishing to make a decision based on the content of the TIR should
consult with PowerStream prior to making any such decision.
Comments and inquiries can be e-mailed to: egconnect@powerstream.ca
Customers without e-mail access can fax comments and inquiries to 1-877-963-6900 x 25001, or
submit through regular mail to:
Station Design & Standards
Embedded Generation
PowerStream Inc.
161 Cityview Boulevard
Vaughan, Ontario L4H 0A9
To contact PowerStream call 1-877-963-6900 x 25001 or e-mail at: egconnect@powerstream.ca
Embedded Generation
Technical Interconnection Requirements
Revision 0
Table of Contents
Table of Contents
1.
Introduction.............................................................................................................................................. 8
1.1
Identification of Embedded Generation and Embedded Generator ............................................... 9
1.2
Related Codes and Governing Laws ................................................................................................. 9
1.3
Interpretations ................................................................................................................................. 9
1.4
Scope ................................................................................................................................................ 9
1.5
Objectives ....................................................................................................................................... 10
1.6
Responsibilities............................................................................................................................... 11
1.7
Terminology...................................................................................................................................... 12
1.8
Capacity Limitations on Generator Interconnections Feeder Loading Limits ................................ 12
1.8.1 Three Phase Generators ............................................................................................................... 13
1.8.2 Single Phase Generators............................................................................................................... 13
1.9
2.
Contact Information ....................................................................................................................... 13
Embedded Generation Facilities .......................................................................................................... 15
2.1
Types of Embedded Generation Facilities ...................................................................................... 15
2.2
Energy Sources ............................................................................................................................... 15
2.2.1 Renewable Energy Sources ........................................................................................................... 15
2.2.2 Clean Energy Sources .................................................................................................................. 15
2.3
Embedded Generation Classification ............................................................................................. 16
2.4
Generators....................................................................................................................................... 16
2.4.1 Embedded Retail Generator ......................................................................................................... 16
2.4.2 Net Metered Generator ............................................................................................................... 16
2.4.3 Retail Generator ............................................................................................................................ 17
2.5
Embedded Generation Programs .................................................................................................... 17
2.6
Outline of Embedded Generation Programs ................................................................................... 17
2.6.1 Emergency Backup Generation and Energy Storage Facilities ..................................................... 18
2.6.3 Feed-in Tariff Program .................................................................................................................. 18
3
Embedded Generation
Technical Interconnection Requirements
Revision 0
2.6.3.1 Micro Feed-in Tariff (microFIT) .................................................................................................. 19
2.6.3.2 Feed-in Tariff (FIT) ...................................................................................................................... 19
2.6.4 Renewable Energy Standard Offer Program (RESOP) ................................................................... 20
2.6.5 Combined Heat and Power Standard Offer Program 2.0 (CHPSOP) ............................................. 20
2.6.6 Demand Response 3 (DR3) ............................................................................................................ 21
2.6.7 Net Metering Program ................................................................................................................. 21
2.6.9 Settlement at Hourly Ontario Energy Price ................................................................................... 22
2.7 Embedded Generation Connections and Metering .......................................................................... 23
2.7.1 Embedded Retail Generation Connection and Metering.............................................................. 23
2.7.1.2 Indirect Parallel Connection ....................................................................................................... 23
2.7.2 Net Metering ................................................................................................................................. 23
2.7.3 Load Displacement ........................................................................................................................ 24
2.7.3 Demand Response 3...................................................................................................................... 24
2.7.4 Settlement at HOEP....................................................................................................................... 24
2.7.5 Wholesale Market Participant ...................................................................................................... 24
2.7.6 General .......................................................................................................................................... 24
2.8
3.
Damages ........................................................................................................................................... 24
Technical Requirements ...................................................................................................................... 25
3.1 General Technical Requirements....................................................................................................... 25
3.1.1 Safety............................................................................................................................................. 25
3.1.2 Active Power ................................................................................................................................. 25
3.1.3 Reactive Power.............................................................................................................................. 25
3.1.4 Equipment Rating And Requirements .......................................................................................... 25
3.1.5 Point of Common Coupling .......................................................................................................... 26
3.1.6 Customer Owned New Line.......................................................................................................... 27
3.1.7 Isolation Device ............................................................................................................................. 29
3.1.8 Interrupting Device Rating ............................................................................................................ 30
3.1.9 Phasing .......................................................................................................................................... 31
3.1.10 Temporary Over-Voltage (TOV) .................................................................................................. 31
4
Embedded Generation
Technical Interconnection Requirements
Revision 0
3.1.11 Grounding ................................................................................................................................... 31
3.1.12 Interconnection Transformer Configuration............................................................................... 34
3.1.12.1 EG Facility Interconnection to 4-Wire Distribution Systems.................................................... 34
3.1.12.2 EG Facility Interconnection to 3-Wire Distribution Systems.................................................... 34
3.1.13 Fault Levels .................................................................................................................................. 35
3.1.14 Instrument Transformers for use in Protection Systems ............................................................ 35
3.1.15 EG Facility Acceptance ................................................................................................................ 35
3.1.16 Generators Paralleling for 6 Cycles or Less (Closed Transition Switching) ................................. 36
3.1.17 Provision for Future Changes ...................................................................................................... 36
3.1.18 Emergency Backup Generation Technical Requirements ......................................................... 36
3.1.19 Energy Storage Technical Requirements .................................................................................... 38
3.1.20 Connection Availability Screening ............................................................................................... 39
3.1.20.1 Distribution Availability Test (DAT) .......................................................................................... 39
3.1.20.2 Transmission Availability Test (TAT)......................................................................................... 39
3.2 Performance Requirements ................................................................................................................. 40
3.2.1 General .......................................................................................................................................... 40
3.2.2 Power Quality ............................................................................................................................... 40
3.2.2.1 Voltage ....................................................................................................................................... 40
3.2.2.2 Voltage and Current Unbalance ................................................................................................. 41
3.2.2.3 Voltage Fluctuations (Flicker)..................................................................................................... 42
3.2.2.4 Voltage and Current Harmonics ................................................................................................. 43
3.2.2.5 Frequency ................................................................................................................................... 45
3.2.2.6 Power Factor .............................................................................................................................. 46
3.2.2.7 Limitation of DC Injection .......................................................................................................... 47
3.2.3 Disturbances ................................................................................................................................. 47
3.2.4 Resonance Analysis ...................................................................................................................... 48
3.2.5 Self-Excitation Analysis ................................................................................................................. 48
3.3 Protection Requirements ..................................................................................................................... 48
3.3.1 General Requirements ................................................................................................................. 48
5
Embedded Generation
Technical Interconnection Requirements
Revision 0
3.3.2 Sensitivity and Coordination ........................................................................................................ 49
3.3.3 Protection Operating Times ......................................................................................................... 50
3.3.4 Breaker Fail (BF) ........................................................................................................................... 50
3.3.5 Single Phase Generators............................................................................................................... 51
3.3.6 Three Phase Generators ............................................................................................................... 52
3.3.7 Phase and Ground Fault Protection .............................................................................................. 55
3.3.8 Phase Loss Protection .................................................................................................................. 56
3.3.9 Over Frequency/Under Frequency Protection.............................................................................. 56
3.3.10 Overvoltage/Undervoltage Protection ....................................................................................... 57
3.3.11 Anti-Islanding Protection ............................................................................................................ 58
3.3.12 Transfer Trip ................................................................................................................................ 58
3.3.13 Embedded Generator End Open (EGEO) .................................................................................... 60
3.3.14 Special Interconnection Protection............................................................................................. 61
3.3.15 Protection Scheme Failures ........................................................................................................ 61
3.3.16 Interconnection Protection Acceptance ..................................................................................... 62
3.3.17 Protection Changes ..................................................................................................................... 63
3.4
OPERATING REQUIREMENTS ......................................................................................................... 63
3.4.1 General ......................................................................................................................................... 63
3.4.2 Islanding ....................................................................................................................................... 64
3.4.3 Unintentional Energization .......................................................................................................... 64
3.4.4 Synchronization ............................................................................................................................ 65
3.4.5 Single Connection Path ................................................................................................................ 66
3.4.6 Automatic Disconnection of Generation and HV Ground Sources .............................................. 66
3.4.7 Automatic Reconnection of Generation ...................................................................................... 67
3.4.8 Reconnection of Generation Following a Sustained Outage or Shutdown.................................. 67
3.4.9 Remote Monitoring and Control ................................................................................................... 68
3.4.9.1 Control Requirements ................................................................................................................ 68
3.4.9.2 Monitoring Requirements ......................................................................................................... 68
3.5 Metering Requirements ....................................................................................................................... 69
6
Embedded Generation
Technical Interconnection Requirements
Revision 0
3.6
Maintenance Requirements........................................................................................................... 69
3.6.1 Protection and Control Systems Equipment ................................................................................. 69
4.
Glossary of Terms ................................................................................................................................... 70
References.................................................................................................................................................. 83
5.
Appendices ............................................................................................................................................... 1
5.1
Appendix 1 - Requirements .............................................................................................................. 1
5.2
Appendix 2 – Agreements ................................................................................................................ 1
5.3
Appendix 3 – Application Forms ...................................................................................................... 1
5.4
Appendix 4 – Remote Monitoring .................................................................................................... 1
Appendix 1(i) - Embedded Generation Connection Overview ..................................................................... 2
Appendix 2(i) - Micro-Embedded Generation Connection Agreement......................................................... 8
Appendix 2(ii) - Small Embedded Generation Connection Agreement...................................................... 12
Appendix 3(i) – Form A – Pre-FIT Consultation Application....................................................................... 15
Appendix 3(ii) - Form B – Connection Impact Assessment Application ..................................................... 16
Appendix 3(iii) – Form C - Micro-Generation Connection Application ...................................................... 17
Appendix 3(iv) - MicroFIT Generator Information Package ....................................................................... 18
Appendix 3(v) - FIT Generator Information Package ................................................................................. 19
Appendix 3(vi) - microFIT Generator Commissioning Verification Form ................................................... 20
Appendix 3(vii) - FIT Generator Commissioning Verification Form ............................................................. 1
Appendix 3(viii) - Net Metering Information Package ................................................................................. 2
Appendix 4(i) - Remote Monitoring and Control Requirements ................................................................... 3
7
Embedded Generation
Technical Interconnection Requirements
Revision 0
1.
Introduction
The “Embedded Generation Technical Interconnection Requirements” (the “TIR”) outlines the
technical requirements for the installation or modification of Embedded Generation (EG)
Facilities connecting to PowerStream Inc.’s (“PowerStream”) Distribution System feeders at ≤
50kV.
Certain requirements including, but not limited to, transfer trip and control and monitoring may
also apply to EG Facilities connecting to the Distribution System of an Embedded LDC other
than PowerStream.
Connection of EG Facilities to PowerStream’s Distribution System feeders impacts the steadystate and transient voltage profiles and current distribution along the feeder in response to
changing supply, load and fault conditions. These impacts must be controlled to:
·
ensure that the safety, reliability and efficiency of PowerStream’s Distribution
System is not materially adversely affected by the connection of EG Facilities to
PowerStream’s Distribution System or the Distribution System of an Embedded
LDC;
·
abide by the requirements of the Distribution System Code (“DSC”) issued by the
Ontario Energy Board, Ontario Electrical Safety Code (“OESC”) and applicable CSA
and IEEE standards; and
·
be compatible with PowerStream’s standard operating, protection, control and
metering systems and practices.
To accomplish this, the design of the power equipment, protection, control and metering systems
used at or for the connection of the EG Facility must meet specific minimum requirements.
Depending on the capacity and electrical characteristics of the connecting EG Facility, specific
additions and/or modifications may be required to PowerStream’s power equipment, protection,
control and metering systems to facilitate the connection.
The TIR has been developed with reference to the Canadian Standards Association such as
CAN/CSA C22.3 No. 9-08 – Interconnection of Distributed Resources and Electricity Supply
Systems, the Distribution System Code (DSC) and international standards such as the Institute of
Electrical and Electronics Engineers (IEEE) Standard 1547 – Interconnecting Distributed
Resources with Electric Power Systems.
It is imperative that these requirements are understood as required by those delegated or
contracted by the owner of an EG Facility (“EG Owner”), PowerStream and other affected Local
8
Embedded Generation
Technical Interconnection Requirements
Revision 0
Distribution Company (LDC) owners for the planning, design, equipment manufacture and
supply, construction, commissioning, operation and maintenance of the EG Facility and
Distribution Systems.
1.1 Identification of Embedded Generation and Embedded Generator
Embedded Generation (EG) is any generation facility that is connected to the distribution grid
of a Local Distribution Company (LDC) that distributes electrical power to Customers and
Consumers. An Embedded Generator shall be a Customer, Consumer or Supplier within
the PowerStream service area which is generating electricity for exporting power to the
PowerStream distribution grid or to displace their own load.
PowerStream may only connect Embedded Generation facilities within its Licensed Territory as
defined in Section 1.1 of the Conditions of Service.
1.2 Related Codes and Governing Laws
Embedded Generation facilities owned by the Customer, Consumer or Supplier shall be subject to
various laws, regulations, and codes as listed in Section 1.2 of the Conditions of Service.
1.3 Interpretations
The rules for interpretation of the PowerStream Embedded Generation Requirements adhere to
the rules listed in Section 1.3 of the Conditions of Service.
1.4 Scope
The TIR applies to the installation of single-phase and three-phase EG facilities connecting to
PowerStream’s Distribution System (50kV and below).
The document is intended to be applied to electric power generators using all types of energy
sources, energy storage and energy conversion technologies – directly connected synchronous and
asynchronous rotating machines, and those connecting via inverters or static power converters
which are above the thresholds mentioned above. The TIR does not apply to EG Facilities parallel
with PowerStream’s Distribution System for less than 100ms (Momentary Closed Transition
Switching) except as noted in Section 3.1.16.
The TIR does not specify protection requirements for the protection of the generator and other
equipment at the EG Facility. The EG Owner is responsible for installing, owning and operating
adequate generator protections as well as protections for other equipment within the EG Facility
to protect them from damage from faults or abnormal conditions which may originate at the EG
Facility or from PowerStream’s Distribution System.
9
Embedded Generation
Technical Interconnection Requirements
Revision 0
The TIR does not constitute a design handbook and is not a substitute for the Ontario Electrical
Safety Code. EG Owners who are considering the development of an EG Facility to connect to
PowerStream’s system shall engage the services of a professional engineer or a registered
consulting firm qualified to provide design and consulting services for electrical interconnection
facilities in the Province of Ontario.
Section 3 contains minimum requirements that the EG Owner is required to comply with in order
to connect its Generation Facility to PowerStream’s Distribution System. Depending on the size
of the EG Facility, the voltage of the interconnected distribution feeder, and whether the EG
Facility is single-phase or three-phase (3-wire or 4-wire) certain requirements may not apply.
It is the EG Owner’s responsibility to ensure that all TIR requirements are met. These TIR
requirements have been developed by PowerStream to ensure that the integrity and power quality
of PowerStream’s Distribution System are maintained to acceptable levels after the connection of
the EG Facility.
Project approval is subject to the results of a Connection Impact Assessment (CIA) performed by
PowerStream. A CIA is required for all projects >10kW in size and must satisfy PowerStream
that there is capacity available for the project and that it can be connected to the distribution
system without any issues or concerns. The EG Owner may have to meet additional or modified
requirements to address unique situations as outlined in the CIA.
Any exemptions to the TIR require PowerStream’s prior written approval.
1.5 Objectives
PowerStream is committed to connecting EG Facilities to the Distribution System while
preserving a safe and reliable electrical supply to all of its customers. The connection of the EG
Facilities must conform to relevant Ontario and Canadian regulations and international design
standards. The TIR has been developed in accordance with the following objectives. These
objectives shall be integrated into all steps to the connection process - design specification,
construction, operation and maintenance of the EG Facility.
SAFETY
The connection of an EG Facility must not create a safety hazard for the general public, other
PowerStream customers, PowerStream employees or others that work on the Distribution System,
nor to personnel working in the EG Facility.
POWER QUALITY
The connection of an EG Facility must not materially degrade the power quality of
PowerStream’s Distribution System below acceptable levels.
10
Embedded Generation
Technical Interconnection Requirements
Revision 0
RELIABILITY
The connection of a EG Facility must not materially compromise the reliability of PowerStream’s
Distribution System as required by the DSC and defined by PowerStream’s Conditions of Service
document.
ACHIEVABILITY
The connection requirements for EG Facilities must be achievable, fair and competitive to allow
equitable access for all EG Owners.
OPERABILITY
The connection of an EG Facility must not restrict the operation of PowerStream’s Distribution
System. All aspects of the connection that can impact PowerStream’s Distribution System must
be compatible with PowerStream’s standard operating, protection, control and metering systems
and practices.
1.6 Responsibilities
Connecting EG Facilities to PowerStream’s Distribution System involves several steps and both
PowerStream and the EG Owner have distinct responsibilities.
PowerStream is responsible for:
·
the safety, reliability, power quality and operation of PowerStream’s Distribution
System, and ensuring the connection of the EG Facility does not adversely affect the
system or PowerStream’s existing customers;
·
maintaining the integrity of PowerStream’s Distribution Systems;
·
operating in compliance with all applicable laws (including its license and codes
issued by the Ontario Energy Board) and within the guidelines of all applicable
Ontario, Canadian and international standards; and
·
establishing the terms and conditions for the TIR that are consistent with the
“Objectives” described above in Section 1.2.
EG Owners are responsible for:
·
the safety, design, construction, operation, metering, protection and control,
and maintenance of the EG Facility;
·
operating in compliance with all applicable laws (including its license and codes
issued by the Ontario Energy Board) and within the guidelines of all
applicable Ontario, Canadian and international standards;
11
Embedded Generation
Technical Interconnection Requirements
Revision 0
·
ensuring that the EG Facility is compatible with PowerStream’s standard operating,
protection, control and metering systems and practices; and
·
abiding by the terms and conditions of the TIR.
1.7
Terminology
Throughout the TIR, the term:
·
“shall” is used to express a mandatory requirement – i.e. a provision that the EG
Facility is obligated to satisfy in order to comply with the requirements of the TIR;
·
“should” is used to express a recommendation or that which is advised but
not required;
·
“may” is used to express an option or that which is permissible within the limits of
the TIR; and
·
“can” is used to express possibility or capability.
1.8 Capacity Limitations on Generator Interconnections Feeder Loading
Limits
The capacity for all sections of all feeders, the “feeder limitation,” is based mainly on the distance
from PowerStream supply station to the Point of Common Coupling (PCC) of the EG Facility.
The feeder limitation applies to all EG Facilities connected or connecting to the feeder and
considers the rated output capacity of each EG Facility. Any single EG Facility connection can
affect the capacity available for all sections of the feeder.
For all sections of the feeder, the total current shall not exceed:
a) 400 Amps for PowerStream feeders operating at voltages 13kV or greater; and
b) 200 Amps for PowerStream feeders operating at voltages below 13kV
Acceptable Generation Limit at a TS or an MS
The acceptable generation limit at a PowerStream TS or a PowerStream MS is established by
adding together: 60% of maximum MVA rating of the single transformer and the minimum
station load.
Short Circuit (SC) Limits
12
Embedded Generation
Technical Interconnection Requirements
Revision 0
The SC limits at TS low voltage bus or at any portion of distribution feeder shall not be exceeded
by the addition of EG Facilities. Refer to Section 3.1.13 for the requirement.
1.8.1 Three Phase Generators
i)
The acceptable individual generation limits for three-phase EG Facilities connecting
to PowerStream’s Distribution System feeders shall not exceed:
a)
b)
ii)
1 MW per connection on feeders operating at voltages below 13kV; and
5 MW per connection on 27.6kV feeders supplied via a 44kV:27.6kV stepdown transformer.
The feeder limitation determines the total acceptable three-phase generation allowed
for all sections of PowerStream’s Distribution System feeders and shall not exceed:
a)
b)
c)
d)
e)
f)
30 MW for feeders operating at 44kV;
19 MW for feeders operating at 27.6kV;
9.6 MW for feeders operating at 13.8kV;
4.3 MW for feeders operating at 12.48kV;
2.9 MW for feeders operating at 8.32kV; and
1.45 MW for feeders operating at 4.16kV.
1.8.2 Single Phase Generators
i)
The acceptable individual generation limits for single-phase EG Facilities
connecting to PowerStream’s Distribution System shall not exceed:
a)
b)
150 kW per connection on feeders operating at nominal voltage levels of
13kV or greater; and
100 kW per connection on feeders operating at nominal voltage levels less
than 13kV.
Note: While the absolute limits are stated above, the actual acceptable generation limit for
specific feeders or TS/MS is determined in the Connection Impact Assessment (CIA).
1.9 Contact Information
PowerStream can be contacted regarding Embedded Generation connection during business
hours, Monday to Friday between 8:30 a.m. and 4:30 p.m., at 1-877-963-6900 x 25001 or such
other numbers as PowerStream may advise through its website or invoices.
PowerStream can also be contacted via e-mail at egconnect@powerstream.ca or such other email addresses as PowerStream may advise through its website or invoices.
13
Embedded Generation
Technical Interconnection Requirements
Revision 0
The mailing address is:
Station Design & Standards
Embedded Generation
PowerStream Inc.
161 Cityview Boulevard
Vaughan, Ontario L4H 0A9
14
Embedded Generation
Technical Interconnection Requirements
Revision 0
2.
Embedded Generation Facilities
2.1 Types of Embedded Generation Facilities
Embedded Generation facilities are interconnected to the PowerStream distribution system for
various purposes as follows:




Standby / Emergency backup
Load displacement
Export of power to the distribution grid
Energy storage
Such interconnected Embedded Generation can be an Emergency Backup Generation Facility, an
Embedded Retail Generation Facility or a Wholesale Market Participant generator as described
in Section 1.2: Definitions of the Distribution System Code (DSC). The owner or operator of any
of the above mentioned generation facilities, is a generator.
2.2 Energy Sources
Energy sources for Embedded Generation facilities will be renewable energy or clean energy,
except for emergency backup.
2.2.1 Renewable Energy Sources






solar
wind
water
renewable or agricultural bio-mass
bio-gas, including landfill gas and
bio-fuel
2.2.2 Clean Energy Sources

natural gas
15
Embedded Generation
Technical Interconnection Requirements
Revision 0
2.3 Embedded Generation Classification
Embedded Generation Classification set forth in the Distribution System Code are outlined in
the table below:
Generator
Classification
Micro
≤ 10 kW
Small
(a) ≤ 500 kW connected on distribution system
voltage < 15 kV
(b) ≤ 1 MW connected on distribution system voltage
≥ 15 kV
Mid-Sized
(a) > 500 kW but ≤ 10 MW connected on distribution
system voltage < 15 kV
(b) > 1 MW but ≤ 10 MW connected on distribution
system voltage ≥ 15 kV
> 10 MW
Large
2.4
Rating
Generators
2.4.1 Embedded Retail Generator
Embedded Retail Generator means Customers which own or operate an embedded generation
facility, other than an Emergency Backup Generation Facility, but is neither a wholesale market
participant, nor a net metered generator. An Embedded Retail Generator’s generation facility is
connected to the distribution system, and the generator generates more electricity than
consumption. Therefore, an Embedded Retail Generator sells output from the embedded
generation facility to either the Ontario Power Authority under a contract or to PowerStream at
the Hourly Ontario Energy Price (HOEP).
2.4.2 Net Metered Generator
As described in the DSC Section 6.7.1, a Customer of a distributor that meets the criteria set out
in Section 7 (1) of the Net Metering Regulation is an “eligible generator” in respect of a
distributor and to whom net metering shall be made available as “net metered generator” by the
distributor.
16
Embedded Generation
Technical Interconnection Requirements
Revision 0
2.4.3 Retail Generator
In accordance with the Retail Settlement Code, a distributor will purchase energy from a
retail generator within its service area, where such generator has indicated that it intends to
generate electricity for sale directly to such distributor and has obtained all required licences
from the Board for generating and exporting electricity.
The generator must also have an executed Connection Agreement with PowerStream. The
Connection Agreement will specify that the generator must meet the technical and metering
requirements set out in the Distribution System Code. The price at which all energy sales will be
settled will be the Hourly Ontario Energy Price as described in Appendix “A” of the Retail
Settlement Code.
2.5
Embedded Generation Programs
Apart from emergency backup as a standby generation facility operated for load displacement
when utility power supply is not available, Embedded Generation facilities will be connected
under different programs, depending on the type and source of energy. Such programs are as
follows:
i.
ii.
iii.
iv.
v.
vi.
vii.
viii.
Micro Feed-in Tariff (microFIT)
Feed-in Tariff (FIT)
Standard Offer Program (SOP) – no new connections offered
Combined Heat & Power SOP 2.0 (CHPSOP)
Demand Response 3 (DR3)
Net Metering
Wholesale Market Participant
Retail Settlement at Hourly Ontario Energy Price (HOEP)
The programs are managed by different stakeholders and settled accordingly. Generators of
programs (i) – (iv) are Embedded Retail Generators as described in Section 2.4.1 and program
(v) is Net Metered Generator as in Section 2.4.2.
Program (viii) is PowerStream administered and settled program as described in the Retail
Settlement Code. A Customer, which is not eligible to be a Net Metered Generator for the nonrenewable fuel type or who generates more than it consumes, will settle with PowerStream, at the
Hourly Ontario Energy Price as described in Appendix “A” of the Retail Settlement Code.
2.6
Outline of Embedded Generation Programs
An outline of each program of Embedded Generation that is presently in effect with
PowerStream is provided below. Technical requirements for connecting such Embedded
Generation are provided in Section 3.
17
Embedded Generation
Technical Interconnection Requirements
Revision 0
2.6.1 Emergency Backup Generation and Energy Storage Facilities
Emergency backup generation and energy storage facilities are installed by Customers for
backup of load when utility power supply is not available.
Customers with a permanently connected Emergency Backup Generation and/or Energy Storage
Facility shall notify PowerStream regarding the presence of such equipment and shall enter into a
Connection Agreement with PowerStream. Contact information is as listed in Section 1.9.
The requirement does not apply to Open-Transition Emergency Backup Generation Facility.
For an overview of the technical requirements, refer to Section 3.1.18.
2.6.3 Feed-in Tariff Program
The Feed-in Tariff (FIT) Program was enabled by the Green Energy and Green Economy Act,
2009 which was passed into law on May 14, 2009. The Ontario Power Authority (OPA) is
responsible for implementing the program.
The FIT Program is a guaranteed pricing structure or tariff for renewable electricity production
and it offers stable prices under long-term contracts for energy generated from renewable
sources, such as solar photovoltaic (PV), on-shore and off-shore wind, water power, biomass,
biogas and landfill gas.
For information on the Feed-in Tariff program, refer to: http://fit.powerauthority.on.ca/
Owners of these projects will be paid a fixed price for the electricity that they produce under a
tariff system.
Projects eligible for the FIT program will receive from the OPA:
(a) a long-term contract for the payment of electricity produced from the
renewable energy project; and
(b) a fixed price for the full term of the contract.
A Customer, Consumer or Supplier eligible to connect a FIT project to the PowerStream
distribution system will have:
(a) a connection agreement signed with PowerStream;
(b) a settlement made by PowerStream on the pre-scheduled billing cycle; and
(c) a settlement based on the contract offered by OPA to the Customer,
Consumer or Supplier.
18
Embedded Generation
Technical Interconnection Requirements
Revision 0
In accordance with the OPA’s Feed-in Tariff program, PowerStream has established a set of
references for the connection of embedded generators to PowerStream’s distribution system. The
information is posted on the PowerStream website here:
http://www.powerstream.ca/app/pages/EG_Overview.jsp
There are two types of processes under the FIT Program: MicroFIT and FIT.
2.6.3.1 Micro Feed-in Tariff (microFIT)
MicroFIT is a stream of the OPA’s FIT program. This program is for “micro scale”
renewable energy projects, generating 10kW or less. MicroFIT is “Micro” generation under the
Embedded Generation classification.
For the OPA’s MicroFIT rules, process, tariff or price schedule and other details, refer to
http://microfit.powerauthority.on.ca/
MicroFIT has a simpler process than FIT, and will be eligible for connection if it meets
the minimum conditions for connection described in Appendix 3(iv) - microFIT Generator
Information Package.
2.6.3.2 Feed-in Tariff (FIT)
FIT is another stream of OPA’s FIT program. This program is for small renewable energy
projects, generating more than 10kW and less than or equal to 500kW. A small FIT project is a
“capacity allocation exempt small embedded generation facility” which is defined in the
Distribution System Code as a project which is not a MicroFIT project and has a nameplate
capacity of:
(a) 250kW or less connected to less than 15kV distribution system and,
(b) 500kW or less connected to greater than 15kV distribution system.
All Projects under the FIT program are connected through a parallel connection. A project
will be considered for connection if it does not have a material adverse impact on the
PowerStream distribution system. A Connection Impact Assessment (CIA) of the project,
performed by PowerStream, must satisfy PowerStream that the project can be connected to the
distribution system without any issues or concerns. The Customer shall pay the cost of the CIA in
accordance with the PowerStream fee schedule prior to PowerStream performing the CIA.
For an overview of the application process and connection requirements for FIT projects, refer to
Appendix 3(v) - FIT Generator Information Package
For the OPA’s FIT rules, process, tariff or price schedule, contract and other details, refer to
http://fit.powerauthority.on.ca/
19
Embedded Generation
Technical Interconnection Requirements
Revision 0
2.6.4 Renewable Energy Standard Offer Program (RESOP)
Important Notes: No new connections are provided under the Renewable Energy Standard
Offer Program (RESOP). Customers and Consumers may rescind the existing RESOP
contract less than 10kW, also referred as SOP, with the OPA and apply for MicroFIT.
No new applications will be received under the RESOP program for EGs larger than 10kW.
Any applicant that has initiated a Connection Impact Assessment (CIA) with PowerStream is
required to rescind the CIA and reapply to OPA under the FIT program.
The OPA, in conjunction with LDCs, established the Renewable Energy Standard Offer Program
(RESOP) to encourage and promote greater use of renewable energy sources such as wind, solar,
photovoltaic (PV), renewable biomass, bio-gas, bio-fuel, landfill gas, or drop in water elevation
for generating electricity. Renewable energy electricity generation projects with a capacity of 10
MW or less that met the program’s requirements were connected to PowerStream distribution
system in order to export electricity.
Generating facilities that participated in the RESOP were connected to the PowerStream
distribution system at a voltage of 27.6 kV or less. Output from the generation facility is metered
as follows:
(a) for generations of 10 kW or less and connected to the line side of the load meter, bidirectional kWh meters are installed to measure energy consumed and energy
exported; and
(b) for all other generations, interval meters are installed.
The Customer or Consumer was solely responsible for any costs associated with the connection
to the PowerStream distribution system and any required metering installation.
2.6.5 Combined Heat and Power Standard Offer Program 2.0 (CHPSOP)
The Combined Heat and Power Standard Offer Program 2.0 (CHPSOP 2.0) is being developed to
support the efficient use of gas-fired electricity generating facilities that use combined heat and
power (CHP) technology. The objective of the CHPSOP 2.0 program is to facilitate the increased
development of CHP facilities that are up to a maximum capacity of 20 MW in size and that
provide thermal energy to operations in the target sectors, specifically: Agricultural Industry
Projects and District Energy Projects.
The First Application Window is set for November 3, 2014 to December 19, 2014 as noted on the
OPA’s website.
CHP Generating Facilities with CHP I or CHPSOP 1.0 contracts are eligible to apply for
20
Embedded Generation
Technical Interconnection Requirements
Revision 0
Expansion Projects. Parities interested in pursuing an Expansion Project are required to submit a
registration form to the OPA no later than November 3, 2014. A final registration form will be
posted after the end of the comment period. For more details, reference section 2.3 of the draft
CHPSOP 2.0 Rules.
For more information as the program is developed, please refer to:
http://www.powerauthority.on.ca/combined-heat-power-procurement
2.6.6 Demand Response 3 (DR3)
Demand Response 3 (DR3) is a program that is overseen by Ontario Power Authority (OPA).
DR3 was developed by the OPA together with DR1 and DR2 and other demand reduction
programs developed from time to time, and all those constitute the Demand Response Program.
For DR3 rules, contract and other details refer to:
https://saveonenergy.ca/Business/Program-Overviews/Demand-Response/Demand-Response3.aspx
A demand response program with contractual obligations is to reduce load during certain periods
of the year. The DR3 load reduction program is for Direct Participants and Aggregators who are
capable of providing a curtailment of load of at least 5.0 MW and 25.0 MW, respectively. OPA
has designated several blocks of hours that a participant can select from to be available to
Curtail.
To be eligible, participants must be operating and available during a predefined schedule of about
1,600 hours per calendar year. Within that 1,600-hour period, one can select to participate in
potential activations of up to 100 hours per year.
Participants make themselves available during scheduled hours for potential notices to reduce
load up to 100 hours or 200 hours per year.
The DR3 Program makes both availability (capacity) and energy payments. Failure to comply
with the contract requirements of the DR3 Program can result in set-offs against potential
revenue.
The program rules, prices, schedules, participation zones, and other specific elements of the DR3
Program are subject to change as required to meet Ontario's energy conservation goals. DR3 will
be operated and managed by the OPA.
2.6.7 Net Metering Program
In order to encourage conservation, PowerStream has established a Net Metering Policy for
eligibility of Customers and Consumers who wish to participate in the Net Metering program.
Eligible Customers and Consumers with renewable energy generation facilities may reduce their
21
Embedded Generation
Technical Interconnection Requirements
Revision 0
energy costs by exporting surplus generated energy back onto the utility distribution system for
credit against the energy the Customer consumes from the distribution system.
In accordance with the Net Metering Regulation, PowerStream has established a Net Metering
Program for netting of surplus generated energy with energy consumed from the PowerStream
supply. The program information is posted on the PowerStream website and can be downloaded
from:
http://www.powerstream.ca/app/pages/EG_NetMetering.jsp
Participation in the Net Metering Program is available to all PowerStream Customers with a
generation facility that meet all of the following conditions and technical requirements:
a)
b)
c)
d)
Generation of electricity is primarily for the Customer’s or Consumer’s own use;
The electricity generated is conveyed to the Customer’s or Consumer’s own
consumption point without reliance on the PowerStream distribution system;
The maximum cumulative output capacity of the generator does not exceed
500 kW; and
The electricity is solely generated from a renewable energy source (such as wind,
drop in water elevation, solar radiation, agricultural bio-mass, or any combination
thereof).
Customers will be required to meet all the parallel generation requirements for Connecting MicroGeneration Facilities (10 kW or less) or other Generation Facilities (greater than 10 kW and up to
500 kW).
2.6.8 Wholesale Market Participant
A Wholesale Market Participant sells or purchases electricity or ancillary services through the
IESO-administered markets. Under the “Market Rules for the Ontario Electricity Market”,
Chapter 2, Section 1.2.1, “No persons shall participate in the IESO-administered markets or
cause or permit electricity to be conveyed into, through or out of IESO-controlled grid unless
that person has been authorized by the IESO to do so”.
All Embedded Market Participants, within the service jurisdiction of PowerStream, once
approved by the IESO are required to inform PowerStream of their approved status in writing,
30 days prior to their participation in the Ontario Electricity market.
2.6.9 Settlement at Hourly Ontario Energy Price
Settlement is done at the Hourly Ontario Energy Price (HOEP) for an embedded generator,
which is a retail generator or a wholesale market participant generator, whose facility is not
connected to the IESO-controlled grid but is connected to the PowerStream distribution
system.
22
Embedded Generation
Technical Interconnection Requirements
Revision 0
Retail Settlement at HOEP is managed and settled by PowerStream. Wholesale Settlement at
HOEP is managed and settled by the IESO.
2.7 Embedded Generation Connections and Metering
Embedded Generation facilities have different types of connections and metering depending on
the size of generation and program. Generation facilities participating in any program are
connected to the PowerStream distribution system at a voltage of 44 kV or less.
As per the definition in Section 1.2 of the DSC, with respect to an embedded generation facility,
“point of supply” means the connection point where electricity produced by the generation
facility is injected into the distribution system. Output from the generation facility is metered as
follows:
a) for generations of 10 kW or less and connected to the line side of the load meter,
by installing a bi-directional kWh meter to measure energy consumed and
energy exported; and
b) for all other generations, by installing a bi-directional interval type meter to
measure energy consumed and energy exported at set intervals.
2.7.1 Embedded Retail Generation Connection and Metering
Embedded retail generators are connected as follows:
2.7.1.2 Indirect Parallel Connection
An indirect parallel connection permits the generation facility and its bi-directional meter to be
installed in parallel with the load service meter of the Customer. The point of parallel connection
is upstream of both meters, but before the connection to the PowerStream distribution system.
As this is a separate service, the generator requires a bi-directional meter and it incurs a monthly
Customer charge of the rate set by OEB.
When the load service requires transformation, the generation facility connected in parallel will
also be connected through the same transformer. Therefore, secondary metering is applied to
both load and generation. Further, transformer loss adjustment as prescribed in the Retail
Settlement Code is applied in generation settlement where applicable.
2.7.2 Net Metering
In Net Metering, the existing load service remains the same, but the meter will be replaced with
a bi-directional revenue meter that records energy flow in both directions. Surplus energy
generated is exported back onto the utility distribution system for credit against the energy the
23
Embedded Generation
Technical Interconnection Requirements
Revision 0
customer consumes from the distribution system.
2.7.3 Load Displacement
In Load Displacement, the output of the generation facility is used or intended to be used
exclusively for the customer’s own consumption. The existing load service remains the same
and depending on the system, the existing load meter may be used or be replaced with a bidirectional revenue meter. No credit is issued for generation and the EG Owner shall ensure that
the generation output does not back feed onto the Distribution System.
2.7.3 Demand Response 3
DR3 participants shall be connected and metered in the manner required by the program. DR3
generation facilities must be equipped with meter(s) as specified by IESO.
2.7.4 Settlement at HOEP
A bi-directional interval meter is used to measure the load consumption, and the power
generated and exported to the grid at the point of common coupling (PCC). Settlement is
performed on the metered consumption and power exported.
2.7.5 Wholesale Market Participant
The connection and metering of a Wholesale Market Participant generation will be similar to
Wholesale Market Participant loads. Connections and metering requirements will vary from
project to project but shall be in accordance with the terms of this document and the Conditions
of Service.
2.7.6 General
The generator will be solely responsible for any costs associated with the connection to the
PowerStream distribution system and any required metering installation not included in the basic
connection.
The cost of metering varies depending on specific site conditions. PowerStream will provide
Customers with meter cost information. Design drawings and a single line diagram of the
generation facility shall be submitted and reviewed by PowerStream; prior to the Connection
Impact Assessment (CIA) and Offer to Connect (Service Design Form) being provided to the
Customer.
2.8
Damages
A Customer with an embedded generation facility connected to the PowerStream distribution
system (other than a micro-embedded generation facility) shall reimburse PowerStream for any
damage to the distribution system or increased operating costs that may result from the
connection of a generation facility.
24
Embedded Generation
Technical Interconnection Requirements
Revision 0
3.
Technical Requirements
The Customer shall ensure that the connection of its generation facility to the distribution system
does not materially and adversely affect the safety, reliability and efficiency of the PowerStream
distribution system.
New or significantly modified generation facilities shall meet the following technical
requirements:
a)
b)
c)
d)
Technical requirements specified in Appendix F.2 of the DSC;
Ontario Electrical Safety Code (OESC) and applicable CSA and IEEE Standards;
PowerStream Technical Interconnection Requirements; and
ESA Electrical Guidelines for Inverter-Based Micro-Generation facilities (10kW and
smaller).
3.1 General Technical Requirements
3.1.1 Safety
The connection, installation and operation of an embedded generation facility shall not create a
safety hazard to PowerStream’s personnel, customers, general public and personnel working in
the EG Facility.
3.1.2 Active Power
The EG Facility shall have to restrict their active power export to the project capacity which was
applied for and assessed in the Connection Impact Assessment.
3.1.3 Reactive Power
The EG Facility shall comply with voltage and power factor requirements in Section 3.2.2.1 and
Section 3.2.2.6 respectively.
3.1.4 Equipment Rating And Requirements
i)
All electrical equipment and its installation shall be approved as required by Rule 2-024 and
Rule 2-004, respectively, of the Ontario Electric Safety Code.
ii)
The EG Facility shall have a connection authorization from ESA prior to a Connection
Agreement with PowerStream.
iii)
The EG Facility shall be maintained throughout the life of the assets to ensure that the EG
Facility operates as designed.
25
Embedded Generation
Technical Interconnection Requirements
Revision 0
iv)
The EG Facility interface equipment shall be compatible with PowerStream’s
Distribution System equipment at the connection voltage which includes but not
limited to:
a)
b)
c)
d)
v)
Maximum Voltage;
Basic Impulse Limit;
Short Circuit Ratings; and
Capacity.
Connection of EG Facilities shall not cause the ratings of PowerStream’s
Distribution System equipment to be exceeded for all operating conditions. This
includes, but is not limited to:
a)
b)
Equipment thermal loading limits; and
Equipment short circuit limits.
vi)
Where reverse power flow is possible, all existing voltage regulating and metering
devices shall be made suitable for bi-directional flow.
vii)
Changes to PowerStream’s Distribution System equipment ratings due to the
interconnection of EG Facilities shall be assessed by PowerStream’s CIA.
PowerStream may determine that equipment that was deemed to be in compliance with the
technical requirements of the DSC as noted in the immediately preceding paragraph is not in
actual compliance with the technical requirements due to any of the following conditions:
(a) a material deterioration of the reliability of the distribution system resulting from the
performance of the generator’s equipment; or
(b) a material negative impact on the quality of power of an existing or a new Customer
resulting from the performance of the generator’s equipment; or
(c) a material increase in generator capacity at the site where the equipment deemed
compliant is located.
In such a case, PowerStream will provide the Customer with rules and procedures for requiring
such equipment to be brought into actual compliance. The Customer shall then bring its
equipment into actual compliance with the technical requirements and within a reasonable time
period specified by PowerStream.
3.1.5 Point of Common Coupling
i)
The PCC must be identified on the single line diagram (SLD).
ii)
The EG Owner shall be responsible for the design, construction, maintenance and
26
Embedded Generation
Technical Interconnection Requirements
Revision 0
operation of the facilities and equipment on the EG Facility side of the PCC.
iii)
All equipment on the EG Facility side of the PCC shall be in accordance with
Section 3.1.4.
iv)
PowerStream shall be responsible for the design, construction, maintenance
and operation of the facilities on the PowerStream’s side of the PCC.
v)
When specifications and parameters (such as voltage, frequency, and power
quality) are mentioned throughout the TIR, they must be met at the PCC unless
otherwise stated.
vi)
PowerStream or the EG Owner may require that their equipment be located on the
other side of the PCC. In this case, the EG owner must provide the necessary space
for PowerStream to install such equipment and PowerStream deem the site
acceptable.
vii)
A 120V AC power service is to be available for Item (vi) above.
3.1.6 Customer Owned New Line
This section applies to EG Owner’s new lines that connect to PowerStream’s Distribution System
at the PCC. It does not apply to those connecting to existing customer owned facilities.
i)
A load break switch for a new line owned by the EG Owner is required at the PCC
to manually disconnect the EG Owner’s line from PowerStream’s Distribution
System:
a)
The load break switch shall be gang-operated for multi-phase applications;
b)
The switch shall have the same requirements as the isolation device in
Section 3.1.7 except that it does not have to be motorized;
c)
The load break switch must be capable of taking the line off potential safely
based on, but not limited to, circuit capacitance, transformer connections and
load considerations;
d)
An overcurrent protection device as outlined in Item (ii) below can serve the
purpose of the load break switch provided that it is located at the PCC and it
can manually disconnect load simultaneously on all phases. If the
overcurrent protection device cannot be visually verified to be open, an
27
Embedded Generation
Technical Interconnection Requirements
Revision 0
additional isolating device shall be provided for work protection purpose.
This may be in the form of single phase solid blade switch, opener, etc.
ii)
An overcurrent protection device is required to automatically disconnect the
EG Owner’s line from PowerStream’s Distribution System for faults on the EG
Owner’s line or equipment, as outlined below:
a)
For EG Facilities connecting to PowerStream’s 3-wire systems, the
overcurrent protection device should provide 3-phase gang-operated fault
interruption. For those connecting to PowerStream’s 4-wire systems, the
overcurrent protection device can be single-phase or three-phase gangoperated;
b)
The overcurrent protection device shall meet, but not be limited to, the
following criteria:
c)
1)
The interrupting rating shall account for present and future
anticipated fault levels;
2)
The setting shall be coordinated with the timed elements of
upstream protective devices, and it shall be sensitive enough to
operate for minimum PowerStream infeed to faults on the customer
owned new line;
3)
If fuses are used, they should not operate for maximum EG infeed to
faults on the interconnected feeder;
4)
If a recloser is used, automatic reclosing shall be disabled.
The location of the overcurrent protection device must be as close to the
PCC as practical. It can be either on the first or second pole after the
PCC, depending on whether a dedicated pole is required to be used for the
revenue metering. Under the following circumstances, the overcurrent
protection device can be located at or near the EGIT, on the high voltage
side:
1)
For new line length not exceeding 200m;
2)
For EG Facilities with more than one interconnection transformer
where the total HV circuit length from the PCC does not exceed
200m;
28
Embedded Generation
Technical Interconnection Requirements
Revision 0
3)
For 44kV connections where fault levels are higher than any
available overcurrent protection device interrupting ratings.
iii)
Fault indicators with directional functionality are required for each phase between
the PCC and the first pole on the customer owned new line and should be visible
from the PCC location.
iv)
The EG Owner shall be responsible for the installation, operation and ownership of
the load break switch, overcurrent protection device and fault indicators required to
be used for the new line.
v)
Any additional requirements shall be determined in the CIA.
3.1.7 Isolation Device
When a Customer with an embedded generation facility is connected to the PowerStream
distribution system, the Customer shall provide an interface protection that is capable of
automatically isolating the generation facility from the PowerStream distribution system under
the following situations:
(a) internal faults within the generator
(b) external faults in the PowerStream distribution system
(c) certain abnormal system conditions, such as over/under voltage, over/under
frequency.
The isolation device shall (as outlined by the OESC Sections 18 & 84):
a)
b)
c)
d)
e)
f)
g)
h)
i)
j)
k)
l)
m)
n)
be in compliance with the OESC
be capable of being energized from both sides
plainly indicate whether in the open or closed position
be capable of being opened at rated load (Load Break Switch)
be located between the PowerStream system and the EG Facility, upstream of all
transformers, generation and HV ground sources
be readily accessible by PowerStream
not be located in a locked facility
not be located in a hazardous location
have provision for being locked in the open position
have a manual override
have no keyed interlocks
have contact operation verifiable by direct visible means (be a Visible Break type)
conform to OESC Sections 14, 28 and 36 if it includes an overcurrent device
be capable of being closed with safety to the operator with a fault on the system
29
Embedded Generation
Technical Interconnection Requirements
Revision 0
o)
p)
iii)
be capable of being operated without exposing the operator to any live parts
and
bear a warning to the effect that inside parts can be energized from sources on both
sides when disconnecting means is open.
In addition to the requirements in Item (ii) above, all three phase EG Facility’s
isolation device shall:
a)
b)
be gang operated and disconnect all ungrounded conductors of the circuit
simultaneously
be motorized if the EG Facility is larger than:
1)
2)
c)
250 kW when connecting to feeders operating below 15kV; and
500 kW when connecting to feeders operating above 15kV.
have a protection interface for tripping if used as a backup for interrupting device
failure (HVI Breaker Failure or LVI Breaker Failure).
iv)
If the isolation device is motorized as required by Item (iii)(b) above, it shall be powered
from a reliable source such as a DC battery to power a DC motor or via a battery-supplied
DC/AC inverter to power an AC motor.
v)
If multiple generators are connected at the EG Facility, one disconnect switch shall be
capable of isolating all of the generators simultaneously.
vi)
Switching, tagging and lockout procedures shall be coordinated with PowerStream.
vii)
The EG Owner and PowerStream shall mutually agree to the exact location of the
disconnect switch.
3.1.8 Interrupting Device Rating
i)
All fault current interrupting devices shall be sized appropriately using present and
anticipated future fault levels.
ii)
The interrupting device used to disconnect generation from PowerStream’s Distribution
System shall operate fast enough to meet the timing requirement of the quickest protection
operation and shall:
a)
operate in no more than 160ms, which includes the protection element
detection time for EG Facilities not equipped with Transfer Trip; and
30
Embedded Generation
Technical Interconnection Requirements
Revision 0
b)
operate within the required time for EG Facilities equipped with Transfer Trip as
shown in Table 12 – maximum interrupting device time is dependent on the speed
of Transfer Trip communications.
3.1.9 Phasing
i)
The EG Facility must connect rotating machines as required to match the phase sequence
and direction of rotation of PowerStream’s Distribution System.
3.1.10 Temporary Over-Voltage (TOV)
i)
When connecting to PowerStream’s 4-wire Distribution System, TOV that may be
caused by the EG Facility connection should not exceed 125% of nominal system voltage
(line to neutral) anywhere on the distribution system and under no circumstance shall
exceed 130%. PowerStream may advise on action needed to reduce TOV to limits by
specifying the requirement of grounding transformer on the HV side.
3.1.11 Grounding
i)
The grounding of the EG Facility shall not cause overvoltages that exceed the rating of
equipment connected to PowerStream’s Distribution System.
ii)
The grounding of the EG Facility shall ensure that TOV limits in Section 3.1.10 are not
exceeded.
iii)
The grounding of the EG Facility shall not disrupt the coordination of ground fault
protection of PowerStream’s Distribution System.
iv)
The EG Facility’s grounding shall be per manufacturer’s recommendation, the OESC and
the requirements in Section 3.1.11 of the TIR.
v)
The connection of a EG Facility shall not cause the Neutral to Earth Voltage (NEV) to
exceed CSA requirements (i.e., less than 10 V rms) on 4-wire multi-grounded distribution
system.
vi)
In the case of shared-use poles, voltages induced on the under-strung neutral must be
minimized so as not to increase NEV.
31
Embedded Generation
Technical Interconnection Requirements
Revision 0
vii)
If the primary HV winding of the EGIT is grounded or a grounding transformer on the HV
side of the EGIT is installed, the ground grid of the EG Facility shall be connected to
PowerStream’s ground grid (neutral).
viii) EG Facilities with a grounded HV EGIT, either utilizing a grounding transformer or a
neutral reactor connected to the HV neutral, shall be sized as required in either Item (ix)
below to ensure that TOV limits are not exceeded or Item (x) below to ensure the impact to
ground fault protection coordination requirements in Item (iii) above is satisfied.
ix)
For EG Facilities connecting to PowerStream’s 4-wire Distribution System, TOV is a major
concern and the neutral reactor (Xn) or grounding transformer shall be sized by the EG
Owner and reviewed during the Connection Impact Assessment based on a Thevenin
Equivalent of the Positive (XEG1) and Zero Sequence (XEG0) Reactance of the EG
Facility (example: at the Point of Connection with the Point of Connection OPEN) that will
result in:
a)
For Conventional (Rotating) Generators:
This will achieve an overall Thevenin Equivalent Positive and Zero Sequence impedance at
any point on the feeder with any or all EG Facility sources and PowerStream sources InService of:
For EG Facilities with an Inverter Interface:
where 1 p.u. impedance is based on:
1)
the total MVA rating of the EG Facility (sum of EGITs MVA ratings) and high side kV
rating of the EGIT(s) for Grounding Transformer sizing; or
2)
the MVA and high side kV rating of the EGIT for Neutral Reactors sizing.
32
Embedded Generation
Technical Interconnection Requirements
Revision 0
[Note: EGIT MVA rating is assumed to be approximately equal to the generation capacity.]
x)
For EG Facilities connecting to PowerStream’s 3-wire Distribution System, a grounded HV
EGIT is not required. However, if the EG Owner decides to have the EGIT grounded, the
ground source contribution from the EG shall be limited as follows. The neutral reactor
(Xn) or grounding transformer shall be sized by the EG Owner and reviewed during the
Connection Impact Assessment based on a Thevenin Equivalent of the Positive (XEG1) and
Zero Sequence (XEG0) Reactance of the EG Facility (example: at the Point of Connection
with the Point of Connection OPEN) that will result in:
a)
For Conventional (Rotating) Generators:
c)
For EG Facilities with an Inverter Interface:
[Note: For (a) above, XEG1 is the equivalent of Xd plus Xt of the EG Facility. For (b)
above, XEG1 is the reactance of the EGIT. See Appendix C for calculation examples.]
xi)
The installation of a wind farm shall not increase the lightning transfer to PowerStream’s
system.
xii)
In wind installations, to limit the exposure of lightning to PowerStream’s Distribution
System, lightning protection grounding shall be electrically separated from the grounding
grid of the wind tower.
xiii) Where the separation in Item (xii) above is not possible or practical, then the ground grids
of the towers shall be electrically separated from the EG Facility Station ground grid from
the point of view of transferred lightning surges. The latter can be achieved by ensuring that
the wind towers are not bonded to the station's ground grid.
xiv) Standalone studies are required to ensure that GPR meets step and touch potential and
OESC requirements.
xv)
The report in Item (xiv) above must be submitted to PowerStream.
33
Embedded Generation
Technical Interconnection Requirements
Revision 0
3.1.12 Interconnection Transformer Configuration
i)
The EG Interconnection Transformer (EGIT) shall not cause voltage disturbances or disrupt
co-ordination of distribution system ground fault protection.
ii)
The EG Owner shall choose one of the EGIT configuration options outlined in Section
3.1.12.1 if the EG Facility is connecting to PowerStream’s 4-wire Distribution System.
iii)
The EG Owner shall choose the EGIT configuration outlined in Section 3.1.12.2 if the EG
Facility is connecting to PowerStream’s 3-wire Distribution System.
iv)
The EG Owner shall ensure that there is no back feed from the EGIT when the generator is
out of service and shall be responsible for all consequences resulting from such back-feeds.
v)
The EGIT may supply unbalance current to support the unbalanced load on the feeder even
when the generator is out of service. The EG Owner is responsible to ensure the design is
adequate to handle the unbalance current. Refer to Requirements in Section 3.2.2.2.
vi)
Items (i), (ii) and (iii) above apply to all EG Facilities connecting directly to PowerStream’s
Distribution System or indirectly through a hybrid feeder.
vii)
Items (i), (ii) and (iii) above may apply to EG Facilities connecting indirectly to
PowerStream’s Distribution System through an embedded LDC if the connections may
negatively impact PowerStream’s system.
viii)
To accommodate the connection of a proposed EG Facility to an existing Delta service
PowerStream will install a Delta meter, however, the customer must upgrade to a Wye 4wire connection at PowerStream’s request. The Wye upgrade will be at the customers cost,
including all labor, wiring, meter(s), and associated hardware.
3.1.12.1 EG Facility Interconnection to 4-Wire Distribution Systems
i)
The EG Facility shall connect to PowerStream’s 4-Wire Distribution System using WyeGround:Wye-Ground EGIT. If another configuration is required, a design may be submitted
to PowerStream for review.
3.1.12.2 EG Facility Interconnection to 3-Wire Distribution Systems
i)
The EG Facility shall connect to PowerStream’s 3-Wire Distribution System through:
Delta:wye EGIT.
34
Embedded Generation
Technical Interconnection Requirements
Revision 0
ii)
For EGIT configurations that connect the EG Facility to PowerStream’s system as a ground
source, the EG Facility shall meet the grounding requirements in Section 3.1.11 Item (x).
iii)
The design of the EGIT shall ensure that all Power Quality requirements are adhered to.
3.1.13 Fault Levels
i)
Maximum fault levels must be maintained within the limits set by the Transmission System
Code (TSC) as shown in Table 1 and the connection of EG Facilities shall not cause these
limits to be exceeded.
Table 1: TSC Maximum Fault Levels
Fault Levels
Maximum fault values
are symmetrical fault
values.
Higher values may
exist for short times
during switching
Requirement
Nominal Voltage (kV)
Maximum ThreePhase Fault (kA)
44
20
27.6 (4-wire)
17
13.8
24
8.32
24
4.16
25
3.1.14 Instrument Transformers for use in Protection Systems
i)
All instrument transformers used in EG Facilities for protections shall meet the
requirement of CSA-C60044-6 or IEEE C57.13.
3.1.15 EG Facility Acceptance
i)
The EG Owner must have a professional engineer licensed in the Province of Ontario
declare (stamp and seal) that the EG Facility has been designed, tested and constructed in
accordance with the requirements of the TIR, PowerStream’s site-specific requirements,
prudent utility practice and all applicable standards and codes.
35
Embedded Generation
Technical Interconnection Requirements
Revision 0
ii)
The EG Owner shall provide the proposed design of all power equipment, protection,
control, and metering systems used at the EG Facility to PowerStream for review.
3.1.16 Generators Paralleling for 6 Cycles or Less (Closed Transition Switching)
i)
The generator shall be exempt from all requirements in the TIR except for the
requirements in Items (ii) and (iii) below.
ii)
EG Facilities paralleling for 6 cycles or less shall have the following protections:
iii)
a)
Under-voltage protection to ensure that the generator is not capable of energizing
PowerStream’s Distribution System if it is de-energized; and
b)
A 6 cycle timer to ensure that the EG Facility will not parallel with PowerStream’s
Distribution System for more than 6 cycles.
Synchronization facilities, where required, must follow the requirements specified in
Section 3.4.4.
3.1.17 Provision for Future Changes
i)
The EG Owner shall be responsible to stay aware of future changes to the business
environment and technical requirements.
ii)
The EG Owner shall make any necessary changes to the EG Facility promptly in response
to:
iii)
a)
New or revised standards;
b)
New or revised codes;
c)
Legislation changes; and
d)
Safety concerns.
The EG Owner may be responsible for some or all costs associated with the changes in Item
(ii) above.
3.1.18 Emergency Backup Generation Technical Requirements
Emergency backup generation facilities are installed by Customers for backup of load when utility
power supply is not available. A Customer with portable or permanently connected emergency
36
Embedded Generation
Technical Interconnection Requirements
Revision 0
backup facility shall comply with all applicable criteria of the Ontario Electrical Safety Code
(OESC) and in particular, shall ensure that its Emergency Backup Generation Facility does not
back feed into the Distributor's system.
A Customer with an Emergency Backup Generation and/or Energy Storage Facility in OpenTransition mode shall further ensure that its facility does not parallel with, nor adversely affect
PowerStream’s distribution system.
Customers who consider installing a Closed-Transition switch shall notify PowerStream and shall
submit documentation that satisfies PowerStream’s technical requirements. Customers shall obtain
written authorization from PowerStream prior to commissioning the switch in Closed-Transition
mode. Closed-Transition switches must not operate the generator in parallel with PowerStream's
distribution system for longer than 100 ms. A backup timer shall monitor the parallel duration and
automatically open the main or generator contacts within 500 ms if the maximum parallel duration
is exceeded. The backup timer shall also provide visual indication and lockout the transfer
system.
Closed transition transfer of the generation facility shall not cause a voltage fluctuation of more
than 5% at the PCC. Closed transition transfer from utility to generator and retransfer shall take
place only when the two sources have a maximum voltage difference of 5%, frequency difference
of 0.2 Hz and phase angle difference of 5 electrical degrees. For backup generation facilities with
an aggregate capacity greater than 5 MVA, active synchronization shall be used.
In order to operate Closed-Transition switches of emergency backup generation facilities, the
Customer must also submit to PowerStream:
i.
ii.
iii.
iv.
v.
vi.
an ESA Plan review report
a Short Circuit Coordination Study
a Sequence of operation in descriptive format
a simplified one-line drawing of the power distribution at the proposed site
monitoring requirements as per section 3.4.9
P. Eng certified commissioning report
Where multiple emergency backup generators with Closed-Transition transfer are planned to be
installed at a single location, the design and configuration shall minimize the impact to the
distribution grid including fault contribution by using techniques such as sequencing the ClosedTransition transfer and generator units, or using a high impedance design or other equivalent
method.
The Customer shall notify PowerStream a minimum of fifteen working days in advance of
scheduled commissioning tests to enable PowerStream to witness the commissioning tests.
PowerStream requires a commissioning test report certified by a Professional Engineer. The
37
Embedded Generation
Technical Interconnection Requirements
Revision 0
commissioning verification report shall confirm the installation, configuration, upstream
protection, co-ordination devices and sequence of operation as per submitted design
requirements. The commissioning report shall be submitted for approval before the operation of
the Emergency Backup and/or Energy Storage Facility.
The main incoming feeder supply load break switch and/or main breaker will have lamacoid
signage with the following message:
The signage shall be 250 mm x 150 mm (10” x 6”) Lamacoid plate c/w aluminium 15 mm (3/5”)
high black letters on yellow background to be fastened permanently to the respective item. A
laminated simplified single line diagram will also be placed on the main incoming feeder supply
load break switch and/or main breaker. The label shall be, at minimum, 250 mm x 150 mm (10” x
6”). All labels shall be supplied and installed by the Customer.
Customers with a permanently connected Emergency Backup Generation Facility operating in
parallel shall notify PowerStream regarding the presence of such equipment and shall enter into a
connection agreement as required in Section 4 of this document. Contact information is as
listed in Section 1.9.
3.1.19 Energy Storage Technical Requirements
Customers with an Energy Storage Facility, whether it is portable or permanently affixed, shall
comply with the requirements of the Technical Interconnection Requirements, including any
PowerStream communication of Technical Interconnection Requirements updates in the form of
bulletins and/or amendments that may occur periodically, if any, and all of the applicable criteria of
the Electrical Safety Code. Furthermore, the Customer is responsible for complying with all
Applicable Laws in respect of the Energy Storage Facility, including, all applicable environmental
requirements.
All Energy Storage Facilities must be operated in isolation from the Distribution System.
Customers with an Energy Storage Facility shall ensure that it never remains connected to the
Distribution System for more than 6 cycles (100ms). As such, the switching transition shall either
be OPEN (break before make) or if the switching transition is CLOSED (make before break), then
the switching transition shall be within 6 cycles (100ms).
38
Embedded Generation
Technical Interconnection Requirements
Revision 0
Customers with permanently affixed Energy Storage Facilities shall notify PowerStream regarding
the presence of such equipment and shall enter into a connection agreement as required in Section 4
of this document. Contact information is as listed in Section 1.9.
3.1.20 Connection Availability Screening
i)
All FIT applications that are complete and eligible will be required to undergo connection
availability screening. The OPA will use the following tests in the connection availability
screening.
3.1.20.1 Distribution Availability Test (DAT)
i)
In the distribution availability test, applications will be assessed in sequential order based
on the established priority ranking. The distribution availability test considers:
a)
All prior OPA contracts
b)
Prior applications that have been processed
c)
Any other generation facilities that are existing, committed or are the subject of a
ministerial direction.
3.1.20.2 Transmission Availability Test (TAT)
i)
ii)
In the transmission availability test, applications will be assessed in sequential order based
on their priority ranking, using the time stamp as a tie-breaker in cases where projects are
ranked with equal points. The transmission availability test considers:
a)
All prior OPA contracts
b)
Prior applications that have been processed
c)
System capacity allocated to other OPA programs (such as the microFIT Program)
d)
Any other generation facilities that are existing, committed or are the subject of a
ministerial direction
e)
Limited minor upgrades to the transmission system whose costs are connection costs
(limited as set out in the FIT Rules).
There are three levels of assessment:
a)
Transformer station test
39
Embedded Generation
Technical Interconnection Requirements
Revision 0
b)
Transmission circuit test
b)
Area test
If an application passes the distribution availability test, it may receive a FIT contract offer if it
passes the transmission availability test where applicable. An application that fails the distribution
availability test will be terminated even if it has passed the transmission availability test.
Projects will need to pass both the TAT and the DAT to receive a FIT contract offer. The
application will be terminated if it fails either of the two tests.
3.2 Performance Requirements
3.2.1 General
i)
The connection of the EG Facility must not materially compromise the reliability or restrict
the operation of PowerStream’s Distribution System.
ii)
The connection of the EG Facility must not degrade power quality below acceptable levels
listed in Section 3.2.2 (Power Quality Requirements).
iii)
The EG Owner shall ensure that the facility is equipped to measure, record and report on
performance related events to demonstrate compliance as required by the applicable
sections of the TIR.
iv)
If the EG Facility is found to significantly deteriorate the performance of the
PowerStream’s Distribution System, it shall be disconnected from PowerStream’s
Distribution System until appropriate measures are taken to mitigate the negative impacts.
3.2.2 Power Quality
3.2.2.1 Voltage
i)
The EG Owner shall ensure that the operation of the EG Facility does not have an
objectionable impact on voltage at the PCC or the interconnected feeder and shall not cause
any violation of CSA Standard CAN3-C235-83 “Preferred Voltage Levels for AC Systems,
0 to 50,000V Electric Power Transmission and Distribution” along the entire interconnected
feeder.
40
Embedded Generation
Technical Interconnection Requirements
Revision 0
ii)
PCC voltage shall be maintained within 0.94~1.06 p.u. and shall not be lower than preconnection voltage.
iii)
The EG Facility shall not actively regulate the voltage at the PCC. Voltage at the PCC shall
be maintained within acceptable limits by following the requirements in Item (vii) below.
iv)
Voltage variations at the PCC shall be limited in accordance with the “Voltage Fluctuations
(Flicker) Requirements” in Section 3.2.2.3.
v)
At the feeder level, EG Facility shall not contribute to short-term voltage fluctuation
anywhere on the feeder by more than 1%.
vi)
At the station level, all EG Facilities connected to the TS/DS shall not collectively
contribute to short-term voltage fluctuation at the station LV bus by more than 1%.
vii)
Tripping of all EG Facilities connected to the station shall not cause abrupt voltage change
to result in a voltage above 110% of nominal bus voltage, or less than 90% of nominal bus
voltage, after a single contingency and before the station ULTC/feeder VR operates. The
operating power factor of the EG Facility at the PCC shall be as required in Section 2.2.2.6
Item (v).
viii)
During normal operation, the EG Facility shall be loaded and unloaded gradually to allow
adequate time for regulating devices on PowerStream’s Distribution System to respond and
avoid excessive voltage fluctuations.
ix)
The EG Facility shall protect itself from abnormal voltage conditions which the distribution
system is subjected to. These may include but are not limited to:
x)
a)
voltage transients; and
b)
sags and swells caused by lightning, switching, faults, and the loss or
switching of customer loads.
Insulation levels and protective equipment at the EG Facility shall be capable of
withstanding abnormal voltages from PowerStream’s Distribution System.
3.2.2.2 Voltage and Current Unbalance
i)
The EG Facility shall be capable of operating under existing unbalance conditions.
41
Embedded Generation
Technical Interconnection Requirements
Revision 0
ii)
The EG Facility shall not cause deterioration of existing unbalance voltage and current
conditions at the PCC and in the distribution system.
iii)
A single phase generator shall not negatively impact the unbalance of the nearest threephase distribution system.
iv)
The EG Facility shall protect itself from highly unbalanced voltages and currents, especially
when connected to PowerStream’s Distribution System where single phase reclosing is
used.
v)
The EG Facility and its interconnection transformer’s design shall take into
consideration the unbalance current it may supply to the unbalanced load on the feeder.
vi)
Single phase generators shall not cause an unbalance of greater than 2% when connected
alone.
vii)
If multiple single phase generators are installed, they shall be connected so that an equal
amount of generation is applied to each single phase of the distribution line, and this
balance shall be maintained if one or more of the generating units go offline.
3.2.2.3 Voltage Fluctuations (Flicker)
i)
The EG Facility shall not create objectionable flicker for other customers on PowerStream’s
Distribution System.
ii)
The voltage dip at the PCC should not be more than 4% on connecting the single largest
generation unit in the facility and should remain within 10% of nominal voltage when the
entire EG Facility and all other EG Facilities on the interconnected feeder trip.
iii)
Item (i) above shall include flicker caused by energization inrush.
iv)
The EG Owner shall take steps to make sure that flicker requirements in Items (i) and (ii)
are met - may need to add loss of synchronism protection, stagger generator
energization, etc.
v)
The EG Facility shall conform to the flicker requirements in CAN/CSA C61000-3-7 and
meet the Pst and Plt limits shown below in Table 3.
Table 3: Pst and Plt Flicker Limits
42
Embedded Generation
Technical Interconnection Requirements
Revision 0
27.6/25/13.8/12/8/4 kV
44kV
0.9
0.7
0.8
0.6
Pst
Plt
Source: CSA/CAN C61000-3-7
vi)
Flicker measurements shall be conducted by the EG Owner using a device that conforms to
CAN/CSA-C61000-4-15 if requested by PowerStream. PowerStream shall request this
measurement if flicker complaints are received in the surrounding area.
vii)
Induction generators and inverter-based generators that do not produce
fundamental voltage before the paralleling device is closed, and double-fed generators
whose excitation is precisely controlled by power electronics to produce a voltage with
magnitude, phase angle, and frequency that match those of the distribution system shall be
tested to determine the maximum startup current. The results shall be used, along with the
Distribution System source impedance for the proposed location, to estimate the starting
voltage magnitude change and verify that the unit will not cause a voltage fluctuation at the
PCC greater than ± 4% of the prevailing voltage level of the distribution system at the PCC.
viii)
Induction generators may be connected and brought up to synchronous speed by direct
application of rated voltage provided that they meet the requirement of voltage drop given
above and/or they do not exceed flicker limits at the PCC. Otherwise, other methods such as
reduced voltage starting or speed matching using the prime mover prior to connection must
be used to respect these voltage drop and flicker limits.
ix)
Large EG Facilities with multiple generator units, shall stagger the generator reconnections
to PowerStream’s Distribution System to meet the above requirements.
3.2.2.4 Voltage and Current Harmonics
i)
The EG Facility shall not inject harmonic current that causes unacceptable voltage
distortion on PowerStream’s Distribution System.
ii)
The EG Facility shall follow the requirements of CAN/CSA C61000-3-06.
iii)
The EG Facility shall operate within the Voltage distortion limits as indicated in Table 4
and Table 5 below.
Table 4: Voltage Distortion Limits for Odd Harmonics
43
Embedded Generation
Technical Interconnection Requirements
Revision 0
Odd Harmonics
Non Multiples of 3
Odd Harmonics
Multiples of 3
Harmonic Voltage (%)
4-27.6kV
Harmonic Voltage (%)
44kV
4-27.6kV
44kV
5
5
2
3
4
2
7
4
2
9
1.2
1
11
3
1.5
15
0.3
0.3
13
2.5
1.5
21
0.2
0.2
17
1.6
1
>21
0.2
0.2
19
1.2
1
23
1.2
0.7
25
1.2
0.7
>25
* Source: CAN/CSA C61000-3-06
Table 5: Voltage Distortion limits for Even Harmonics
Even Harmonics
Harmonic Voltage (%)
4-27.6kV
44kV
2
1.6
1.5
4
1
1
6
0.5
0.5
8
0.4
0.4
44
Embedded Generation
Technical Interconnection Requirements
Revision 0
10
0.4
0.4
12
0.2
0.2
>12
0.2
* Source: CAN/CSA C61000-3-06
0.2
iv)
Total Harmonic Distortion (THD) shall be a maximum of 3% on 44kV systems and 6.5%
on other systems.
v)
The EG Facility shall operate within the current harmonic limits as listed in Table 6.
Table 6: Harmonic Current Limits
Harmonic Number h
5
7
Admissible harmonic
5-6
3-4
current ih=Ihi/Ii
* Source: CAN/CSA C61000-3-06
(%)
11
13
1.5-3
1-2.5
√∑
6-8
* Ih is the total harmonic current of order h caused by the consumer and I i is
the rms current corresponding to his agreed power (fundamental
frequency)
vi)
The EG Owner and/or PowerStream may be required to implement measures that will
mitigate the harmonic distortions caused by the EG Facility such as by adding harmonic
filters, at the EG Owner’s sole expense.
vii)
The limits presented in Items (iii), (iv) and (v) above exclude the harmonic
distortions present on PowerStream’s Distribution System when the EG Facility is
disconnected from the distribution system.
viii)
The TIR does not impose design limits to limit harmonic-caused telephone interference
problems as it is almost impossible to predict. However, the EG Owner shall make sure that
the design complies with all applicable standards and shall not cause telephone interference.
3.2.2.5 Frequency
i)
The generators at the EG Facility shall operate at a nominal frequency of 60Hz.
45
Embedded Generation
Technical Interconnection Requirements
Revision 0
ii)
The generators at the EG Facility shall remain synchronously connected over the frequency
range presented below in Table 7.
iii)
The generators shall trip in the time required in accordance with Section 3.3.10 for any
frequencies beyond what is presented in Table 7.
Table 7: Operating Frequency Range
Generator Size
≤ 30 kW
≥ 30 kW
Frequency Range (Hz)
Low Range
High Range
59.3
60.5
57.0-59.8
(adjustable set point)
60.5
* Source: IEEE 1547
3.2.2.6 Power Factor
i)
The preferred power factor range of operation is ±0.9.
ii)
EG Facilities > 30 kW shall be capable of operating in constant power factors anywhere
between 0.95 leading and 0.95 lagging.
iii)
EG Facilities ≤ 30kW shall not be required to adjust their power factor.
iv)
If warranted by local distribution system conditions (such as causing a violation of
CSA/CAN3-C235-83 voltage limits at the PCC), this range may be narrower or wider and
will be specified by PowerStream in the CIA.
v)
The EG Facility shall be capable of operating within lagging and leading power factor
ranges with or without other EG Facilities in service on the feeder.
vi)
PowerStream shall determine the required operating power factor of the EG Facility during
the CIA study and shall specify this to the EG Owner.
46
Embedded Generation
Technical Interconnection Requirements
Revision 0
vii)
Power factor correction or reactive power compensation techniques may be required.
viii)
Induction generators consume reactive power and the EG Owner shall be required to
provide reactive power compensation to correct the power factor at the PCC.
ix)
EG Facilities greater than 10 MW shall be assessed by the IESO to determine whether the
proposed connection is IESO-impactive and whether the reactive power compensation at
the generator units shall be sufficient so as not to cause any material increase in the reactive
power requirements at the transmission system transformer station due to the operation of
the EG Facilities at all load conditions on the feeder.
3.2.2.7 Limitation of DC Injection
i)
The DC current injection by the EG Facility shall not be greater than 0.5% of the full rated
output current at the PCC after a period of six cycles following the energization of
PowerStream’s Distribution System.
3.2.2.8 Voltage Regulation
i)
Voltage variations at the point of common coupling (“PCC”) are limited to +/- 6% of the
nominal voltage. The generation facility should not actively regulate the voltage at the PCC.
ii)
During normal operation, the generation facilities must be loaded and unloaded gradually to
allow adequate time for regulating devices to respond and avoid excessive voltage
fluctuation.
iii)
The generation facility shall not cause objectionable voltage and current unbalance
conditions. The generation facility shall not cause voltage unbalance beyond 3% and
current unbalance beyond 10% at the PCC.
3.2.3 Disturbances
i)
The EG Facility shall be designed, built and maintained in accordance with all
applicable codes, regulations and standards, along with the requirements of the TIR. The
design shall minimize the impact of:
a)
overvoltages during ground faults;
b)
electric disturbances which can cause irregular power flows;
c)
interference – radio, television and telephone;
47
Embedded Generation
Technical Interconnection Requirements
Revision 0
d)
audible noise; and
e)
other disturbances which may reduce the reliability of PowerStream’s distribution
system.
3.2.4 Resonance Analysis
i)
The prudent design of an EG Facility should include careful consideration of resonance and
ferroresonance.
ii)
Ferroresonance or resonance studies are not mandatory.
iii)
If resonance problems do arise, full co-operation and data sharing on the part of the EG
Owner shall be required.
3.2.5 Self-Excitation Analysis
i)
EG Facilities with induction generators and not equipped with Transfer Trip (Section
3.3.13) shall conduct studies to assess whether there is a possibility of self-excitation.
ii)
Self-excitation analysis, if required by Item (i) above, shall be submitted to PowerStream
for review.
3.3 Protection Requirements
3.3.1 General Requirements
i)
All protective device settings and protection scheme designs must be submitted to
PowerStream for review.
ii)
Protections must not be interlocked with the position of any isolating/interrupting devices.
iii)
Protection settings may be required to be changed over time to maintain adequate system
protection as the system configuration changes.
iv)
All protection operations shall ensure that the generator(s) and all HV Ground
Sources are isolated from PowerStream’s Distribution System within the required time from
the start of the disturbance.
v)
All protection designs must:
48
Embedded Generation
Technical Interconnection Requirements
Revision 0
a)
ensure proper coordination with PowerStream’s protections;
b)
be failsafe; and
c)
ensure that both the EG Facility and PowerStream’s distribution system, customers
and general public safety are maintained.
vi)
The design of the protections at the EG Facility shall be performed by a qualified
professional engineer to ensure that the overall protection scheme will ensure a safe and
reliable interconnection to PowerStream’s Distribution System.
vii)
Protection relays shall be “utility grade” and shall meet the minimum requirements
specified in IEEE C37.90, “Standard for Relays and Relay Systems Associated with
Electrical Power Apparatus,” latest edition as well as meet the requirements in
Section 3.1.20 and Section 3.1.21. “Industrial grade” relays shall not be permitted for the
interconnection protection.
viii)
Protection functions shall remain operational after distribution system disturbances or loss
of supply from the distribution system for the required period of time needed to operate
properly.
ix)
Communication facilities between PowerStream’s TS and recloser and the EG Facility may
be required as a result of EG Facility interconnections.
x)
The interconnection protection is required to have a dedicated device but if the EG Owner
decides to combine some of the protection functions in other relays, this would be subject to
PowerStream’s approval.
xi)
Additional protections other than the ones listed in the TIR may be required
depending on the application and shall be communicated to the EG Owner at the
appropriate stage.
3.3.2 Sensitivity and Coordination
i)
The EG Facility’s interconnection protection shall provide adequate sensitivity to
detect abnormal conditions as required in Section 2.3 and isolate its generator(s) and if
present, its HV ground source, from PowerStream’s Distribution System.
ii)
The design of the EG Facility’s interconnection protection system shall coordinate with
other PowerStream protection system devices.
49
Embedded Generation
Technical Interconnection Requirements
Revision 0
3.3.3 Protection Operating Times
i)
The EG Facility’s interconnection protection shall disconnect the EG Facility’s
generation and HV ground sources, if present, from PowerStream’s Distribution System
within the required time as specified in the individual requirements throughout the TIR.
3.3.4 Breaker Fail (BF)
i)
EG Facilities with an aggregate output > 500kW shall provide breaker failure
protection for the primary interrupting device (i.e. breaker, HVI, LVI) that is
responsible for disconnecting the generator and/or the HV ground sources from
PowerStream’s Distribution System.
ii)
The breaker failure protection should have a maximum pickup time delay of 0.3s after
initiation.
iii)
In the event of an HVI breaker fail condition, the breaker fail protection shall:
iv)
a)
trip the next zone at the EG Facility, specifically the upstream isolation device and
all LV breakers shall be tripped; and
b)
remove the prime mover and excitation system as appropriate.
In the event of an LVI breaker fail condition, the breaker fail protection shall ensure that a
fault in the EG Facility is cleared and will not affect the Distribution System by:
a)
tripping the HVI if an HVI exists;
b)
opening the motorized disconnect switch (Isolation Device) as explained in Item (vi)
below if an HVI does not exist;
c)
removing the prime mover and excitation system as appropriate.
v)
The motorized disconnect switch (see requirements in Section 3.1.7 Item (iii)(b)) shall be
opened by a separate auxiliary relay in the event of a breaker fail condition to ensure that
the EG Facility is properly isolated from PowerStream’s Distribution System.
vi)
The motorized disconnect switch shall be used to automatically isolate the EG Facility from
the distribution system. In the event that an alternate interrupting means (fuses or
otherwise) is not provided by the EG Facility or if such alternate interrupting means fail to
coordinate with the opening of the motorized disconnect switch, then the disconnect switch
may incur significant damage when attempting to interrupt a sustained fault current
50
Embedded Generation
Technical Interconnection Requirements
Revision 0
condition as it is not rated for breaking fault current. The design of the EG Facility shall
take this into consideration when deciding on a location for the Isolation Device to ensure
that safety of the EG Facility personnel, PowerStream’s personnel and general public will
be ensured.
vii)
In the case of a circuit switcher being used, the interrupter and the motorized
disconnect shall be specifically chosen to operate independently and no additional BF
protection shall be required. If the motorized disconnect switch in the circuit switcher is not
rated to break load, an additional load break switch shall be required to satisfy the
requirement in Section 3.1.7.
viii)
The design of the BF protection for the HVI shall be submitted to PowerStream for review
and acceptance.
ix)
EG Facilities ≤ 500kW shall be exempted from Items (i) through (viii) above, but shall have
an alternate means of disconnecting the EG Facility generation energy source from the
Distribution System when the associated breaker fails to open for any interconnection
protection operations. This can be achieved by the opening of the isolation device, disabling
an inverter, or by removing the prime mover and excitation system as appropriate.
3.3.5 Single Phase Generators
i)
Minimum protection requirements for single phase EG Facilities shall be in
accordance with Table 8 below and are mandatory for all generators to which this TIR
document is applicable.
ii)
Inverter type generators shall be compliant with CSA Standards, C 22.2-107.1
“General use Power Supply” and CAN/CSA 22.2 No 257-06 “Interconnecting inverter
based micro distributed resources to distribution system” and bear a certification mark
recognized by the Ontario Electrical Safety Code.
iii)
The final design of the protection system shall be submitted to PowerStream for
approval in accordance with Section 3.3.19 of the TIR.
Table 8: Minimum Protections Required for Single Phase EG Facilities
Protection Description
Interconnect Disconnect Device
Generator Disconnect Device
Over-Voltage Trip
IEEE Device #
89
59
51
Embedded Generation
Technical Interconnection Requirements
Revision 0
Under-Voltage Trip
Over Frequency Trip
Under Frequency Trip
Overcurrent**
Distance ***
Synchronizing Check*
Anti-Islanding Protection
Additional Protections May Be Required
27
81O
81U
50/51
21
25
Refer to Section 3.3.12
* Only required for synchronous generators and other types which have standalone
capability
** Could be provided by magnetic circuit breaker or fuse
*** Distance may be required to be able to detect faults along the entire length
of the feeder
3.3.6 Three Phase Generators
i)
Three Phase EG Facilities shall have the minimum protection requirements as shown below
in Table 9 and are mandatory for all generators to which the TIR is applicable.
ii)
Inverter type generators shall be compliant with CSA Standards, C 22.2-107.1
“General use Power Supply” and CAN/CSA 22.2 No 257-06 “Interconnecting inverter
based micro distributed resources to distribution system” and bear a certification mark
recognized by the Ontario Electrical Safety Code.
iii)
All three-phase EG Facilities, including those using multiple three-phase inverters or
multiple single-phase inverters, shall meet the following conditions
iv)
a)
be able to maintain a balanced 3-phase output under all operating conditions;
b)
be able to detect the loss of voltage in one or more phases of PowerStream’s
distribution system and automatically cease to energize all phases from the
interconnected system; and
c)
be able to detect the loss of voltage in one or more phases of the EG Facility’s
electric power production source and automatically cease to energize all phases
from the interconnected system.
The final design of the protection system shall be submitted to PowerStream for
approval in accordance with Section 3.3.19 of the TIR.
52
Embedded Generation
Technical Interconnection Requirements
Revision 0
53
Embedded Generation
Technical Interconnection Requirements
Revision 0
Table 9: Three-Phase Minimum Protection Requirements
Function
Requirement
Basic AntiIslanding
Element function
Over-Voltage
Under-Voltage
Over-Frequency
Under-Frequency
Transfer Trip Receive
EGEO
Other passive Anti- Rate of Change of
Frequency (ROCOF)
islanding
Vector Surge
(Application
Directional Reactive
Specific)
Power Relay 17
Phase Over-current
Phase Inverse Timed
Over-current 18
Phase Fault
Protection
Voltage Controlled
Over-current 18, 19
Directional Phase
Over-current 20
Phase Distance 19, 20
Under-Voltage 21
Neutral Over-current
Neutral Inverse Timed
Over-currentNeutral
18
Directional
Ground
Over-current 20
Fault
Protection
Ground Distance 19, 20
Tele-protections
Under-Voltage 21
Ground Overvoltage 22
Open Phase and
Phase Unbalance
Ferro-resonance
Synchronization
Device
59
27
81O
81U
Synchronous
Req.
Req.
Req.
Req.
Inverter
Req.
Req.
Req.
Req.
Req.
Req.
Req.
Req.
TTR
EGEO
81R
see Section
see Section
≤ 500 kW
78
32R
≤ 500 kW
≤ 500 kW
17
Req.
See 18
50
51
Induction
Section
see Section see Section
see Section see Section
≤ 500 kW Not req 16
See 18, 19
See 18, 19
See 18, 19
67
Req. 20
Req.20
Req. 20
21
27
50N
51N
67N
See 19, 20
See 21
Req.
See 18
Req. 20
See 19, 20
See 21
Req.
See 18
Req. 20
See 19, 20
See 21
Req.
See 18
Req. 20
21N
See 19, 20
See 19, 20
See 19, 20
27
59G
See 21
Req. 22
See 21
Req. 22
See 21
Req. 22
3.3.9,
3.3.11 iii)
3.3.12
3.3.13
3.3.11 iv)
≤ 500 kW Not req
≤ 500 kW Not req
17
Req.
Req.
See 18
See 18
51V
3.3.10,
3.3.11 iii)
3.3.7
Negative Sequence
Current
Negative Sequence
Voltage
46
See Section
See Section
See Section
47
See Section
See Section
See Section
Peak detecting
Overvoltage
Synchronizing
59I
See 23
See 23
See 23
25
Required
See Section
See Section
3.2.2.2
3.3.8
3.3.8
54
3.4.4
Embedded Generation
Technical Interconnection Requirements
Revision 0
14
All protection element functions must be shown on Single Line Diagrams
15
Three-phase EG Facilities up to 500kW comprised of a single three-phase inverter unit that is CSA certified and bears a certification
mark recognized by OESC shall be deemed compliant to Table 10. EG Facilities that consist of multiple three-phase inverters or multiple
single-phase inverters shall comply with Section 3.3.6 of the TIR.
16
Other passive anti-islanding protection functions may not be required if inverters have active anti-islanding controls
17
Directional Reactive Power relay is an alternative to 78 (Vector Surge) provided that there is a predictable reverse reactive power flow
for island conditions
18
An alternative or complement to Over-current (50, 50N). Special caution is needed for selection of inverse-time characteristics that
meet time constraints
19
May be used to provide distinction between normal load and feeder-end fault conditions when basic over-current (50, 50N) is
insufficient
20
May be used to provide distinction between internal and external faults for the reconnection of EG Facility
21
May be used to provide fault protection for EG Facilities where fault current in-feed levels are too small for practical detection by overcurrent or distance elements
22
Required for EG Facilities that do not contribute ground current to ground faults on PowerStream’s distribution system
3.3.7 Phase and Ground Fault Protection
i)
The EG Facility’s interconnection protection shall ensure that the EG Facility will detect
and isolate itself and any HV ground sources from PowerStream’s Distribution System for:
a)
All internal faults within the EG Facility; and
b)
All external faults on the interconnected feeder including single phase lateral taps.
This applies to all phase-phase and phase-ground faults.
ii)
Phase and ground protections shall always be operational whenever phase and ground
current can be sourced from the EG Facility.
iii)
The protective device selectivity and sensitivity shall be maintained over the full range of
minimum to maximum fault currents (present and anticipated future levels) with the EGs
infeed.
iv)
The EG Facility shall be capable of selectively detecting faults on the EG Facility side of
the HVI, and shall disable the HVI auto-reclosure scheme – Refer to Section 3.4.7.
v)
The total clearing time for faults on PowerStream’s Distribution System or for faults in the
EG Facility shall be no more than:
a)
500ms for EG Facilities equipped with fast Transfer Trip; or
b)
200ms for EG Facilities not equipped with fast Transfer Trip. This can be relaxed to
500ms if the EG Owner can demonstrate that the EG Facility fault contributions will
not encroach on PowerStream’s Distribution System minimum fuse melt
characteristic.
55
Embedded Generation
Technical Interconnection Requirements
Revision 0
[Note: The total clearing time is measured from the start of the abnormal condition to the
time that the EG Facility ceases to energize PowerStream’s Distribution System].
3.3.8 Phase Loss Protection
i)
ii)
The EG Facility’s interconnection protection must be capable of detecting the loss of any
phase to which the EG Facility is connected which occurs within the EG Facility or on the
interconnected feeder.
Upon the detection of the open-phase condition the EG protection shall:
a)
Disconnect the generation from the Distribution System within 500ms
3.3.9 Over Frequency/Under Frequency Protection
i)
The EG Facility’s interconnection protection scheme shall have the capability of
detecting abnormal frequencies shown below in Table 10.
ii)
The EG Facility shall disconnect from PowerStream’s Distribution System in the clearing
times specified in Table 10.
iii)
The clearing time in Table 10 shall be measured from the start of the abnormal condition
until the time that the EG Facility ceases to energize PowerStream’s Distribution
System.
iv)
More stringent clearing times may be specified in the CIA if required.
v)
EG Facilities > 30kW shall have the frequency set point field adjustable.
vi)
EG Facilities ≤ 30kW shall have the frequency set point either fixed or field
adjustable.
vii)
EG Facilities ≥ 1MW shall have the lower frequency set points set to comply with the
NorthEast Power Coordinating Council (NPCC) “Directory D12”.
viii)
EG Facilities > 10MW shall follow the frequency set points and clearing times
specified by the IESO’s SIA.
Table 10: Over/Under Frequency Protection Set Points and Clearing Times
56
Embedded Generation
Technical Interconnection Requirements
Revision 0
Generator
Size
≤ 30 kW
> 30 kW
Frequency Range (Hz)
Clearing Times(s)*
> 60.5
< 59.3
> 60.5
< (59.8 – 57.0) - adjustable
< 57.0
0.16
0.16
0.16
Adjustable 0.166 to 300
0.16
* Generators ≤ 30kW – Maximum clearing time
* Generators > 30kW – Default clearing time
Source: IEEE 1547
3.3.10 Overvoltage/Undervoltage Protection
i)
The EG Facility’s interconnection protection scheme shall have the capability of
detecting abnormal voltages shown in Table 11.
ii)
The EG Facility shall disconnect from PowerStream’s Distribution System in the clearing
times specified in Table 11.
iii)
Voltage shall be measured:
a)
phase-neutral for single phase installations;
b)
phase-neutral for grounded Wye-Wye transformer configurations; or
c)
phase-phase for all other installations.
iv)
The voltages shall be detected at the PCC.
v)
If the requirement in Item (iv) above is not practical or feasible, estimated values may be
used if approved by PowerStream.
vi)
The clearing time in Table 11 shall be measured from the start of the abnormal condition
until the time that the EG Facility ceases to energize PowerStream’s Distribution
System.
vii)
More stringent clearing times may be specified in the CIA if required.
viii)
EG Facilities > 30kW shall have the voltage set point field adjustable.
ix)
EG Facilities ≤ 30kW shall have the voltage set point either fixed or field adjustable.
x)
Undervoltage relays should be time-delayed to avoid unnecessary tripping while overvoltage relays may be instantaneous.
57
Embedded Generation
Technical Interconnection Requirements
Revision 0
xi)
High speed instantaneous voltage protection may be considered for detecting
ferroresonance and self-excitation conditions.
xii)
EG Facilities > 10MW shall follow the voltage set points and clearing times specified by
the IESO’s SIA.
Table 11: Over/Under Voltage Protection Setting and Clearing Time
Voltage Range (% of base voltage) Clearing Time(s)*
V < 50
0.16
50 ≤ V < 88
2.00
110 < V < 120
1.00
V ≥ 120
0.16
* EG ≤ 30 kW – Maximum clearing time Source: IEEE 1547
* EG > 30 kW – Normal clearing time
3.3.11 Anti-Islanding Protection
i)
Upon loss of voltage in one or more phases of PowerStream’s Distribution System, the EG
Facility shall automatically disconnect from PowerStream’s Distribution System within
500ms.
ii)
The EG Owner shall demonstrate to PowerStream that it shall not sustain an island for
longer than the time requirements in Item (i) above.
iii)
All EG Facilities shall have anti-islanding protection. This may involve different protection
functions, however all EG Facilities shall have:
a)
Under/Over Frequency protection (Section 3.3.10);
b)
Under/Over Voltage protection (Section 3.3.11); and
c)
Transfer Trip for anti-islanding protection may be required as stipulated in Section
3.3.13.
3.3.12 Transfer Trip
i)
A Transfer Trip (TT) signal from the station feeder breaker(s) to the EG Facility shall be
required for all EG Facilities whose aggregate capacity is 1 MW or larger.
58
Embedded Generation
Technical Interconnection Requirements
Revision 0
ii)
A Transfer Trip (TT) signal from the feeder breaker(s) and/or upstream recloser(s) (where
the recloser is located between the EG Facility and feeder breaker) to the EG Facility shall
be required for any or all of the following conditions:
a)
When the aggregate EG Facility capacity is greater than 50% of the minimum feeder
load or the minimum load downstream of recloser(s); or
b)
When the aggregate generation, comprising of existing generation, other earlier
proposed EG Facilities, and the concerned EG Facility is greater than 50% of the
minimum feeder load or minimum load downstream of the recloser; or
c)
If the existing reclosing interval of the feeder breaker(s) and/or upstream recloser(s)
is less than 1.0s.
iii)
A Transfer Trip (TT) signal from upstream feeder breaker(s) and/or recloser(s) to the EG
Facility connected at downstream of Municipal Station (MS) supplied by that feeder shall
be required. This is required when the aggregate generation comprising of existing
generation, other earlier proposed EG Facilities, at the feeder or at the MS including
concerned EG Facility is greater than 50% of minimum feeder load or the minimum load
downstream of recloser respectively.
iv)
A Transfer Trip (TT) signal from transmission line terminal breaker(s) of an upstream
Transformer Station (TS) to the EG Facility shall also be required if the TS where the EG
Facility is being proposed is radially supplied by that transmission line and there is a
possibility of islanding of the entire transmission line, or where Wide area islands could
exist – aggregate generation on transmission line is greater than 50% of the minimum load
on the transmission line. This signal will be cascaded onto the TT signal that will be
required between the TS feeder breaker and the EG Facility in Item (ii) above.
v)
The EG Facility shall cease to energize PowerStream’s Distribution System with no
intentional time delay and isolate all generation and HV ground sources upon receipt of a
Transfer Trip signal.
vi)
Transfer Trip communications shall meet the timing requirements in Table 12. The
maximum TT time shall depend on the operational speed of the EG Facilities interrupting
device.
Table 12: TT Timing Requirements
59
Embedded Generation
Technical Interconnection Requirements
Revision 0
Maximum TT
Communication Time
(ms)
83
67
50
33
17
Speed of EG Facility`s
Interrupting Device
(cycles)
3
4
5
6
7
vii)
The EG Facility shall remain disconnected from PowerStream’s Distribution System if the
Transfer Trip (TT) channel is unavailable.
viii)
The Transfer Trip (TT) teleprotection system shall be failsafe.
ix)
Upon loss of the Transfer Trip (TT) communication channel, the generation and HV ground
sources shall disconnect within 5 seconds of the channel failing. A controlled shutdown
may be allowed and must be submitted to PowerStream for approval.
x)
The EG Facility shall remain disconnected until the Transfer Trip (TT) channel is repaired
and PowerStream’s Controlling Authority has been advised that all EG Facility
interconnection protections have been restored to service.
xi)
EG Facilities with an aggregate capacity of 500kW and less, may be exempted from Items
(ii) and (iii) above and permitted to use passive anti-islanding protections in accordance
with Section 3.3.12 Item (iv).
3.3.13 Embedded Generator End Open (EGEO)
i)
An Embedded Generator End Open (EGEO) real-time signal from the EG Facility to
PowerStream is required whenever Transfer Trip is required, as outlined in Section 3.3.13.
ii)
The EGEO signals shall be combined into one composite communications channel signal as
outlined in the EGEO Design Requirement in Section 3.3.16.
iii)
Upon failure of the EGEO channel, PowerStream may block its feeder reclosing until the
channel is repaired.
iv)
The EG Owner shall make repairs in the event of channel failure as quickly as possible.
v)
In the event of Item (iii) above, PowerStream can seal in Transfer Trip to the affected EG
Facility until the channel is repaired to enable automatic reclosing on its feeders.
60
Embedded Generation
Technical Interconnection Requirements
Revision 0
3.3.14 Special Interconnection Protection
i)
Other protections not specified in this requirements document may be required
depending on the application.
ii)
The EG Owner shall be aware of site specific conditions and the nature of PowerStream’s
Distribution System to properly assess the need for additional protections.
3.3.15 Protection Scheme Failures
i)
The EG Facility generation and HV ground sources shall be disconnected from
PowerStream’s Distribution System and notify PowerStream’s Controlling Authority if:
a)
The EG Facility’s local interconnection protection system fails;
b)
The breaker trip coil or interrupting device fails;
c)
The DC supply is lost; or
d)
The TT signal channel fails.
ii)
Alarm Telemetry shall be provided to PowerStream directly from the EG Facility as
required in Section 3.4.
iii)
With the exception of Item (i)(d) above, disconnection shall be automatic and
immediate (no intentional time delay).
iv)
Disconnection following TT signal failure shall be automatic but can be delayed as outlined
in Section 3.3.12 Item (ix).
v)
PowerStream may send TT to the EG Facility following a EGEO signal failure as outlined
in Section 3.3.13 Item (v).
vi)
The device(s) used to disconnect the generation shall remain open until such a time when
the affected system is returned to normal service condition and the EG Facility is safe for
reconnection to PowerStream’s distribution system.
vii)
The interconnection protection design submitted to PowerStream during the implementation
phase of the Connection Process shall provide sufficient detail to ensure that the protection
scheme failure requirements outlined in Item (i) above are addressed.
61
Embedded Generation
Technical Interconnection Requirements
Revision 0
viii)
In designs where self-diagnostic features do not trip the appropriate breakers upon failure,
sufficient backup and/or redundancy protections shall be provided.
ix)
If electro-mechanical relays are used, the protection and control design shall be of a failsafe nature to ensure the integrity of the protection scheme under malfunctioning
conditions.
3.3.16 Interconnection Protection Acceptance
i)
The EG Owner shall provide PowerStream with complete documentation on the proposed
EG Facility’s interconnection protection scheme to ensure compliance with the
requirements of the TIR and all applicable standards. Documentation shall include, but is
not limited to:
a)
a detailed Single Line Diagram;
b)
an overall description on how the protection will function;
c)
a description on failure modes;
d)
detailed engineering drawings that includes design details on protection and control,
teleprotection and telemetering schemes and components including manufacturer
and model #;
e)
the protection element settings (pickup, timers, etc.);
f)
details on monitoring for the protection system performance (DFR, SER, and
telemetry);
g)
details on backup supply to any critical loads;
h)
details on the Breaker Failure protection if required by Section 3.3.4; and
i)
details on the disconnecting and interrupting device.
ii)
If PowerStream proposes any changes from the review in Item (i) above, the EG Owner
shall revise and re-submit the protection information to PowerStream.
iii)
All documentation must be submitted together.
iv)
The latest submissions will be filed by PowerStream and MUST MATCH the
documentation retained by the EG Owner.
62
Embedded Generation
Technical Interconnection Requirements
Revision 0
3.3.17 Protection Changes
i)
The EG Owner shall obtain PowerStream’s prior written approval of all:
a)
interconnection equipment replacements;
b)
design modifications; and
c)
setting changes.
ii)
Any changes without prior approval shall be deemed a violation of Connection
Agreement (CA) and may result in immediate disconnection from PowerStream’s
Distribution System.
3.4
OPERATING REQUIREMENTS
3.4.1 General
i)
Switching that involves manual operation of air break switches shall require all
connected EG Facilities to disconnect their generation from the system as directed by the
Controlling Authority.
ii)
In the event that the source configuration changes, other than what was studied in the EG
Owner’s CIA or listed in their Connection Agreement, all connected EG Facilities shall
disconnect their generation from the distribution system as directed by the Controlling
Authority. It shall be the EG Owner’s responsibility to ensure that their protections are
capable of detecting all external faults.
iii)
Any temporary feeder parallels shall require that all connected EG Facilities to come offline as directed by PowerStream’s Control Room.
iv)
Transfer Trip and EGEO communications shall be required for EG Facilities that are 1 MW
and larger connecting to PowerStream’s Distribution System at voltages less than 50 kV.
v)
For feeders with multiple feeder reclosers, 50% minimum feeder load calculations shall
identify remaining loading levels with reclosers in open position.
vi)
The EG Facility shall parallel with PowerStream’s Distribution System without causing a
voltage fluctuation at the PCC greater than ± 4% of the prevailing voltage level of the
distribution system at the PCC and meet the flicker requirements in Section 3.2.2.3.
63
Embedded Generation
Technical Interconnection Requirements
Revision 0
vii)
The EG Facility (synchronous and permanent magnet generators) shall remain in
synchronism with PowerStream’s Distribution System while operating in parallel to
PowerStream’s Distribution System. The EG Facility is expected to have loss-of-field
protection as part of the generator protection to quickly disconnect the generator should the
excitation to the generator fail.
viii)
No automatic reconnection to the system shall be allowed unless:
a)
there is always contact with the EG Owner or EG Facility operator who has the
ability to immediately disconnect the EG Facility from the system if requested by
the Controlling Authority (24 hours/7 days per week); or
b)
the Distributor’s Controlling Authority has the ability to remotely disconnect the EG
Facility from the system, and
c)
feeder relay studies must be updated if circuit configuration is materially altered. If
the source changes from the configuration studied in the CIA, the generator will not
be allowed to reconnect.
ix)
Automatic Reconnection to PowerStream’s distribution system shall be locked out once
voltage and frequency are not within operating ranges for a period of 15 minutes on any
phase for any EG Facilities limited to one connection path if stipulated in their Connection
Agreement.
x)
Legacy EG Facilities need to meet the operating requirements of the TIR.
3.4.2 Islanding
i)
Intentional islanding is not allowed at this time.
ii)
Islanding detection and protection is required as per Section 3.3.11.
3.4.3 Unintentional Energization
i)
The EG Facility shall not energize PowerStream’s Distribution System when the
distribution system is de-energized.
64
Embedded Generation
Technical Interconnection Requirements
Revision 0
3.4.4 Synchronization
i)
Any EG Facility that is capable of generating its own voltage while disconnected from
PowerStream’s Distribution System shall require proper synchronization facilities before
connection is permitted.
ii)
Interconnection shall be prevented if the EG Facility and PowerStream’s Distribution
System are operating outside the limits specified in Item (iii) below.
iii)
Synchronous generators, self-excited induction generators or inverter-based generators that
produce fundamental voltage before the paralleling device is closed shall only parallel with
PowerStream’s Distribution System when the frequency, voltage, and phase angle
differences are within the ranges given below in Table 13 at the moment of
synchronization.
Table 13: Resynchronization Requirements
Aggregate
Rating of
Generators
(kVA)
Frequency
Difference
(Δ f, Hz)
Voltage
Difference
(Δ V, %)
Phase Angle
Difference
(Δ Φ, )
0-500
>500 – 1500
>1500
0.3
0.2
0.1
10
5
3
20
15
10
* Source: IEEE 1547
iv)
For synchronous generators, an approved automatic synchronization device shall be
required if the plant is unattended (IEEE device number 25) to ensure that the EG Facility
will not connect to an energized feeder out of synchronism.
v)
Induction generators and inverter-based generators that do not produce fundamental voltage
before the paralleling device is closed, and double-fed generators whose excitation is
precisely controlled by power electronics to produce a voltage with magnitude, phase angle,
and frequency that match those of the distribution system may not require synchronization
facilities.
vi)
Any proposed synchronizing scheme shall be submitted to PowerStream prior to installation
and shall be able to accommodate automatic reclosing on PowerStream’s distribution
facilities.
65
Embedded Generation
Technical Interconnection Requirements
Revision 0
3.4.5 Single Connection Path
i)
The requirements in Items (ii), (iii) and (v) below shall apply to EG Facility
connections which have a restriction to only a single connection path (normal
configuration) as stipulated in their Connection Agreement.
ii)
EG Facility generation connection shall be restricted only to the “normal Distribution
System supply configuration” and when all required protection and control systems
required for safe and reliable connection to the Distribution System are operational.
iii)
Upon request the EG Facility connection can be approved for “Alternate Grid
Connection Path” if deemed acceptable by PowerStream. An additional assessment on
Distribution System supply configurations shall be required.
iv)
The CIA and Connection Agreement shall clearly identify the Distribution System supply
configuration studied and determined to be acceptable for safe and reliable EG Facility
connection in accordance with Item (i) above.
v)
If an alternate configuration exists and if Item (ii) above applies to the EG Facility, then the
EG Facility shall be disconnected until the normal configuration is restored.
3.4.6 Automatic Disconnection of Generation and HV Ground Sources
i)
All EG Facility generation and sources of ground current shall be automatically
disconnected from the Distribution System whenever the EG Facility’s interconnection
protection or TT operates, as required by the other sections in the TIR. The timing
requirements for automatic disconnection are detailed below in Items (ii), (iii), (v), (vi) and
(vii).
ii)
For those EG Facilities that require TT, all generation shall be disconnected
immediately (without any intentional delay) upon the receipt of a TT signal from
PowerStream.
iii)
For those EG Facilities that require TT, all generation shall be disconnected within 500ms
of when external faults are detected on the Distribution System by the EG Facility’s
interconnection protection.
iv)
For those self-clearing EG Facilities that do not require TT, all generation shall be
disconnected within 200ms of the start of the abnormal condition on the Distribution
System by the EG Facility’s interconnection protection.
66
Embedded Generation
Technical Interconnection Requirements
Revision 0
v)
All sources of EG Facility generation shall be disconnected within 500ms when the EG
Facility Anti-islanding Protection operates.
vi)
All three-phase EG Facility ground sources shall be disconnected within 500ms if any of
the items (ii) to (v) above operates.
vii)
A back-up means shall be provided for disconnecting the EG Facility generation and all
grounded EGIT or HV grounding transformers that provide a ground return path for ground
faults on the HV side of the EGIT, should the interrupting device fail.
3.4.7 Automatic Reconnection of Generation
i)
EG Facility shall not be automatically reconnected to the Distribution System until the
Distribution System voltage is stabilized within 6% of nominal and the frequency is
between 59.5Hz and 60.5Hz, for a definite time period defined in Item (vi) below.
ii)
Automatic reconnection of the EG Facility shall include an adjustable delay that may delay
the reconnection for 5 minutes.
iii)
Additional requirements listed in Section 3.2.2.3 and Section 3.4.4 shall be met for this
automatic reconnection following a momentary outage to occur.
iv)
Should restoration attempts of PowerStream source to the Distribution System fail to reestablish stable voltages within 15 minutes, automatic reconnection of the EG Facility shall
be disabled.
v)
For all EG Facilities with a limit to connect through only one “normal configuration” path
in accordance with their Connection Agreement, PowerStream’s Controlling Authority
shall give permission to the EG Facility operators to manually reconnect when stable
voltages have not been restored within 15 minutes. No automatic reconnection shall take
place after the 15 minutes.
3.4.8 Reconnection of Generation Following a Sustained Outage or Shutdown
i)
No automatic reconnection of the EG Facility shall occur following a sustained outage or
shutdown – when the voltage and/or frequency out of normal operating range on any phase
for more than 15 minutes for any EG Facilities limited to one connection path if stipulated
in their Connection Agreement. Permission to reconnect shall be given by PowerStream’s
Controlling Authority in accordance with the terms of the Connection Agreement.
67
Embedded Generation
Technical Interconnection Requirements
Revision 0
3.4.9 Remote Monitoring and Control
i)
EG projects >100kW in size will be required to have remote monitoring and control
capability in place. For specific requirements, please refer to the Remote Monitoring
Information Package in Appendix 4(i). The following is a list of basic monitoring and
control provisions required for each Embedded Generation program.
3.4.9.1 Control Requirements
i)
Generators >100kW in size connected to the PowerStream Distribution System are
required to provision for real time monitoring and control to PowerStream. Provision will
include, but is not limited to, the ability to remotely dispatch the generator (on/off)
3.4.9.2 Monitoring Requirements
i)
Generators >100kW in size connected on the PowerStream Distribution System are
required to provision for real time monitoring to PowerStream. Provision will include,
but is not limited to, the following:
The inverter is required to provide remote monitoring equipment for monitoring of:
a)
b)
c)
d)
Voltage
Current
Real and reactive power
Circuit breaker status
ii)
Remote monitoring data to be provided via DNP3 or Modbus over Ethernet protocol via
Ethernet data port. If Ethernet is not available, then a serial data port using Modbus or
DNP3 data protocol. Data to be transmitted to PowerStream via customer supplied RTU
and WiMax 1.8Ghz radio, as specified in the PowerStream Remote Monitoring Information
Package and PowerStream Remote Monitoring Control Form.
iii)
Note: For EG Facilities connecting to the Distribution System via an embedded feeder,
PowerStream may provide real-time operating information to the LDC that owns the
Embedded Feeder. For EG Facilities connecting to the Distribution System via an
embedded feeder that are not monitored by PowerStream, the EG Owner may be required to
provide monitoring to the LDC that owns the embedded feeder.
iv)
EG Facilities are expected to have functioning Remote Monitoring systems prior to
generation connection to the grid. In the event of a monitoring system breakdown, it is
expected that the EG Owner will have the link repaired within 3 days of the failure.
68
Embedded Generation
Technical Interconnection Requirements
Revision 0
3.5 Metering Requirements
Metering requirements vary with the type and intent of the EG Facility. Please consult the IESO
Market Rules and Section 5 of the Distribution System Code for details.
3.6 Maintenance Requirements
3.6.1 Protection and Control Systems Equipment
Both the EG Owner and PowerStream shall ensure that inspection and testing are performed in
accordance with the following:
i)
The EG Owner shall ensure that only Qualified Personnel carry out all inspection and
testing of equipment after the Ownership Demarcation Point, and the Distributor shall
ensure that only Qualified Personnel carry out all inspection and testing of equipment up to
the Ownership Demarcation Point.
ii)
The protective relaying at the EG Facility should be re-verified once every four (4) years by
the EG Owner and a written report confirming this re-verification provided to PowerStream
each time. The EG Owner shall make advance notice of this re-verification to PowerStream
so that PowerStream can make arrangements to witness the re-verification. This witnessing
will be at the discretion of PowerStream and the costs of the witnessing shall be borne by
PowerStream.
iii)
The supply feeder shall be operated on a regularly scheduled basis to confirm its operation
and the functioning of the associated protection schemes.
iv)
The EG Facility shall be visually inspected at least once per year to note obvious
maintenance problems such as broken insulators or other damaged equipment.
v)
Any deficiencies identified during inspections should be noted and repairs scheduled as
soon as possible, with timing dependent on the severity of the problem, due diligence
concerns (of both PowerStream and the EG Owner) and financial and material
requirements.
vi)
PowerStream shall be notified of any deficiencies involving critical protective equipment,
including all protections which trip PowerStream’s 27.6kV feeder breaker.
69
Embedded Generation
Technical Interconnection Requirements
Revision 0
4.
Glossary of Terms
In addition to the Glossary of Terms in the Conditions of Service document, this reference
document contains a variety of terms that are defined in the context of Embedded Generation.
Some terms are duplicated.
Sources for definitions:
A
MR
DSC
RSC
Electricity Act, 1998, Schedule A, Section 2, Definitions
Market Rules for the Ontario Electricity Market, Chapter 11, Definitions
Distribution System Code Definitions
Retail Settlement Code Definitions
Term
Definition
Anti-Islanding
A protection system aimed at detecting islanded conditions (see
island) and disconnecting the EG Facility from the Distribution
System if an island forms
AVR
Automatic Voltage Regulator
BF
Breaker Fail
Breaker
Fault Interrupting Device: this may be a breaker, circuit
switcher, HVI, LVI
Business Day
Any day that is not a Saturday, a Sunday, or a legal holiday in
the Province of Ontario;
Capacity Allocation Exempt
Small Embedded Generation
Facility
A project which is not a microFIT project and has a nameplate
capacity of:
a) 250kW or less connected to less than 15kV system
b) 500kW or less connected to greater than 15kV system
CCE
Connection Cost Estimate
CEA
The Canadian Electricity Association
CIA
A Connection Impact Assessment is a detailed assessment of a
70
Embedded Generation
Technical Interconnection Requirements
Revision 0
project's impact on the grid. The results include a technical
report outlining project feasibility, technical specifications
needed for the project and the impacts the project would have
on the distribution system.
Class 1
EG Facility aggregate capacity at PCC ≤ 250kW
Class 2
250kW < EG Facility aggregate capacity at PCC < 1500kW
Class 3
1.5MW ≤ EG Facility aggregate capacity at PCC ≤ 10MW
Class 4
EG Facility aggregate capacity at PCC > 10MW
Closed-transition
Transferring load from the distribution system to the EG
momentarily and then operating in stand-alone (emergency)
mode or transferring load from the EG back to the
distribution system momentarily. A closed-transition transfer is
also referred to as a make- before-break transfer. The
momentary interconnection of a EG system to the distribution
system for 100 ms or less provided both sources are
synchronized
CO
Central Office: a local telephone company office that
provides a central point for the termination of
telecommunication lines and trunks, and where they can be
interconnected.
Coefficient of grounding - is
defined as 100% x ELG/ELL
where:
ELG is the highest rms, line-to-ground, power-frequency
voltage, on a sound phase, at a selected location, during a lineto-ground fault affecting one or more phases.
ELL is the line-to-line power-frequency voltage that would be
obtained, at a selected location, with the power fault
removed. COG for three-phase systems are calculated from the
phase-sequence impedance components, as viewed from the
fault location.
71
Embedded Generation
Technical Interconnection Requirements
Revision 0
COG
Connection Agreement
The COG is useful in the selection of a surge arrester rating for
a selected location
The EG Owner is required to enter into a Connection
Agreement with PowerStream prior to exporting electricity
onto the Distribution System
Controlling Authority
The entity responsible for performing, directing, or authorizing
changes in the conditions or physical position of certain
Apparatus or Devices.
COVER
Confirmation of Verification Evidence Report
CSA
The Canadian Standards Association
Day
A calendar day unless specifically stated otherwise
DESN
Dual Element Spot Network – Type of TS
DCA
Distribution Connection Agreement
Demarcation Point
The point at which PowerStream’s equipment ends and another
party’s equipment begins.
DFR
Disturbance Fault Recorder
EG
See Embedded Generation
EGEO
Embedded Generator End Open: a signal used to confirm the
status of the generator breaker – used to prevent out-of-phase
reclosing onto the generator
*Formerly referred to as EGEO – Embedded Generator End
Open
EG Facility
All equipment including generators, transformers, protections,
and line on the EG Facility side of the PCC
72
Embedded Generation
Technical Interconnection Requirements
Revision 0
EGIT or EG Interconnection
Transformer
The transformer used to step up the voltage from the EG
to distribution voltage levels.
EG Owner
A person who owns or operates a generation facility.
Embedded Generation
Facility
A generation facility which is not directly connected to the
IESO- controlled grid but instead is connected to a distribution
system, and has the extended meaning given to it in Section 1.9
Embedded Wholesale
Consumer
A Consumer who is a wholesale market participant whose
facility is not directly connected to the IESO-controlled grid but
is connected to a distribution system (DSC)
Embedded Generation
Technical Interconnection
Requirements
This document as well as any updates of technical
interconnection requirements in the form of bulletins and/or
amendments that are published periodically by PowerStream on
its website.
Emergency Backup
Generation Facility
A generation facility that has a transfer switch that isolates it
from a distribution system
Enhancement
A modification to the main distribution system that is made to
improve system operating characteristics such as reliability or
power quality or to relieve system capacity constraints
resulting, for example, from general load growth, but does not
include a renewable enabling improvement;
Expansion
A modification or addition to the main distribution system in
response to one or more requests for one or more additional
Customer connections that otherwise could not be made, for
example, by increasing the length of the main distribution
system, and includes the modifications or additions to the
main distribution system identified in Section 3.2.30 but in
respect of a renewable energy generation facility excludes a
renewable enabling improvement
73
Embedded Generation
Technical Interconnection Requirements
Revision 0
Distribution Lines
Distribution System lines that operate at nominal
line-line voltages below 27.6 kV.
Distribution System
Any power line facilities under the operating
authority of the Wires owner (PowerStream or LDC)
that operate at nominal line-line voltages of 50 kV or
below. This includes sub-transmission power lines
that operate at 27.6 kV or 44 kV and distribution
lines that operate at voltages below 27.6 kV.
Distributor
The electric utility owning or operating the
distribution lines.
DNP 3.0
Distributed Network Protocol
DO
Drop Out
MS
An electrical station that is used to step down a subtransmission voltage to a distribution voltage for distribution to
the end use customer.
DSC
Distribution System Code
Effectively Grounded
A system grounded through a sufficiently low impedance so
that COG does not exceed 80%. This value is obtained
approximately when, for all system conditions, the ratio of the
zero-sequence reactance to the positive-sequence reactance
(X0/X1) is positive and ≤ 3, and the ratio of zero-sequence
resistance to positive-sequence reactance (R0/X1) is positive
and < 1.
Embedded LDC
A distributor who is not a wholesale market participant
and is provided electricity by a host distributor.
74
Embedded Generation
Technical Interconnection Requirements
Revision 0
EMI
Electromagnetic Interference
ESA
Electrical Safety Authority
Essential Loads
Part of the load that requires continuous quality electric power
for its successful operation or devices and equipment whose
failure to operate satisfactorily jeopardizes the health or safety
A
or three-phase
emanating
from financial
a substation
of single-phase
personnel, and/or
results inline
loss
of function,
to
supply
load. to property deemed essential by the user
loss,
or damage
Feeder
Ferroresonance transient or
sustained overvoltage.
A phenomenon caused by the interaction of system capacitance
and nonlinear inductance of a transformer, usually resulting in
very high
Ferroresonance Protection
(59I)
Ferroresonance detection can be accomplished with a
peak detecting overvoltage element (59I). This type of element
is able to respond to the sub cycle high peak voltages that are
characteristic of the ferroresonance phenomena. Standard
overvoltage elements typically employ RMS calculations to the
waveform and may not be able to detect the high peaks as they
will be averaged with low peak values that also may occur.
Where ferroresonance is expected or found to be a problem,
ferroresonance detection will be required by the
interconnection protection at the EG Facility location
to disconnect the EG Facility.
Generation Facility
A facility for generating electricity or providing ancillary
services, other than ancillary services provided by a transmitter
or distributor through the operation of a transmission or
distribution system, and includes any structures, equipment or
other things used for that purpose
Generator
A person who owns or operates a generation facility
GPR
Ground Potential Rise: IEEE defines this as the voltage that a
station grounding grid may attain relative to a distant grounding
point assumed to be at the potential of remote earth.
75
Embedded Generation
Technical Interconnection Requirements
Revision 0
Harmonics
Sinusoidal voltages and currents at frequencies that are
integral multiples of the fundamental power frequency (60Hz).
High Voltage
In TIR, high voltage refers to PowerStream’s system voltage
and can be referred to as medium voltage.
HVDS
High Voltage Distribution Station: the distribution station
connected directly to Hydro One transmission system (115kV
system) which steps down transmission voltage to distribution
voltage for distribution to the end use customer.
HVGT
HV Grounding Transformer
HV Ground Source
Three-phase ground sources are any three-phase power
transformers or grounding transformers that provide a groundcurrent (zero-sequence) return path to phase-ground faults on
the HV side of the EGIT. That includes separate HV grounding
transformers or EGITs that have star-connected HV winding
with the star-point neutral connected to ground, either solidly
or through a reactor.
HVI
High Voltage Interrupter – any breaker/fault clearing device
that is on the PowerStream side of the EGIT – voltage rating is
usually at medium voltage distribution level.
Embedded Feeders
Feeders owned partly by PowerStream and partly by other
entities (e.g. Hydro One owns the first 50% of the feeder, and
PowerStream owns the remainder of the feeder).
ICCP
IEEE
Inter-Control Center Communications Protocol
The Institute of Electrical and Electronics Engineers
76
Embedded Generation
Technical Interconnection Requirements
Revision 0
IED
Intelligent Electronic Device
IESO
Independent Electricity System Operator
Interrupting Device
The device used to disconnect generation from PowerStream’s
Distribution System: this may be a high voltage interrupter
(HVI) or through a low voltage interrupter/breaker (LVI).
Island
An operating condition where a EG Facility(ies) is (are)
supplying load(s) that are electrically separated from the main
electric utility.
Large Embedded Generation
Facility
An embedded generation facility with a name-plate rated
capacity of more than 10 MW.
Load
The amount of power supplied or required at a specific
location.
Load Displacement
In relation to a generation facility that is connected on the
Customer side of a connection point, that the output of the
generation facility is used or intended to be used exclusively for
the Customer’s own consumption
Load Factor
Ratio of average load during a designated period to the
peak (maximum) load in the same period.
Load Flow Study
Steady state computer simulation study of voltages and currents
in the Distribution System.
LVGT
Low Voltage Grounding Transformer
LVI
Low Voltage Interrupter
77
Embedded Generation
Technical Interconnection Requirements
Revision 0
MCOV
Maximum Continuous Operating Voltage
Medium Voltage
See High Voltage
Micro-embedded Generation
Facility
An embedded generation facility with a nameplate rated
capacity of 10 kW or less
Mid-sized Embedded
Generation Facility
An embedded generation facility with a name-plate rated
capacity of 10 MW or less and:
a) more than 500 kW in the case of a facility
connected to a less than 15 kV line; and
more than 1 MW in the case of a facility connected to a 15 kV
or greater line
NERC
Non Detection Zone – range where passive anti-islanding
protection may not operate within required time due to the
small mismatch between generation and load.
North American Electric Reliability Corporation
NEV
Neutral to Earth Voltage
MTBF
Mean Time Between Failure
MTTR
Mean Time to Repair
OEB
Ontario Energy Board
OESC
Ontario Electrical Safety Code
OGCC
Ontario Grid Control Centre
Open Transition
An open transition transfer maintains isolation from utility
power before it makes contact with generation facility
power. An open transition transfer is also called a breakbefore-make transfer. A break-before-make transfer breaks
NDZ
78
Embedded Generation
Technical Interconnection Requirements
Revision 0
contact with one source of power before it makes contact with
another.
Parallel Operation
The state and operation where the EG Facility is connected to
the Distribution System and supplies loads along with the
electric grid.
PCC or Point of Common
Coupling
The point where the EG Facility is connected to
PowerStream’s Distribution System.
Point of Connection
The point where the new EG Facility’s connection assets or
new line expansion assets will be connected to PowerStream’s
existing Distribution System.
Pst
A measure of short-term perception of flicker obtained for a ten
minute interval.
PSS
Power System Stabilizer
Plt
A measure of long-term perception of flicker obtained for a
two-hour period.
PQ
Power Quality
Protection Scheme
PT
Protection functions including associated sensors, relays, CTs,
VTs, power supplies, intended to protect a Distribution System
or interconnected facility.
Potential Transformer
PU
Pick Up
79
Embedded Generation
Technical Interconnection Requirements
Revision 0
Renewable Enabling
Improvement
A modification or addition to the main distribution system
identified in Section 3.3.2 that is made to enable the main
distribution system to accommodate generation from renewable
energy generation facilities.
Renewable Energy Expansion
Cost Cap
In relation to a renewable energy generation facility, the dollar
amount determined by multiplying the total name-plate rated
capacity of the renewable energy generation facility referred
to in Section 6.2.9(a) (in MW) by $90,000, reduced where
applicable in accordance with Section 3.2.27A (DSC)
Resonance
A tendency of a system to oscillate at maximum amplitude at
certain frequencies, usually resulting in very high voltages and
currents.
RLSS
Rotational Load Shedding Schedules
ROCOF
Rate-of-change-of-frequency
RMS
Root Mean Square
RTU
Remote terminal unit
SC
Short Circuit Current
Small Embedded Generation
Facility
An embedded generation facility which is not a microembedded generation facility with a name-plate rated capacity
of 500 kW or less in the case of a facility connected to a less
than 15 kV line and 1MW or less in the case of a facility
connected to a 15 kV or greater line.
SCADA
Supervisory Control and Data Acquisition
80
Embedded Generation
Technical Interconnection Requirements
Revision 0
SER
Sequence of Events Recorder
SIA
System Impact Assessment
SLD
Single Line Diagram
SPS
Special Protection Scheme
Stabilized
A Distribution System returning to normal frequency and
voltage after a disturbance for a period of 5 minutes or as
determined by the Wires Owner.
Sub-transmission Lines
27.6kV or 44kV PowerStream owned distribution lines
Synchronized
See Parallel Operation
Telemeter
Transfer of metering data using communication systems
THD
Total Harmonic Distortion – a measurement of the harmonic
distortion present. It is defined as a ratio of the sum of the
powers of all harmonic components to the power of the
fundamental frequency.
TIR
Abbreviation for “Distributed Generation Technical
Interconnection Requirements: Interconnections at Voltages
50kV and Below”
TOV
Temporary Overvoltage – oscillatory power frequency
overvoltages of relatively long duration – from a few cycles to
hours.
Transmission System
Any power line facilities under the operating authority of the
Wires Owner usually operating at voltages higher than 50kV,
line to line.
81
Embedded Generation
Technical Interconnection Requirements
Revision 0
Transfer Trip
A signal sent over communication channels from upstream
devices commanding the EG Facility to disconnect from
PowerStream's Distribution System.
Trip Time
The time between the start of the abnormal condition to the
time where the system disconnects and ceases to energize the
Distribution System.
TS
An electrical station that is used to step down transmission
voltage to a sub-transmission voltage for distribution to the end
use customer and Municipal Stations (“MS”).
TSC
Transmission System Code
TT
See Transfer Trip
Type Test
Test performed on a sample of a particular model or device to
verify its operation and design.
ULTC
Under-Load Tap Changer
UTC
Coordinated Universal Time
VT
Voltage Transformer
Wholesale Market Participant
A person that sells or purchases electricity or ancillary
services through the IESO-administered markets.
Wires Owner
The entity who owns and/or operates a Distribution
System or distribution lines.
82
Embedded Generation
Technical Interconnection Requirements
Revision 0
References
[1]
Hydro One Distributed Generation Technical Interconnection Requirements –
Interconnections at Voltages 50kV and Below – DT-10-015 R3
[2]
Toronto Hydro Distributed Generation Requirements – Revision #3
[3]
Ontario Energy Board Distribution System Code Appendix F – Process and Technical
Requirements for Connecting Embedded Generation Facilities – Section F.2 Technical
Requirements
[4]
Ontario Energy Board Distribution System Code
83
5.
Appendices
5.1 Appendix 1 - Requirements
(i)
Embedded Generation Overview
5.2 Appendix 2 – Agreements
5.3
(i)
Micro-Embedded Generation Facility Connection Agreement
(ii)
Connection Agreement for a Small Embedded Generation Facility or a Mid-Sized
Embedded Generation Facility
Appendix 3 – Application Forms
(i)
Form A – Pre-FIT Consultation Application
(ii)
Form B – Connection Impact Assessment Application
(iii)
Form C – Micro-Generation Connection Application
(iv)
MicroFIT Generator Information Package
(v)
FIT Generator Information Package
(vi)
microFIT Generator Commissioning Verification Form
(vii) FIT Generator Commissioning Verification Form
(viii) Net Metering Information Package
5.4
Appendix 4 – Remote Monitoring
(i)
Remote Monitoring and Control Requirement
PowerStream Parallel Generation Requirements
Page 1 of 9
Appendix 1(i) - Embedded Generation Connection Overview
Embedded Generation Connection Overview
(An Overview of Processes, Requirements and Approvals)
Building a generation facility and connecting it to the PowerStream distribution or subtransmission system
requires attention to safety, adherence to technical standards, all in compliance with regulatory
requirements. Connection of a customer owned involves several steps and both parties have distinct
responsibilities.
This section provides a comprehensive set of references that are intended to
familiarize PowerStream customers about the overall process, requirements, and approvals that
may apply to connections of embedded generators to the PowerStream distribution or
subtransmission system.
The Ontario Energy Board (OEB) has created rules within the Distribution System Code (DSC) that
require Local Distribution Companies (LDC’s) to facilitate to connect EG facilities to the respective
LDC’s distribution system accordingly.
What is PowerStream responsible for?
•
•
PowerStream is responsible for the safety, reliability, and efficiency of its distribution system,
and ensuring that the new generation connection does not adversely affect the distribution
system or existing customers
PowerStream is responsible for ensuring that the Distribution System Code and applicable
standards are followed
What is the Generator (Customer) responsible for?
•
•
•
•
The safety, design, construction, operation, metering, protection and control, and
maintenance of the generating facility
The Customer must contact all applicable agencies involved and obtain all approvals prior to the
connection being permitted
The Customer must ensure that all necessary submissions and agreements are completed and
required payments made to PowerStream Inc
The Customer should consider using a consultant to assist with the connection requirements,
process, and approvals
What is the process for connecting a customer owned embedded generator?
The connection process for a customer owned generator is based on the Generator Classification as
shown in the table below:
Generation Classification
Rating
Micro
≤ 10 kW
Small
(a) ≤ 500 kW connected on distribution system
voltage < 15 kV
(b) ≤ 1 MW connected on distribution system voltage
≥ 15 kV
Mid-Sized
(a) < 10 MW but > 500 kW connected on distribution
system voltage < 15 kV
(b) > 1 MW but < 10 MW connected on distribution
system voltage ≥ 15 kV
Large
≥ 10 MW
Small, Mid-Sized and Large Generators - Connection Process Overview Under FIT Program
The following is the connection process overview for generators that are greater than 10kW and operate
at voltages below 50kV:
1. Initial Contact
The Customer proposing the installation of a generation facility contacts PowerStream. PowerStream will
provide the Customer with an information package and a Form A - Pre-FIT Consultation Application. The
Customer will:
Review the information provided by PowerStream and develop an installation plan.
2. Initial Consultation
After the Customer has reviewed the information package he develops an installation plan. The Customer
will:
 Complete and submit the Form A - Pre-FIT Consultation Application to PowerStream
 Contact the Ontario Power Authority (OPA) and complete the OPA FIT application. Once the
application is completed the project will be issued a Reference Number.
After PowerStream has reviewed the Form A - Pre-FIT Consultation Application and established the
generator classification, the project will be discussed with the Customer in a face to face meeting. The
aim of this meeting is discuss issues of mutual interest early in the Customer's review of the feasibility of
the project.
PowerStream will provide the Customer with a Form B - Connection Impact Assessment Application.
3. Connection Impact Assessment
If the Customer decides to proceed with the project, the Customer submits the completed Form B Connection Impact Assessment Application and a signed Study Agreement Form with a payment for the
Connection Impact Assessment.
The cost of the Connection Impact Assessment varies with the size of the generation facility. The amount
of the Connection Impact Assessment Fee will be determined at the initial consultation.
The Customer is allocated capacity upon completion of the CIA (excludes Micro) by PowerStream's
Stations Design department. The capacity allocation for feeder and stations is maintained in accordance
with the capacity allocation process shown in Note 1.
Renewable generation projects up to and including 250 kW on lines less than 15 kV or up to and
including 500 kW on lines greater than or equal to 15 kV, are exempted from the capacity allocation
process.
4. Connection Cost Estimate
After the CIA is complete, the scope of work required to connect new generation can be developed and
the cost of connection to PowerStream’s distribution system can be estimated.
5. Design and Build
Once agreement of the scope, cost and timing are reached, the Customer is required to sign a
Connection Cost Recovery Agreement. After submitting the agreement and payment, detailed design and
construction at additions or modification to PowerStream’s distribution system may begin.
6. Connect, Operate and Maintain
Once all of the required work and approvals are completed, a Connection Agreement will be signed by
PowerStream and the Customer. The Connection Agreement provides an outline of the connection as
well as the roles and responsibility of each party.
If the generator is one MW or larger, an Operating Agreement will be issued by PowerStream's
Operations department and signed by both parties. A Standard Operating Agreement can be found on
PowerStream’s website.
What are the reference documents that specify process and requirements internal to
PowerStream?
-
PowerStream Conditions of Service contains among other things information for the
connection of Embedded Generation facilities.
-
PowerStream Technical Interconnection Requirements outlines the classifications
and general terms and conditions for the connection of Embedded Generation facility to
the distribution system.
-
Appendix 2(i) reference document titled “Micro-Embedded Generation Connection
Agreement” provides the terms, conditions, and technical requirements for embedded
generators that are 10kW or less.
-
Appendix 2(ii) reference document “Small Embedded Generation Connection Agreement”
provides the terms, conditions, and technical requirements for embedded generators that are
greater than 10kW.
Note: Net Metering Program
PowerStream has established a Net Metering program for customers who are planning to install a
generator that uses a renewable technology and is less than 500kW. Net Metering is a program whereby
eligible customers with specific generation facilities can reduce their net energy costs by exporting
surplus generated energy back onto the utility distribution system for credit against the energy the
customer consumes from the distribution system.
What external approvals are a part of the PowerStream connection process?
Depending on the size, type, fuel, and location of generation facilities, the connection of your
generation facilities to our distribution system may require approvals from various regulators that
govern the electricity industry in Ontario. Below are some of the relevant organizations you may need
to engage for the connection of an embedded generation facility.
a) Independent Electricity System Operator (IESO)
The Independent Electricity System Operator (IESO) manages the Ontario power grid,
provides the hourly energy spot market prices, as well as sets and enforces the Market
Rules for participating in the Ontario electricity market.
A System Impact Assessment is conducted by the IESO prior to the customer connecting
an embedded generation facility that is 10 MW or greater in size.
Embedded generators that are over 20 MW or are participating in the Renewable
Energy Supply Contract are required to register with the IESO as a Market Participant
and must comply with all market rules, including metering requirements.
b) Ontario Energy Board (OEB)
The Distribution System Code issued by the OEB sets out the minimum conditions that
Distributors must meet in carrying out their obligations to distribute electricity in Ontario,
under their licence. The interconnection process and requirements for embedded
generation are governed by the Distribution System Code including Appendix F.
The OEB regulates the electricity and gas industry in Ontario. The Ontario Energy Board
Act, 1998, Section 57, requires that electricity market participants be licensed in order to
export power to the distribution grid. More specifically, the Customer (Generator) must
obtain a Generator Licence from the OEB when:


The Applicant intends to sell power into the IESO-administered market.
The Applicant intends to settle for amounts through a distributor's retail settlement
system for energy injected into the distributor's distribution system (i.e. sell
electricity through the distributor). If so, the Applicant must have a connection
agreement and a service agreement for settlement purposes with the distributor.
Generally, a generator licence is not required for load displacement generator or Net
Metering customers.
c) Ontario Power Authority (OPA)
In the case the customer wants to participate in the Ontario Power Authority Feed-in
Tariff Program of renewable energy sources, the customer will need to sign a Feed-in
Tariff contract with the OPA.
d) Electrical Safety Authority (ESA)
The Ontario Electrical Safety Authority sets and enforces standards for electrical safety
through the Ontario Electrical Safety Code. Before connecting to the PowerStream
distribution system, the customer is required to have the ESA inspect their generation
facility and provide a Connection Authorization to PowerStream.
e) Other External Approvals
Customers should also be aware that other approvals might be required such as those
from the Ontario Ministry of Environment, the Canadian Environmental Assessment
Agency, etc.
1. Ontario Ministry of the Environment (MOE)
Depending on the size, type, fuel and location of generation facilities, the MOE may
require that the Customer carry out an environmental assessment.
The MOE sets environmental standards for electricity projects in Ontario and ensures
that generators, distributors and transmitters follow rules and standards when
constructing and operating facilities.
The Guide to Environmental Assessment for Electricity Projects provides the
environmental assessment requirements for electricity projects. They apply equally to
the public and private sectors.
Projects involving generators less than 1 MW typically do not require environmental
screening or environmental assessment. The MOE must be contacted to determine
whether an environmental assessment is required.
2. Canadian Environmental Assessment Agency (CEAA)
The CEAA controls the federal environmental assessment process and it applies
whenever a federal authority has a specified decision-making responsibility for a
project.
Depending on the impact of the generation facilities on the federal jurisdiction, a
federal environmental assessment may be required.
Please contact the CEAA to determine whether a federal environmental assessment
is required.
How do I apply for connection of an embedded generation facility?
Customers interested in connecting a customer owned generator to the PowerStream distribution or
subtransmission system should contact PowerStream at 1-877-963-6900, extension 25001 or email to
egconnect@powerstream.ca.
Customers without e-mail access can request the form and submit the completed form by regular mail to
the following address:
Station Design & Standards
Embedded Generation
PowerStream Inc.
161 Cityview Boulevard
Vaughan, Ontario L4H 0A9
Phone: Vaughan & Vicinity
Barrie & Vicinity
All Other Areas
Fax:
905-417-6900
- extension 25001
705-722-7222
- extension 25001
1-877-963-6900
905-532-4447
- extension 25001
Appendix 2(i) - Micro-Embedded Generation Connection Agreement
Micro-Embedded Generation Facility Connection Agreement
In consideration of PowerStream Inc. (PowerStream) agreeing to allow you to connect your 10 kW name-plate
rated capacity or smaller generation facility to the PowerStream’s distribution system, you hereby agree to the
following terms and conditions.
1.0
Eligibility
1.1 You agree that your generation connection shall be subject to all applicable laws and bound by the
terms and conditions of the PowerStream’s Conditions of Service as amended from time-to-time,
which have been filed with the OEB and are available on request.
2.0
Technical Requirements
2.1 You represent and warrant that you have installed or will install prior to the connection of your
generation facility to the PowerStream’s distribution system, an isolation device satisfying Section 84
of the Ontario Electrical Safety Code, located outside typically near the meter, and agree to allow the
PowerStream’s staff access to and operation of this as required for the maintenance and repair of the
distribution system.
2.2 You agree to perform regular scheduled maintenance to your generation facility as outlined by the
manufacturer in order to assure that connection devices, protection systems, and control systems are
maintained in good working order and in compliance with all applicable laws.
2.3 You agree that during a power outage on the PowerStream system your generation facility will shut
down, unless you have installed special transfer and isolating capabilities on your generation facility.
You agree to the automatic disconnection of your generation facility from the PowerStream’s
distribution system, as per the generator protective relay settings set out in this Agreement, in the event
of a power outage on the PowerStream distribution system or any abnormal operation of the
PowerStream distribution system.
2.4 You covenant and agree that the design, installation, maintenance, and operation of your generation
facility are conducted in a manner that ensures the safety and security of both the generation facility
and the PowerStream’s distribution system.
2.5 Due to PowerStream’s obligation to maintain the safety and reliability of its distribution system, you
acknowledge and agree that in the event PowerStream determines that your generation facility (i)
causes damage to; and/or (ii) is producing adverse effects affecting other distribution system customers
or PowerStream’s assets, you will disconnect your generation facility immediately from the
distribution system upon direction from the PowerStream and correct the problem at your own expense
prior to reconnection.
3.0
Liabilities
3.1 You and PowerStream will indemnify and save each other harmless for all damages and/or adverse
effects resulting from either party’s negligence or willful misconduct in the connection and operation
of your generation facility or the PowerStream distribution system.
3.2 PowerStream and you shall not be liable to each other under any circumstances whatsoever for any
loss of profits or revenues, business interruptions losses, loss of contract or loss of goodwill, or for any
indirect, consequential, incidental or special damages, including but not limited to punitive or
exemplary damages, whether any of the said liability, loss or damages arise in contract, tort or
otherwise.
9
4.0
Compensation and Billing
4.1
If you are not embedded retail generator, you agree that, subject to any applicable law:
a)
PowerStream will not pay you for any excess generation that results in a net delivery to
the PowerStream between meter reads; and
b) There will be no carryover of excess generation from one billing period to the next unless
you are, at the relevant time, a net metered generator (as defined in section 6.7.1 of the
Distribution System Code).
4.2 If you are an embedded retail generator selling output from the embedded generation facility to the
Ontario Power Authority under contract, you agree that PowerStream will pay you for generation in
accordance with the Retail Settlement Code.
4.3 If you are an embedded retail generator selling output to the PowerStream, you agree that
PowerStream will pay you for generation in accordance with the Retail Settlement Code.
5.0
Termination
5.1 You understand that you have the right to terminate this agreement at any time, and that by doing so
you are required to disconnect your generation facility and notify PowerStream of such action.
6.0
Assignment
6.1 You may assign your rights and obligations under this Agreement with the consent of PowerStream,
which shall not withhold its consent unreasonably. PowerStream shall have the right to assign its
rights and obligations under this Agreement without your consent.
I understand, accept and agree to comply with and be bound by the above terms and conditions governing the
connection of my generation facility to the PowerStream distribution system.
Customer Signature: _________________________________
Date: ____________________
Print name: _______________________________________________________________________
PowerStream Account Number:
Billing Address: _____________________________________________________________________
I confirm that the following information is true and accurate:
Nameplate rating of Generator: KW Total installed generation:
KW
Project Location:
Connection Type (Parallel):
OPA Reference number:
Type:
Wind Turbine;
Photovoltaic (Solar);
Other _______________________________
Inverter Utilized:
Yes
No
10
Hydraulic Turbine;
Fuel Cell;
Inverter Certification:
C22.2 #107.1
UL 1741
Site Certified by the ESA
For Office use: Feeder: Date Connected:
Generator Protective Relay Settings
Table 1 - Inverter Based Generation
The following relay settings shall be used for inverters built to the CSA standard:
Source: CSA C22.2 No. 107.1-01 Table 16
System Voltage Vn = V
nominal V (Volts)
Frequency
F (Hertz)
Maximum number of cycles to
disconnect
Seconds
Cycle
V < 0.5 Vn
60
0.1
6
0.5 Vn < V < 0.88 Vn
60
2
120
1.10 Vn < V <1.37 Vn
V > 1.37 Vn
Vn
60
60
F < 59.5*
2
0.033
0.1
120
2
6
F > 60.5
Vn
0.1
6
* The UL1741 & IEEE P1547 Standards use F < rated-0.7 i.e. 59.3 Hz. To update if CSA C22.2 No. 107.1-01 is
changed
Table 2 - Non - Inverter Generation
Requirements for Non-Inverter based generation are as follows:
System Voltage Vn =V
nominal V (Volts)
Frequency
F (Hertz)
Maximum clearing time*
Seconds
Cycles
V < 0.5 Vn
60
0.16
9.6
0.5 Vn ≤ V < 0.88 Vn
60
2
120
1.10 Vn ≤ V <1.20 Vn
60
1
60
V ≥ 1.20 Vn
60
0.16
9.6
Vn
F < 59.3
0.16
9.6
Vn
F > 60.5
0.16
9.6
*Clearing time is the time between the start of the abnormal condition and the generation ceasing to energize the
PowerStream’s distribution system
-
If you are uncertain about your generation equipment’s protective relay settings, please check with your
generating equipment supplier.
- Automatic reconnect setting time for your generator is after 5 minutes of normal voltage
and frequency on the PowerStream’s distribution system.
11
Appendix 2(ii) - Small Embedded Generation Connection Agreement
12
CONNECTION AGREEMENT FOR A SMALL EMBEDDED GENERATION
FACILITY
This Connection Agreement is made this _______ day of ___________, 2014.
BETWEEN
PowerStream Inc., (the “Distributor”)
AND
______________________, (the “Customer”)
(each a “Party” and collectively the “Parties”)
RECITALS
WHEREAS the Distributor is the owner of the distribution system serving the service
area described in electricity distribution licence number ED-2004-0420 (the “Licence”)
issued by the Ontario Energy Board (the “Board”) (the "Distributor’s distribution
system").
AND WHEREAS the Customer owns or operates an embedded generation facility that
is located in the Distributor’s licensed service area (the "Facility").
AND WHEREAS the Customer has connected or wishes to connect its Facility to the
Distributor’s distribution system and the Distributor has connected or has agreed to
connect the Facility to the Distributor's distribution system.
AND WHEREAS the Distributor has previously reviewed and accepted the Customer's
application to connect and related materials that were submitted to the Distributor in
accordance with the process set out in the Distribution System Code (the "Code")
(altogether, the "Application") and the Distributor and the Customer have signed a
connection cost agreement (both of which are attached to this Agreement as Schedule
A).
AND WHEREAS in accordance with its Licence and the Code, the Distributor has
agreed to offer, and the Customer has agreed to accept, distribution service in relation
to the Facility.
NOW THEREFORE in consideration of the foregoing, and of the mutual covenants,
agreements, terms and conditions herein contained, the Parties, intending to be legally
bound, hereby agree as follows:
13
1.
Definitions and Schedules
1.1
Words and phrases contained in this Agreement (whether capitalized or not) that
are not defined in this Agreement have the meanings given to them in the
Electricity Act, 1998, the Ontario Energy Board Act, 1998, any regulations made
under either of those Acts, or the Code.
1.2
The following schedules form part of this Agreement:
Schedule A – Application and Connection Cost Agreement (recitals)
Schedule B – Single Line Diagram, Connection Point and Location of Facilities
(section 2.3)
Schedule C – List of Other Contracts (section 3.4)
Schedule D – Technical and Operating Requirements (section 4.1(d))
Schedule E – Billing and Settlement Procedures (section 5.3)
Schedule F – Contacts for Notice (section 12.1)
Schedule G – Dispute Resolution (section 16.1)
Schedule H – Provisions Applicable if Facility Financed by a Lender (sections
19.3, 20.3 and 21.1)
Where a schedule is to be completed by the Parties, the Parties may not include
in that schedule a provision that would be contrary to or inconsistent with the
Code or the remainder of this Agreement.
2.
Type of Facility and Customer
2.1
The Facility has a name-plate rated capacity of:
more than 10 kW and:
(a) up to and including 500 kW, if the Facility is or will be connected to a less
than 15 kV line; or
(b) up to and including 1 MW, if the Facility is or will be connected to a 15
kV or greater line
(in which case the Facility is a “Small Embedded Generation Facility”)
10 MW or less and:
(a) more than 500 kW, if the Facility is or will be connected to a less than 15
kV line; or
(b) more than 1 MW, if the Facility is or will be connected to a 15 kV or
greater line
14
(in which case the Facility is a “Mid-sized Embedded Generation Facility”)
2.2
The Facility is or will be connected:
directly to the Distributor’s distribution system
on the load customer side of a connection point to the Distributor’s
distribution system
the load customer is the same as the Customer
the load customer is: __________________________
2.3
Schedule B sets out the following:
(a)
a single line diagram of the Facility;
(b)
a list of the facilities of one Party that are on the property of the other Party; and
(c)
a diagram of the metering installations applicable to the Facility.
2.4
The Customer:
intends to:
sell output from the Facility to the Ontario Power Authority and has
entered into an agreement with the Ontario Power Authority for that
purpose
deliver and sell output from the Facility to the Distributor
(in which case the Customer is an “Embedded Retail Generator”)
does not intend to sell any of the output of the Facility to the Ontario
Power Authority or the Distributor
3.
Incorporation of Code and Application of Conditions of Service and Other
Contracts
3.1
The Code, as it may be amended from time to time, is hereby incorporated in its
entirety by reference into, and forms part of, this Agreement. Unless the context
otherwise requires, all references to “this Agreement” include a reference to the
Code.
15
3.2
The Distributor hereby agrees to be bound by and at all times to comply with the Code,
and the Customer acknowledges and agrees that the Distributor is bound at all times to
comply with the Code in addition to complying with the provisions of this Agreement.
3.3
In addition to this Agreement, the relationship between the Distributor and the
Customer will be governed by the Distributor’s Conditions of Service that are
in effect at the relevant time. In the event of a conflict or an inconsistency
between a provision of this Agreement and a provision of the Distributor’s
Conditions of Service, the provision of this Agreement shall govern.
3.4
The Distributor may require or may have already required the Customer to enter into one
or more of the other contracts listed in Schedule C. In the event of a conflict or an
inconsistency between a provision of the Code or this Agreement and a provision of such
other contract, the provision of the Code or this Agreement shall govern.
4.
Facility Standards
4.1
The Customer shall ensure that the Facility:
(a)
meets all applicable requirements of the Electrical Safety Authority (“ESA”);
(b)
conforms to all applicable industry standards including, but not limited to, those of the
Canadian Standards Association (“CSA”), the Institute of Electrical and Electronic
Engineers, the American National Standards Institute and the International
Electrotechnical Commission;
(c)
is installed, constructed, operated and maintained in accordance with this Agreement, the
Distributor’s offer to connect, the requirements of the ESA, the connection cost
agreement, all applicable reliability standards and good utility practice; and
(d)
meets the technical and operating requirements set out in Schedule D. These
requirements shall not exceed any technical or operating requirements set out in the Code
unless the Customer agrees.
5.
Charges, Settlement and Billing
5.1
The Customer shall pay the Distributor such charges as may be approved by
the Board in relation to the connection of, and the provision of distribution
service to, the Facility.
5.2
The Customer agrees to the following in relation to settlement for the output
of the Facility:
if the Customer is not an Embedded Retail Generator (see section 2.4)
the Distributor will not pay the Customer for any excess generation
that results in a net delivery to the Distributor between meter reads
16
and there will be no carryover of excess generation from one billing
period to the next unless the Customer is at the relevant time a net
metered generator
if the Customer is an Embedded Retail Generator (see section 2.4)
the Distributor will settle all applicable payments and charges in
accordance with the Retail Settlement Code
5.3
Billing and settlement activities will be conducted in accordance with the procedures set
out in Schedule E.
6.
Representations and Warranties
6.1
The Customer represents and warrants to the Distributor as follows,
and acknowledges that the Distributor is relying on such
representations and warranties without independent inquiry in
entering into this Agreement:
(a)
(b)
(c)
(d)
(e)
(f)
(g)
(h)
(i)
(j)
6.2
the Facility is fully and accurately described in the Application;
all information in the Application is true and correct;
the Facility is in compliance with all applicable technical requirements and
laws;
the Customer has been given warranty information and operation manuals for the
Facility;
the Customer has been adequately instructed in the operation and maintenance of
the Facility and the Customer has developed and implemented an operation and
maintenance plan based on those instructions;
if the Customer is a corporation or other form of business entity, the Customer is
duly incorporated, formed or registered (as applicable) under the laws of its
jurisdiction of incorporation, formation or registration (as applicable);
the Customer has all necessary power, authority and capacity to enter into this
Agreement and to perform its obligations under this Agreement;
this Agreement constitutes a legal and binding obligation on the Customer,
enforceable against the Customer in accordance with its terms;
the Customer holds all permits, licences and other authorizations that may be
necessary to enable it to own and operate the Facility; and
any individual signing this Agreement on behalf of the Customer has been duly
authorized by the Customer to sign this Agreement and has the full power and
authority to bind the Customer.
The Distributor represents and warrants to the Customer as follows,
and acknowledges that the Customer is relying on such
representations and warranties without independent inquiry in
entering into this Agreement:
(a)
(b)
the Distributor is duly incorporated under the laws of Ontario;
the Distributor has all necessary power, authority and capacity to enter into this
17
(c)
(d)
Agreement and to perform its obligations under this Agreement;
this Agreement constitutes a legal and binding obligation on the Distributor,
enforceable against the Distributor in accordance with its terms; and
any individual signing this Agreement on behalf of the Distributor has been duly
authorized by the Distributor to sign this Agreement and has the full power and
authority to bind the Distributor.
7.
Disconnection Device at the Point of Connection
7.1
The Customer shall furnish and install a disconnection switch at the point of
connection for the Facility that opens, with a visual break, all ungrounded poles
of the connection circuit. The disconnection switch at the point of connection
shall be rated for the voltage and fault current requirements of the Facility, and
shall meet all applicable CSA standards, ESA requirements, and all other
applicable laws. The switch enclosure, if applicable, shall be properly grounded.
The disconnection switch at the point of connection shall be accessible at all
times, located for ease of access to the Distributor’s personnel, and shall be
capable of being locked in the open position. The Customer shall follow the
Distributor’s procedures for switching, clearance, tagging, and locking.
8.
Modifications to the Facility
8.1
The Customer shall not modify its connection assets or the Facility except in accordance
with this section. Where the modification will not increase the maximum electrical output
of the Facility, the Customer shall give the Distributor no less than 15 working days
notice prior to the date on which the modification will be completed. Where the
modification will increase the maximum electrical output of the Facility, the Customer
shall submit a new application for connection to the Distributor. The Distributor shall
process that application for connection in accordance with the Code. The Customer shall
not commence such modification until that process has been completed.
9.
Insurance
9.1
Throughout the term of this Agreement, the Customer shall carry commercial
general liability insurance for third party bodily injury, personal injury, and
property damage in an amount as follows:
if the Facility is a Small Embedded Generation Facility (see section 2.1)
not less than $1,000,000 per occurrence and in the annual aggregate
if the Facility is a Mid-sized Embedded Generation Facility (see section
2.1)
not less than $2,000,000 per occurrence and in the annual aggregate
18
Prior to execution of this Agreement, the Customer shall provide the Distributor
with a valid certificate of insurance. The Customer shall provide the Distributor
with prompt notice of any cancellation of the Customer's insurance by the insurer.
10.
Liability and Force Majeure
10.1
The liability provisions of section 2.2 of the Code apply to this Agreement and are
hereby incorporated by reference into, and form part of, this Agreement.
10.2
A Party shall have a duty to mitigate any losses relating to any claim for
indemnification from the other Party that may be made in relation to that other
Party. Nothing in this section shall require the mitigating Party to mitigate or
alleviate the effects of any strike, lockout, restrictive work practice or other labour
dispute.
10.3
A Party shall give prompt notice to the other Party of any claim with respect to
which indemnification is being or may be sought under this Agreement.
10.4
The force majeure provisions of section 2.3 of the Code apply to this Agreement and are
hereby incorporated by reference into, and form part of, this Agreement.
11.
Facility Commissioning and Testing
11.1
The Customer shall give the Distributor at least fifteen days advance written
notice of the date(s) and time(s) on which the Facility will be commissioned and
tested prior to connection. The Customer shall give the Distributor the same
notice in relation to the commissioning and testing of any material modification to
the Customer’s connection assets or Facility that occurs after connection.
11.2
The Distributor shall have the right to witness the commissioning and testing activities
referred to in section 11.1.
12.
Notice
12.1
Any notice, demand, consent, request or other communication required or
permitted to be given or made under or in relation to this Agreement shall be
given or made: by courier or other personal form of delivery; by registered mail;
by facsimile; or by electronic mail. Notices shall be addressed to the applicable
representative of the Party identified in Schedule F.
12.2
A notice, demand, consent, request or other communication referred to in
section12.1 shall be deemed to have been made as follows:
(a)
(b)
where given or made by courier or other form of personal delivery, on the date of
receipt;
where given or made by registered mail, on the sixth day following the date of
mailing;
19
(c)
(d)
where given or made by facsimile, on the day and at the time of transmission as
indicated on the sender's facsimile transmission report; and
where given or made by electronic mail, on the day and at the time when the
notice, demand, consent, request or other communication is recorded by the
sender’s electronic communications system as having been received at the
electronic mail destination.
13.
Access to Facility
13.1
Each Party shall ensure that its facilities are secured at all times.
13.2
The Customer shall permit and, if the land on which the Facility is located is
not owned by Customer, cause such landowner to permit, the Distributor's
employees and agents to enter the property on which the Facility is located at
any reasonable time. Such access shall be provided for the purposes of
inspecting and/or testing the Facility as and when permitted by this
Agreement, the Code or the Distributor’s Conditions of Service or as required
to ensure the continued safe and satisfactory operation of the Facility, to
ensure the accuracy of the Distributor's meters, to establish work protection,
or to perform work.
13.3
Any inspecting and/or testing referred to in section 13.2 shall not relieve the
Customer from its obligation to operate and maintain the Facility and any
related equipment owned by the Customer in a safe and satisfactory operating
condition and in accordance with this Agreement.
13.4
The Distributor shall have the right to witness any testing done by the
Customer of the Facility and, to that end, the Customer shall provide the
Distributor with at least fifteen working days advance notice of the testing.
13.5
Notwithstanding section 10.1, where the Distributor causes damage to the
Customer's property as part of this access, the Distributor shall pay to the
Customer the Customer's reasonable costs of repairing such property or, if
such property cannot be repaired, replacing such property.
13.6
Notwithstanding section 10.1, if the Customer has been given access to the Distributor’s
property, and if the Customer causes damage to the Distributor’s property as part of that
access, the Customer shall pay to the Distributor the Distributor’s reasonable costs of
repairing such property or, if such property cannot be repaired, replacing such property.
14.
Disconnection of Facility to Permit Maintenance and Repairs
14.1
If the Customer requests it, the Distributor will provide the Customer with
reasonable notice of any planned equipment outages in the Distributor’s
distribution system that occur on or after the date of the Customer's
request which will impact the Facility or its connection.
20
14.2
The Distributor will make reasonable efforts to ensure that the outages referred
to in section 14.1 will be of minimal duration and cause minimal inconvenience
to the Customer.
14.3
In connection with any planned equipment outage, either Party may
disconnect or isolate, or require the disconnection or isolation of, its Facility or
system (as applicable) from the other Party’s Facility or system (as
applicable) so that the employees, contractors or agents of the Party may
construct, maintain, repair, replace, remove, investigate or inspect its own
Facility or system (as applicable) in accordance with the terms of this
Agreement and good utility practice.
14.4
Where practical, the Customer shall notify the Distributor prior to temporarily
isolating or disconnecting the Facility from the Distributor’s distribution
system.
15.
Disconnection of Facility for Other Reasons
15.1
The Customer shall discontinue operation of the Facility and the Distributor
may isolate or disconnect the Facility from the Distributor's distribution system,
upon any of the following:
(a)
(b)
(c)
(d)
(e)
termination of this Agreement in accordance with section 19;
if the Customer’s connection assets or the Facility are modified by the Customer
in a manner contrary to section 8.1;
during an emergency or where necessary to prevent or minimize the effects of an
emergency;
in accordance with section 31, 31.1 or 40(5) of the Electricity Act, 1998, other
applicable law, the Code, the Distributor’s Licence or the Distributor’s Conditions
of Service; or
where required to comply with a decision or order of an arbitrator or court made
or given under Schedule G.
15.2
In the event of disconnection under section 15.1(b), the Facility shall remain
isolated or disconnected from the Distributor's distribution system until the
connection process referred to in section 8.1 has been completed.
15.3
In the event of disconnection under section 15.1(c), the Distributor shall
reconnect, or permit the reconnection of, the Facility to the Distributor's
distribution system when it is reasonably satisfied that the emergency
has ceased and that all other requirements of this Agreement are met.
15.4
In the event of disconnection under section 15.1(d) or 15.1(e), the Distributor
shall reconnect, or permit the reconnection of, the Facility to the Distributor’s
distribution system when the Distributor is reasonably satisfied that the reason for
the disconnection no longer exists, the Customer agrees to pay all Board-
21
approved reconnection costs charged by the Distributor, and the Distributor is
reasonably satisfied of the following, where applicable:
(a)
(b)
the Customer has taken all necessary steps to prevent the circumstances that
caused the disconnection from recurring and has delivered binding undertakings
to the Distributor that such circumstances shall not recur; and
any decision or order of a court or arbitrator made or given under Schedule G that
requires a Party to take action to ensure that such circumstances shall not recur
has been implemented and/or assurances have been given to the satisfaction of the
affected Party that such decision or order will be implemented.
15.5
Where the Facility has been isolated or disconnected, each Party shall be
entitled to decommission and remove its assets associated with the connection.
Each Party shall, for that purpose, ensure that the other Party has all necessary
access to its site at all reasonable times.
15.6
The Customer shall continue to pay for distribution services provided up to the
time of isolation or disconnection of its Facility
15.7
The Customer shall pay all reasonable costs including, but not limited to, the costs of
removing any of the Distributor’s equipment from the Customer’s site, that are directly
attributable to the isolation or disconnection of the Facility and, where applicable, the
subsequent decommissioning of the Facility. The Distributor shall not require the
removal of the protection and control wiring on the Customer’s site.
15.8
While the Facility is isolated or disconnected, the Distributor shall not be required to
convey electricity to or from the Facility.
16.
Dispute Resolution
16.1
Any dispute between the Customer and the Distributor arising under or in relation to this
Agreement will be resolved in accordance with Schedule G. The Parties shall comply
with the procedure set out in Schedule G before taking any civil or other proceeding in
relation to the dispute, provided that nothing shall prevent a Party from seeking urgent or
interlocutory relief from a court of competent jurisdiction in the Province of Ontario in
relation to any dispute arising under or in relation to this Agreement.
17.
Amendments
17.1
The Parties may not amend this Agreement without leave of the Board except
where and to the extent permitted by this Agreement.
17.2
The Parties may by mutual agreement amend this Agreement to reflect changes
that may from time to time be made to the Code during the term of this
Agreement.
22
17.3
The Parties may by mutual agreement amend any portion of a schedule that was
originally to be completed by the Parties.
17.4
No amendment made under section 17.2 or 17.3 shall be contrary to or
inconsistent with the Code or the remainder of this Agreement.
17.5
The Parties shall amend this Agreement in such manner as may be required by
the Board.
17.6
Any amendment to this Agreement shall be made in writing and duly executed by both
Parties.
18.
Waiver
18.1
A waiver of any default, breach or non-compliance under this Agreement is not effective
unless in writing and signed by the Party to be bound by the waiver. The waiver by a
Party of any default, breach or non-compliance under this Agreement shall not operate as
a waiver of that Party’s rights under this Agreement in respect of any continuing or
subsequent default, breach or non-compliance, whether of the same or any other nature.
19.
Term of Agreement and Termination
19.1
This Agreement shall become effective upon execution by the Parties, and
shall continue in effect until terminated in accordance with section 19.2 or 19.3.
19.2 The Customer may, if it is not then in default under this Agreement, terminate
this Agreement at any time by giving the Distributor thirty days prior written
notice setting out the termination date.
19.3
Except as set out in Schedule H, the Distributor may terminate this Agreement
upon any material breach of this Agreement by the Customer (a "Default"), if the
Customer fails to remedy the Default within the applicable cure period referred
to in section 19.4 after receipt of written notice of the Default from the
Distributor.
19.4
The Customer shall cure a Default within the applicable cure period specified
in the Code or the Distributor’s Conditions of Service. If no such cure period is
specified in relation to a given Default, the cure period shall be sixty working
days.
19.5
Termination of this Agreement for any reason shall not affect:
(a)
(b)
the liabilities of either Party that were incurred or arose under this Agreement
prior to the time of termination; or
the provisions that expressly apply in relation to disconnection of the Customer’s
facilities following termination of this Agreement.
23
19.6
Termination of this Agreement for any reason shall be without prejudice to the
right of the terminating Party to pursue all legal and equitable remedies that may
be available to it including, but not limited to, injunctive relief.
19.7
The rights and remedies set out in this Agreement are not intended to be
exclusive but rather are cumulative and are in addition to any other right or
remedy otherwise available to a Party at law or in equity. Nothing in this section
19.7 shall be interpreted as affecting the limitations of liability arising from section
10.1 or the obligation of a Party to comply with section 16 while this Agreement is
in force.
19.8 Sections 19.5 to 19.7 shall survive termination of this Agreement.
20.
Exchange and Confidentiality of Information
20.1
Confidential information in respect of a Party means (i) information disclosed by
that Party to the other Party under this Agreement that is in its nature
confidential, proprietary or commercially sensitive and (ii) information derived
from the information referred to in (i), but excludes the following:
(a)
(b)
20.2
information that is in the public domain; or
information that is, at the time of the disclosure, in the possession of the receiving
Party, provided that it was lawfully obtained from a person under no obligation of
confidence in relation to the information.
Subject to section 20.3, each Party shall treat all confidential information
disclosed to it by the other Party as confidential and shall not, without the written
consent of that other Party:
(a)
(b)
disclose that confidential information to any other person; or
use that confidential information for any purpose other than the purpose for which
it was disclosed or another applicable purpose contemplated in this Agreement.
Where a Party, with the written consent of the other Party, discloses confidential
information of that other Party to another person, the Party shall take such steps
as may be required to ensure that the other person complies with the
confidentiality provisions of this Agreement.
20.3
Nothing in section 20.2 shall prevent the disclosure of confidential information:
(a)
(b)
(c)
(d)
where required or permitted under this Agreement, the Code, the Market Rules or
the Distributor’s Licence;
where required by law or regulatory requirements;
where required by order of a government, government agency, regulatory body or
regulatory agency having jurisdiction;
if required in connection with legal proceedings, arbitration or any expert
determination relating to the subject matter of this Agreement, or for the purpose
24
(e)
(f)
of advising a Party in relation thereto;
as may be required to enable the Distributor to fulfill its obligations to any
reliability organization; or
as may be required during an emergency or to prevent or minimize the effects of
an emergency.
20.4
Notwithstanding section 10.1, a Party that breaches section 20.2 shall be liable to
the other Party for any and all losses of the other Party arising out of such
breach.
20.5
The Parties agree that the exchange of information, including, but not limited to,
confidential information, under this Agreement is necessary for maintaining the
reliable operation of the Distributor’s distribution system. The Parties further
agree that all information, including, but not limited to, confidential information,
exchanged between them shall be prepared, given and used in good faith and
shall be provided in a timely and cooperative manner.
20.6
Each Party shall provide the other with such information as the other may
reasonably require to enable it to perform its obligations under this
Agreement.
20.7
Each Party shall, as soon as practicable, notify the other Party upon becoming
aware of a material change or error in any information previously disclosed to
the other Party under this Agreement and, in the case of the Customer, in any
information contained in its Application. The Party shall provide updated or
corrected information as required to ensure that information provided to the
other Party is up to date and correct.
21.
Assignment, Successors and Assigns
21.1
Except as set out in Schedule H, the Customer shall not assign its rights or
obligations under this Agreement in whole or in part without the prior written
consent of the Distributor, which consent shall not be unreasonably withheld or
unduly delayed. The Distributor may withhold its consent to any proposed
assignment until the proposed assignee assumes, in writing, all of the
Customer's obligations contained in this Agreement.
21.2
The Distributor shall have the right to assign this Agreement in whole upon
written notification to the Customer.
21.3
This Agreement shall be binding upon and enure to the benefit of the Parties and their
respective successors and permitted assigns.
22.
Governing Law
22.1
This Agreement shall be governed by the laws of the Province of Ontario and the federal
laws of Canada applicable therein.
25
23.
Entire Agreement
23.1
Except as expressly provided herein, this Agreement constitutes the entire
agreement between the Parties with respect to the subject-matter hereof and
supersedes all prior oral or written representations and agreements of any kind
whatsoever with respect to the subject-matter hereof.
IN WITNESS WHEREOF, the Parties hereto, intending to be legally bound, have
caused this Agreement to be executed by their duly authorized representatives.
__________________________________
Customer Signature
___________________
Date
___________________________________
Name (Print)
____________________________________
Title
__________________________________
Distributor Signature
___________________
Date
Name:
Title:
Manager, Stations Design and Standards
26
SCHEDULE A
Application and Connection Cost Agreement (recitals)
27
SCHEDULE B
Single Line Diagram, Connection Point and Location of Facilities (section 2.3)
B.1
Single Line Diagram and Connection Point
PCC
Transformer
28
B.2 Single Line Diagram
29
B.3 List of Facilities on the Property of the Other Party
B.3.1 The following facilities of the Customer are located on the property of the
Distributor:
No facilities of the Customer have been located on the property of the Distributor.
B.3.2 The following facilities of the Distributor are located in the property of the
Customer:




Revenue Meter
Instrument Transformers
Metering Test Blocks
Revenue Metering Panel Wiring
30
B.4 Metering Installation Diagram
31
SCHEDULE C
List of Other Contracts (section 3.4)
C.1 Feed-In Tariff Contract
32
C.2 Certificate of Insurance
33
C.4 Notice to Proceed
34
SCHEDULE D
Technical and Operating Requirements (section 4.1(d))
SCHEDULE D
TECHNICAL AND OPERATING REQUIREMENTS
D.1
Protection Scheme
1.
General
Relaying specified in this Agreement is intended to protect the Distribution
System only. Experts in the relevant fields shall perform all protection
schemes designed for the Generating Facility. The Distributor will require
that the Customer submit the descriptions of electrical and protection
packages signed and stamped by a Professional Engineer (Licensed in
Ontario). As a minimum, the package signed by the Professional Engineer
shall include the single line diagram showing the key electrical
components and protection relays, a description of the relay protection
philosophy, proposed settings, testing and commissioning plan. The
commissioning plan must describe the tests to be done to demonstrate the
protection’s effectiveness to trip for internal faults (within the Generating
Facility), external faults on the Distributor’s feeder, islanding, and other
abnormal Distribution System conditions. The Distributor reserves the right
to witness any or all the commissioning tests and future periodic tests. The
testing and commissioning report of the Generating Facility and the final
relay settings shall also be signed and stamped by the Customer’s
Professional Engineer.
The Customer is required to re-verify / test its protections, especially those
impacting the Distributor, on a regular basis, to verify that the system
operates as designed-every four (4) years for microprocessor based
systems and every two (2) years for electro-mechanical based system.
The re-verification / test report for the electrical and protection facilities.
The Customer is responsible to design, install, maintain and protect its
Generating Facility against all internal electrical faults and other external
conditions imposed by the Distribution System such as over voltages,
voltage unbalances, open phase(s), power quality and recloses of the
feeder breaker / recloser.
The Customer shall ensure that its electrical system design meets the
Distributor’s design requirements for the particular voltage at which it is to
be connected to the Distribution System.
All interface protective relays shall be utility grade, meet the Distributor’s
requirements, IEEE /ANSI C37.90 design standards and shall be of the
type generally used in utility systems. Adequate facilities for testing and
maintenance shall be provided. Microprocessor based relays shall be
equipped with self-checking / diagnostic features. The relays shall have
sealable covers or other means to prevent tampering or unauthorized
setting adjustments. The types and settings of the protective relays shall
be submitted to the Distributor for review and acceptance.
Protective relaying and systems must be designed to provide required
safety, selectivity, reliability and speed of operation. In some cases
redundancy in protection schemes / relays may be required. The
Customer should consider these requirements in the design of its
Generating Facility.
The Customer may be tied to more than one feeder. These feeders may
have different fault levels and originate from different distribution /
transformer stations or transformers within the same distribution /
transformer station. The protection scheme and protection coordination
must account for these possibilities.
The Customer shall take reasonable steps to ensure that the operation or
failure of its Generating Facility does not cause a Distribution System
outage or disturbance.
The Generating Facility shall comply, as a minimum, with section 84 of the
OESC.
2.
Grounding
The Customer shall design a proper grounding system for the Generating
Facility in accordance with Applicable Law and standards. Grounding
installations shall be capable of carrying the maximum foreseeable fault
current, for the duration of such fault, without risking safety to the public or
other personnel that may be present on site when a fault occurs. The
grounding system design shall prevent equipment damage and
interference with the operation of the distribution and any communication
system that may be present.
The Customer shall provide grounding system design and ground
potential rise (GPR) study if requested by the Distributor.
3.
Protection Coordination
Upon request from the Customer, the Distributor will provide information
on three phase and single phase-to-ground fault levels and associated
X/R ratios at the Ownership Demarcation Point.
The Customer shall provide results of the protection coordination study
and coordination curves. In special cases, the Distributor may require
additional protection and / or features to be provided by the Customer for
interface protection.
The Distributor’s review will be limited to checking the interface protection
settings as it affects the Distribution System, and does not include any
review of the Generating Facility’s protection schemes.
4.
Remote / Transfer Trip / ‘Customer End Open’ Status
Depending on the type and rating of generation connected to the
distribution feeder and minimum feeder load, remote / transfer trip feature
between the feeder breaker at the distribution / transformer station and the
Generating Facility may be required. The main purpose of the remote /
transfer trip signal, when used, will be to ‘speed up’ the tripping at the
Generating Facility following the tripping of the feeder breaker to prevent
an islanding situation. Necessary protection at the Generating Facility
must be provided in all cases to independently detect and trip for islanding
situations (should the communication channel fail). If the Generating
Facility can operate successfully in an island mode, i.e. it can maintain
normal voltage and frequency, then a remote / transfer trip must be
provided to isolate the Generating Facility.
The remote/transfer trip protection is required:
a) When aggregate capacity on project feeder is 1MW or larger;
b) When the aggregate generation, comprising of existing
generation, other earlier proposed EG facilities, and the concerned
EG facility, is greater than 50% of the minimum feeder load.
The Distributor will determine the requirements of remote / transfer trip,
Customer end open status, and voltage supervision etc. for the particular
Generating Facility on a case-by-case basis. If communication is required,
the Customer will be responsible to provide a reliable communication
channel between its Generating Facility and the distribution station. A
ground potential rise study may also be required for Generating Facility for
the installation of telephone wires as the communication channel between
the distribution station and the Customer. The study is to ensure that the
Generating Facility do not present a safety hazard or adversely affect
telecom and protection systems.
5.
Protection System Failure
The telecommunication facilities, used for protection purposes, shall have
a level of reliability consistent with the required performance of the
protection system. The Distributor shall review telecommunication channel
media.
Telecommunication circuits used for the protection and control of the
Distribution System shall be dedicated to that purpose.
Telecommunication systems shall be:
a) designed to prevent unwanted operations such as those caused by
equipment or personnel; and
b) powered by the station’s batteries or other sources independent from
the power system; and
c) monitored in order to assess equipment and channel readiness
If at any time, the protection system or the communication channel for
remote / transfer trip is not functioning or out of service, or the DC supply
is lost, the Customer / interface breaker must be opened to isolate the
Customer from the Distribution System and the Distributor shall be
informed accordingly. The breaker(s) must remain open until the affected
system is returned to normal service condition.
Circuits on the Distribution System will automatically re-close after an
initial feeder fault. The Customer’s protection scheme shall ensure that the
Customer is disconnected from the feeder before the circuit is re-closed.
The Distributor shall not be liable for any damages whatsoever as a result
of an auto-reclosure on the feeder. The Distributor shall give reasonable
notice to the Customer if it intends to change the re-closing time on it’s
feeder breakers.
The Customer shall re-verify its station protections and control systems
that can impact on the Distribution System. The maintenance cycle can be
site specific.
The Customer shall ensure the closing of the Generating Facility onto the
Distributor’s feeder is synchronized
D.2
OWNERSHIP DEMARCATION POINT REQUIREMENTS
1.
The Customer’s protective relays at the Ownership Demarcation Point
must coordinate with the existing Distributor’s protective devices for feeder
protection. The Customer’s protective system shall be capable of
automatically isolating the Customer or its components from the
Distribution System in the following situations:
2.
(a)
Internal faults within the Generating Facility involving various
electrical components e.g. Customers, transformers, bus bars,
cables, motors;
(b)
External faults in the Distribution System, such as phase and
ground faults;
(c)
Certain abnormal system conditions such as over / under voltage,
over / under frequency, open phase(s);
(d)
Islanding.
The Customer’s protective device(s), at the Ownership Demarcation Point
should meet the following minimum requirements:
(a)
Have suitable ratings, characteristics and setting ranges so that
proper coordination with the upstream Distributor’s feeder
protective device(s) is achieved;
(b)
Be designed and selected so as to provide required safety,
selectivity, reliability and speed of operation;
(c)
Protect the downstream equipment viz. transformer, busbar against
faults and other abnormal conditions;
(d)
Provide backup protection for the downstream equipment protective
device(s).
3.
The Customer shall provide settings for the protective devices at the
Ownership Demarcation Point for the Distributor’s review and agreement.
4.
The following are the minimum technical and functional requirements that
shall be met by the Customer at the Ownership Demarcation Point. The
devices used to meet these requirements can, however, be located
elsewhere in the Generating Facility:
(a)
Voltage Regulation: The Customer shall not degrade the voltage
provided to the Distribution System outside the range given in CSA
C235.
(b)
Integration with the Distribution System grounding and with
grounding protection: The Customer agrees to coordinate the
grounding scheme and the grounding fault protection of the
Customer with that of the Distribution System.
(c)
Synchronization: During synchronization, the Customer agrees not
to cause a voltage fluctuation at the interface point of more than +
or – 5% of the operating voltage.
(d)
Inadvertent Energization: The Customer shall not energize the
Ownership Demarcation Point when the Distribution System has
been de-energized for any reason.
(e)
Reconnection after a Distributor Distribution System Outage: No
reconnection shall take place until the Distributor’s supply voltage
and frequency are within operating limits. The Customer shall have
a suitable adjustable delay feature that can delay reconnections as
per the Distributor’s site-specific requirements.
(f)
Monitoring: The Distributor may require that the Customer unit(s)
be monitored for availability, connection status, real power output,
imaginary power output etc. at the Ownership Demarcation Point.
The Customer will be required to cover all costs associated with the
installation of a Remote Terminal Unit (RTU) and associated
hardware compatible with the SCADA system of the Distributor if
required by the Distributor.
(g)
Response to Voltage Disturbances: The Customer agrees that the
protection functions of the interface protection system shall
measure the effective (RMS) or fundamental frequency value of
each phase-to-neutral or phase-to-phase voltage as required. The
Generating Facility shall disconnect from the Distribution System
when any of the measured voltages are outside the permissible
range. The range(s) and the clearing time(s) shall be determined by
the Distributor.
(h)
Response to Frequency Disturbances: The Generating Facility shall
follow the Distributor’s frequency within the range of 59.3 Hz to 60.5
Hz (on a 60 Hz base). The Generating Facility shall disconnect
from the Distribution System if the frequency goes outside the
range above. The Distributor shall determine the frequency limits
and the clearing time shall be within 0.3 seconds (IESO
requirement).
5.
(i)
Disconnection for Faults: The Customer shall disconnect the
Generating Facility from the Distribution System for faults on the
feeder to which it is connected.
(j)
Loss of Synchronism: The Generating Facility with synchronous
Customers shall have necessary protective functions to trip the
Customer from the Distribution System without any intentional
delay in case of loss of synchronism.
(k)
Feeder Reclosing Coordination: The Generating Facility shall be
designed to coordinate with the Distributor’s feeder reclosing
practice. The Distributor shall not liable to the Customer for any
damage or loss to the Generating Facility due to the reclosure of a
feeder breaker.
(l)
Limitation of DC Injection: The DC injection shall be limited as per
item 4.3.1 of IEEE P1547 / D08 or the latest revision of the draft
standard, as applicable.
(m)
Limitation of Voltage Flicker Induced by the Customer: The
Customer shall not create objectionable flicker for other customers
on the Distributor’s feeder.
(n)
Harmonics: The Customer agrees that the maximum harmonic
current distortions shall be limited as per the values given in Table
2 of IEEE P1547 / D08 or the latest revision of the draft standard,
as applicable.
(o)
Immunity Protection: The influence of electromagnetic interference
(EMI) shall not result in a change of state or mal-operation at the
Ownership Demarcation Point.
(p)
Surge Capability: The interface system shall have the capability to
withstand voltage and current surges in accordance with the
environments defined in IEEE/ANSI C 62.41 or IEEE C 37.90.1 as
applicable.
(q)
Unintentional Islanding: Islanding is a condition in which a portion of
the Distribution System may be energized solely by the Customer
while that portion of the system is electrically separated from the
rest of the Distribution System. If such a situation is created, the
Customer shall disconnect from the Distributor’s feeder within a
time period that shall be specified by the Distributor depending
upon the site specific requirements.
The Customer shall provide, install and maintain (unless other
arrangements are made and accepted by the Distributor), suitable
disconnecting device(s) at the Ownership Demarcation Point. The use of
this device(s) will be to isolate the Customer in case of Emergency and for
Work Protection. The disconnecting device(s) shall:
(a)
be located at or near to the point of interface of the Generating
Facility to the Distribution System, and must be readily accessible;
(b)
provide a visible break in the main current-carrying path and isolate
the Generating Facility from the Distribution System;
(c)
have three-pole gang operated switch mechanisms suitable for load
break operations at rated load (single-phase Customers may use
single-pole devices subject to the Distributor’s acceptance);
(d)
be lockable in the open position;
(e)
be suitable for safe operation under the conditions of use;
(f)
be capable of being energized from both sides;
(g)
meet all other OESC and ESA requiremenents.
D.3
REQUIREMENTS FOR INSPECTION, TESTING AND COMMISSIONING
Both the Customer and the Distributor shall ensure that inspection and testing
are performed in accordance with the following:
(a)
The Customer shall ensure that only Qualified Personnel carry out all
inspection and testing of equipment after the Ownership Demarcation
Point, and the Distributor shall ensure that only Qualified Personnel
carry out all inspection and testing of equipment up to the Ownership
Demarcation Point.
(b)
The protective relaying at the Generating Facility should be reverified
once every four (4) years by the Customer and a written report
confirming this reverification provided to the Distributor each time. The
Customer shall make advance notice of this reverification to the
Distributor so that the Distributor can make arrangements to witness
the reverification. This witnessing will be at the discretion of the
Distributor and the costs of the witnessing shall be borne by the
Distributor.
(c)
The supply feeder shall be operated on a regularly scheduled basis to
confirm its operation and the functioning of the associated protection
schemes.
(d)
The Generating Facility shall be visually inspected at least once per
year to note obvious maintenance problems such as broken insulators
or other damaged equipment.
(e)
Any deficiencies identified during inspections should be noted and
repairs scheduled as soon as possible, with timing dependent on the
severity of the problem, due diligence concerns (of both the Distributor
and the Customer) and financial and material requirements.
(f)
The Distributor shall be notified of any deficiencies involving critical
protective equipment, including all protections which trip the
Distributor’s 27.6kV feeder breaker.
The Customer shall submit a proposed commissioning plan to the Distributor for
any Generating Facility connecting to the Distribution System for the Distributor’s
review. The Distributor reserves the right to witness any or all commissioning
tests and request additional tests that it deems necessary to be performed.
The commissioning plan must be signed by a Professional Engineer licensed in
the Province of Ontario and must detail how the Customer will demonstrate that
the protections and fault interrupting devices will detect and clear the required
conditions and automatically separate the Generating Facility from the
Distribution System. The Distributor may also require that tests be carried out to
screen for possible power quality problems caused by the operation of the
Generating Facility.
Prior to the Customer being connected for the first time, the Customer shall have:
(a)
Paid for all costs due and payable by the Customer relating to the
connection of the Generating Facility to the Distribution System as set
out in this Agreement; and
(b)
provided the Distributor with the test results as set out in this
Agreement herein; and
(c)
provided the Distributor with any specific approvals or permits required
to ensure that the Generating Facility is in full compliance with all laws,
regulations, by-laws and statutes; and
(d)
written acceptance of the coordination of the energization date,
energization time and applicable orders to operate have been signed
by the Distributor.
Before parallel operation with the Distribution System is allowed, field verification
may be required by the Distributor.
Pre-parallel inspection and testing shall include but not be limited to:
(a)
CT and PT ratio tests;
(b)
CT and PT secondary circuit tests to verify phasing, polarity, continuity
and single ground reference;
(c)
Completion of relay manufacturer’s recommended acceptance tests as
listed in instruction manuals;
(d)
Witnessing the testing of relays and their protective settings as per the
Distributor’s accepted protective settings (Customer’s and the
Distributor testing personnel must have copies of the accepted settings
before testing begins);
(e)
Tests to verify that relays trip breakers according to the Distributor’s
accepted Customer’s schematic diagram / tripping matrix;
(f)
Tests of phasing between the Distributor and the Generating Facility
(primary voltage);
(g)
Directionality test on distance, reverse power, and any other directional
relays used for interface protection;
(h)
Final synchronization tests, before paralleling the two systems, to
verify that the Customer(s) in the Generating Facility are in phase with
the Distribution System;
(i)
Checking remote / transfer trips and Customer end open signals,
where applicable;
(j)
Tests to prove the interface protection and functional requirements;
(k)
Other tests, as required.
As built drawings (single line diagram showing protection and metering, AC and
DC schematics, final relay settings, testing and commissioning results for
interface protection etc.) shall be submitted to the Distributor within sixty (60)
Business Days after the connection. The Distributor may retain these for future
reference.
The Customer shall, at its own expense, have the Generating Facility tested and
verified by any and all other agencies that may have jurisdiction over the
Generating Facility.
D.4 Generator Protective Relay Settings
Over Frequency/Under Frequency Protection
Table 1 – Over/Under Frequency Protection Set Points and Clearing Times
Overvoltage/Undervoltage Protection
Table 2 - Over/Under Voltage Protection Setting and Clearing Time
D.5 FIT Project Inverter Settings
D.6 Requirements for FIT Project
The Connection Impact Assessment resulted in the following requirements for
the proposed embedded generation project.
1. Remote Shutdown
The embedded generation project is required to have remote shutdown via DNP3
signal.
1.1 Specifications for Remote Shutdown
Remote shutdown to be provided via DNP3 - command to be transmitted via
customer supplied RTU and WiMax 1.8Ghz radio, as specified in the
PowerStream Embedded Generation Information Package and PowerStream
Remote Monitoring Control Form.
2. Remote Monitoring
The inverter must provide remote monitoring equipment for monitoring of:
o
o
o
o
Voltage
Current
Real and reactive power
Circuit breaker status
2.1 Specifications for Remote Monitoring
Remote monitoring data to be provided via DNP3 or Modbus over Ethernet
protocol via Ethernet data port. If Ethernet is not available, then a serial data port
using Modbus or DNP3 data protocol. Data to be transmitted to PowerStream via
customer supplied RTU and WiMax 1.8Ghz radio.
The remote shutdown and remote monitoring requirements are in
service as of <date>.
SCHEDULE E
Billing and Settlement Procedures (section 5.3)
The following provisions apply in relation to billing and settlement in relation to the
Facility:
SALE AND PURCHASE OF POWER
1.
In accordance with the Distributor’s Conditions of Service the Customer agrees to
purchase any power which it requires for the Feed in Tariff (FIT) Facility from the
Distributor under Standard Supply Service or pursuant to any contract which is entered
into by the Distributor and the Customer for that purpose.
2.
The OPA will pay the Supplier any amounts owing under the FIT Contract through
settlement between the Supplier and the applicable LDC on a periodic basis in
accordance with the applicable LDC’s monthly, quarterly or other periodic billing cycle.
In the event that the Facility is connected and in operation prior and/or post the term of
the OPA contract date(s) then, in accordance with the Retail Settlement Code the
Distributor agrees to purchase from the Customer all electrical energy (kWh) supplied by
FIT Facility to the Distributor at the Ownership Demarcation Point in a given settlement
hour and agrees to pay the Customer the Hourly Ontario Energy Price (HOEP) as
published by the IESO (or such other price that reflects the price the Distributor pays the
IESO, as set out in the Code as it may be amended from time to time).
3.
The supplier agrees to pay to the LDC the Ontario Energy Board (OEB) approved
monthly fixed rate in accordance with approved rate application processes.
4.
The Supplier shall provide any necessary documentation in order to establish an HST
exemption.
5.
Settlement invoices and payments shall be issued by the Distributor. Unless otherwise
agreed to by the Parties, any invoice is subject to adjustment for errors in arithmetic,
computation, meter reading corrections and estimates and the application of awards or
penalties resulting from settlement payment disputes between the Distributor and the
IESO and/or the OPA. Any adjustments for errors will be made in the month following
the month in which the error was first detected by the Distributor or first brought to the
attention of the Distributor. Any adjustments resulting from the application of awards or
penalties related to settlement payment disputes between the Distributor and the IESO
and/or OPA will be made in the month following the month in which the Distributor
received the award or penalty.
6.
Each Party must notify the other of any billing statement errors. The Distributor, at its
sole discretion, will make adjustments to any billing statements affected within the month
following the month in which the dispute is settled with the IESO and the Distributor is
first notified in writing by the IESO and/or OPA.
7.
The Customer shall select the method of payment as either in the form of Pre-authorized
Payment or cheque and inform the Distributor of its preferred method of payment. All
electronic payments made by the Distributor to the Customer shall be sent to the
Customer’s designated bank account with a statement to the address provided by the
Customer by mail. All cheque payments made by the Distributor to the Customer shall be
sent together with a statement to the address provided by the Customer by mail. The
Customer may change the bank account or the address to which payments are to be made
hereunder upon thirty (30) Business Days written notice to the Distributor, unless the
Parties agree otherwise.
8.
All FIT Generators will be responsible for load charges as per their rate classificiation
according to their load requirements.
SCHEDULE F
Contacts for Notice (section 12.1)
POWERSTREAM CONTACTS
PowerStream Inc.
161 Cityview Blvd., Vaughan, ON, L4H 0A9
Contact
Business
Fax
1-877-777-3810
(905) 532-4481
(905) 532-4511
(905) 532-4555
1-877-963-6900, ext. 5012
905-513-4135
(905) 532-4490
(905) 532-4481
System Controller
Anytime
Customer Relations Manager
Customer Relations
Representative
System Control Manager
GENERATOR CONTACTS
_______________________
________________________________________________
Contact
Business
Cell
Fax
SCHEDULE G
Dispute Resolution (section 16.1)
G.1
The Party claiming a dispute will provide written notice to the other Party. The
Parties will make reasonable efforts through or by their respective senior
executives to resolve any dispute within sixty days of receipt of such notice.
G.2
If a dispute is settled by the senior executives of the Parties, the Parties shall
prepare and execute minutes setting forth the terms of the settlement. Such
terms shall bind the Parties. The subject-matter of the dispute shall not thereafter
be the subject of any civil or other proceeding, other than in relation to the
enforcement of the terms of the settlement. If a Party fails to comply with the
terms of settlement, the other Party may submit the matter to arbitration under
section G.3. A copy of the minutes referred to in this section from which all
confidential information has been expunged shall be made available to the public
by the Distributor upon request.
G.3
If the senior executives of the Parties cannot resolve the dispute within the time
period set out in section G.1 or such longer or shorter period as the Parties
may agree, either Party may submit the dispute to binding arbitration under
sections G.4 to G.8 by notice to the other Party.
G.4
The Parties shall use good faith efforts to appoint a single arbitrator for purposes
of the arbitration of the dispute. If the Parties fail to agree upon a single arbitrator
within ten working days of the date of the notice referred to in section G.3, each
Party shall within five working days thereafter choose one arbitrator. The two
arbitrators so chosen shall within fifteen working days select a third arbitrator.
G.5
Where a Party has failed to choose an arbitrator under section G.4 within the
time allowed, the other Party may apply to a court to appoint a single arbitrator to
resolve the dispute.
G.6
A person may be appointed as an arbitrator if that person:
(a)
(b)
(c)
is independent of the Parties;
has no current or past substantial business or financial relationship with either
Party, except for prior arbitration; and
is qualified by education or experience to resolve the dispute.
G.7
The arbitrator(s) shall provide each of the Parties with an opportunity to be
heard orally and/or in writing, as may be appropriate to the nature of the dispute.
G.8
The Arbitration Act, 1991 (Ontario) shall apply to an arbitration conducted under
this Schedule G.
G.9
The decision of the arbitrator(s) shall be final and binding on the Parties and may
be enforced in accordance with the provisions of the Arbitration Act, 1991
(Ontario). The Party against which the decision is enforced shall bear all costs
and expenses reasonably incurred by the other Party in enforcing the decision.
G.10
A copy of the decision of the arbitrator(s) from which any confidential information
has been expunged shall be made available to the public by the Distributor
upon request.
G.11 Subject to section G.12, each Party shall be responsible for its own costs and
expenses incurred in the arbitration of a dispute and for the costs and expenses
of the arbitrator(s) if appointed to resolve the dispute.
G.12 The arbitrator(s) may, if the arbitrator(s) consider it just and reasonable to do so,
make an award of costs against or in favour of a Party to the dispute. Such an
award of costs may relate to either or both the costs and expenses of the
arbitrator(s) and the costs and expenses of the Parties to the dispute.
G.13
If a dispute is settled by the Parties during the course of an arbitration, the
Parties shall prepare and execute minutes setting forth the terms of the
settlement. Such terms shall bind the Parties, and either Party may request that
the arbitrator(s) record the settlement in the form of an award under section 36
of the Arbitration Act, 1991 (Ontario). The subject-matter of the dispute shall not
thereafter be the subject of any civil or other proceeding, other than in relation
to the enforcement of the terms of the settlement.
G.14
If a Party fails to comply with the terms of settlement referred to in section
G.13, the other Party may submit the matter to arbitration under section G.3 if
the settlement has not been recorded in the form of an award under section
36 of the Arbitration Act, 1991 (Ontario).
G.15.
A copy of the minutes referred to in section G.13 from which all confidential
information has been expunged shall be made available to the public by the
Distributor upon request.
G.16
The Parties may not, by means of the settlement of a dispute under section
G.2 or section G.13, agree to terms or conditions that are inconsistent with or
contrary to the Code or this Agreement.
SCHEDULE H
Provisions Applicable if Facility Financed by a Lender (sections 19.3, 20.3 and
21.1)
H.1
For the purposes of this Schedule, "lender" means a bank or other entity
whose principal business in that of a financial institution and that is
financing or refinancing the Facility.
H.2
Where notice of a Default has been served on the Customer under section
19.3, an agent or trustee for and on behalf of a lender ("Security Trustee")
or a receiver appointed by the Security Trustee ("Receiver") shall upon
notice to the Distributor be entitled (but not obligated) to exercise all of the
rights and obligations of the Customer under this Agreement and shall be
entitled to remedy the Default specified in the notice within the applicable
cure period referred to in section
19.4. The Distributor shall accept performance of the Customer's
obligations under this Agreement by the Security Trustee or Receiver in
lieu of the Customer's performance of such obligations, and will not
exercise any right to terminate this Agreement under section 19.3 due to
a Default if the Security Trustee, its nominee or transferee, or the
Receiver acknowledges its intention to be bound by the terms of this
Agreement and such acknowledgment is received within 30 days of the
date of receipt by the Customer of the notice of Default.
H.3
The Customer may, without the prior written consent of the Distributor,
assign by way of security only all or any part of its rights or obligations
under this Agreement to a lender. The Customer shall promptly notify the
Distributor upon making any such assignment.
H.4
The Customer may disclose confidential information of the Distributor to a
lender or a prospective lender.
Ref #2
Schedule C
14
Appendix 3(i) – Form A – Pre-FIT Consultation Application
Form A – Pre-FIT Consultation Application
This application form is for generators applying for a Pre-FIT Consultation. Email your completed Form A to
PowerStream at egconnect@powerstream.ca. If you wish to fax your completed Form A to PowerStream, please
do so at 905-532-4447 to the attention of Stations Design and Construction – Embedded Generation.
IMPORTANT: All fields below are mandatory, except where noted. Incomplete applications may be returned by
PowerStream.
1. Project Name:
My project is:
Project size:
Distribution Connected
Transmission Connected
Generator connecting on:
single phase
Proposed total capacity:
three phase
kW
2. Project Location: City / Town / Township
Address
Postal Code
Please provide a site plan with approximate line routings for connecting to nearby PowerStream facilities. The
site plan should include roads, concession and lot numbers (if applicable).
3. Project Contact Information:
Choose a single point of contact:
Owner
Owner
(mandatory)
Consultant
Consultant
(optional)
Company
Contact - first name
Contact – last name
Mailing address
Town / City
Postal Code
Telephone
Fax
Email
Preferred method of contact with PowerStream:
4. Project Type:
(Select one only)
Email
Telephone
Postal Mail
Wind Turbine
Hydraulic Turbine
Steam Turbine
Solar
Diesel Engine
Gas Turbine
Fuel Cell
Biomass
Anaerobic Digester
Bio-Diesel
Other (please specify)
Fax
Co-generation/CHP (combined heat and power)
5. Machine Characteristics:
Machine starting inrush current:
Rotating machine type:
PowerStream Inc.
Form A – Pre-FIT Consultation
October 2009 – rev 1.1
Synchronous
Induction
Inverter-type
Page 1 of 1
Appendix 3(ii) - Form B – Connection Impact Assessment Application
Form B - Connection Impact Assessment Application
This application form is for generators applying for Connection Impact Assessment (CIA) and for generators with
a project size greater than 10 kW. This application form is required for:



New generators applying for CIA
New generators applying for revision to their original CIA
Generators applying for CIA after rescinding a previous CIA. Note: Include your previous CIA Project ID#
below.
For generation size less than or equal to 10 kW, complete Form C - Micro-Generation Connection Application.
IMPORTANT: All fields below are mandatory, except where noted. Incomplete applications may be returned by
PowerStream.
If you have any questions contact PowerStream by email to egconnect@powerstream.ca or telephone 1-877-963-6900
extension 25001.
Return the completed form, fees and other required documents by mail, email or fax to:
PowerStream Inc.
Stations Design and Standards – Embedded Generation
161 Cityview Boulevard,
Vaughan, Ontario, L4H 0A9
Email: egconnect@powerstream.ca
Fax: 905-532-4447 – Attention: Stations Design and Standards – Embedded Generation
NOTE 1: Applications are cautioned NOT to incur major expenses until PowerStream approves to connect the
proposed generation facility.
NOTE 2: All technical submissions (Form B, single line diagrams, etc.) must be signed and sealed by a licensed
Ontario Professional Engineer (P.Eng.).
Date:
(dd/mm/yyyy)
1. Application Type:
New CIA Application
CIA Revision / Rework
Original CIA Project ID# (if applicable):
Project Name:
2. Ontario Power Authority Feed-In Tariff (FIT) Contract #:
3. Proposed In-Service Date:
4. Project Size:
(dd/mm/yyyy)
Number of units
Nameplate rating of each unit
Generator connecting on
Existing total nameplate capacity
Proposed total nameplate capacity
PowerStream Inc.
Form B – Connection Impact Assessment Application
October 2014 – rev 1.6
kW
single phase
kW
kW
three phase
Page 1 of 9
Form B - Connection Impact Assessment Application
5. Project Location: Address
City / Town / Township
Lot Number (s)
Concession number(s)
6. Project Contact Information:
GPS coordinates
Choose a single point of contact:
Generator
(mandatory)
Owner
Consultant
Owner
(mandatory)
Consultant
(optional)
Company / Person
Contact Person
Mailing address line 1
Mailing address line 2
Telephone
Postal Code
Cell
Fax
Email
Preferred method of contact with PowerStream:
Email
Telephone
Postal Mail
Fax
7. Program Type:
A. Net Metering
B. FIT
C. Load Displacement
C. CHP
D. Energy Storage
E. Other (please specify) ________________
8. Fuel Type:
A. Existing:
Wind Turbine
Hydraulic Turbine
Steam Turbine
Solar/Photovoltaic
Diesel Engine
Gas Turbine
Fuel Cell
Biomass
Anaerobic Digester
Bio-Diesel
Other (please specify)
Co-generation/CHP (combined heat and power)
B. New:
Wind Turbine
Hydraulic Turbine
Steam Turbine
Solar/Photovoltaic
Diesel Engine
Gas Turbine
Fuel Cell
Biomass
Anaerobic Digester
Bio-Diesel
Other (please specify)
Co-generation/CHP (combined heat and power)
PowerStream Inc.
Form B – Connection Impact Assessment Application
October 2014 – rev 1.6
Page 2 of 9
Form B - Connection Impact Assessment Application
9. Customer Status
Are you an existing PowerStream customer?
If yes, PowerStream 12-digit account number:
Customer name registered on this account:
Are you a Goods and Service Tax (GST) registrant?
If yes, provide your GST registration number:
Yes
Yes
-
No
No
RT
10. Location and Site Plan:
Provide site plan with approximate line routings for connection to nearby PowerStream facilities. The site
plan should include roads, concession and lot numbers and nearby power lines. It should identify the Point of
Common Coupling (PCC) location on the PowerStream feeder and the location (i.e. on private property or
municipal property) of all generator lines (collector lines and transmission / distribution lines).
Drawing / Sketch number:
, Rev.
11. Connection to PowerStream’s Distribution System:
a.
b.
c.
d.
Proposed or existing connection voltage to PowerStream’s distribution system:
kV
Station:
Feeder:
Distance between the connection point on the feeder (PCC) and the demarcation point between the
utility and distributed generation ‘owned’ Electrical Safety Authority approved load break switch
(located on source side of metering, breaker, interface transformer, etc.):
km
e. If line tap required: Line tap between generating facility demarcation point (load break switch and
metering) and connection point on PowerStream’s feeder (PCC):
Conductor size (e.g. 366):
Conductor type (e.g. AL):
Note: PowerStream may request actual impedance for non-standard conductors at a later time.
f. PCC GPS coordinates:
g. Route distance from PCC (if distance from PCC to generator > 500m) to generation site:
km
h. Line tap to be built by:
PowerStream (see Note) OR
other (specify):
i. Line tap to be owned by:
PowerStream (see Note) OR
other (specify):
NOTE: Customers requiring line tap construction between their demarcation point and the connection point on the
PowerStream feeder should contact PowerStream to discuss potential ownership options, construction and coordination
logistics for these facilities. Also, those customers whom may require attaching collector lines to PowerStream poles
must also contact PowerStream to discuss potential to engage in joint use of utility assets.
PowerStream will consider owning and operating all new lines if they are designed and constructed to PowerStream
standards and are located on municipal roadway right-of-ways. This may change your PCC location. You must contact
PowerStream to discuss. For details email egconnect@powerstream.ca or call 1-877-963-6900, extension 25001.
12. Single Line Diagram (SLD):
Provide a SLD of the generating facility including the Interface Point / PCC to PowerStream’s distribution
system.
SLD drawing number:
, Rev.
PowerStream Inc.
Form B – Connection Impact Assessment Application
October 2014 – rev 1.6
Page 3 of 9
Form B - Connection Impact Assessment Application
13. Protection Philosophy:

Provide a document describing the protection philosophy for detecting and clearing:
- internal faults within the embedded generation facility;
- external phase and ground faults (in PowerStream’s distribution system);
- certain abnormal system conditions such as over/under voltage , over/under frequency, open phase(s);
- islanding
Document Number:

, Rev.
Include a tripping matrix or similar information in the document.
Note: Embedded generator shall install utility grade relays for the interface protection. The protection
design shall incorporate facilities for testing and calibrating the relays by secondary injection.
14. Generator Characteristics
NOTE: Inverter-based generating units must not inject DC greater than 0.5% of the full rated output
current at the point of connection of the generating units. The generated harmonic levels must not
exceed those given in the CAN/CSA-C61000-3-6 Standards.
No existing generators (if chosen, part a. is optional)
a. Characteristics of Existing Generators (if applicable):
1.
2.
3.
4.
5.
6.
7.
8.
9.
Number of generating unit(s):
Manufacturer / Type or Model No:
/
Rated capacity of each unit:
kW
kVA
If unit outputs are different, fill in additional sheets to provide the information.
Rated frequency:
Hz
Rotating machine type:
Synchronous
Induction
Other (specify)
Generator connecting on:
single phase
three phase
Limits of range of reactive power at the machine output:
Lagging (over-excited)
kVAR
power factor
Leading (under-excited)
kVAR
power factor
Limits of range of reactive power at the PCC:
Lagging (over-excited)
kVAR
power factor
Leading (under-excited)
kVAR
power factor
Starting inrush current:
pu (multiple of full load current)
For SPC/Inverter Type Units:
i. Terminal voltage:
ii. Line –interactive type (i.e. intended for
parallel operation with electric utility)
iii. Power factor
iv. Battery backup provided
v. Maximum fault current for terminal faults
vi. Standards according to which built
vii. Provide Manufacturer’s technical brochure
and specification sheet
PowerStream Inc.
Form B – Connection Impact Assessment Application
October 2014 – rev 1.6
V
Yes
No
Yes
A
No
Page 4 of 9
Form B - Connection Impact Assessment Application
For Synchronous Units:
i.
ii.
iii.
iv.
Nominal machine voltage:
kV
Minimum power limit for stable operation
kW
Unsaturated reactances on:
kVA base
Direct axis subtransient reactance, Xd”
pu
Direct axis transient reactance, Xd’
pu
Direct axis synchronous reactance, Xd
pu
Zero sequence reactance, X0
pu
Provide a plot of generator capability curve (MW output vs MVAR)
Document Number:
, Rev.
kV base
For Induction Units:
i.
ii.
iii.
Nominal machine voltage:
kV
Unsaturated reactances on:
kVA base
kV base
Direct axis subtransient reactance, Xd”
pu
Direct axis transient reactance, Xd’
pu
Total power factor correction installed:
kVAR
- Number of regulating steps
- Power factor correction switched per step
kVAR
- Power factor correction capacitors are automatically switched off when generator breaker
opens
Yes
No
b. Characteristics of New Generators:
10.
11.
12.
13.
14.
15.
16.
17.
18.
Number of generating unit(s):
Manufacturer / Type or Model No:
/
Rated capacity of each unit:
kW
kVA
If unit outputs are different, fill in additional sheet to provide the information.
Rated frequency:
Hz
Rotating machine type:
Synchronous
Induction
Other (specify)
Generator connecting on:
single phase
three phase
Limits of range of reactive power at the machine output:
Lagging (over-excited)
kVAR
power factor
Leading (under-excited)
kVAR
power factor
Limits of range of reactive power at the PCC:
Lagging (over-excited)
kVAR
power factor
Leading (under-excited)
kVAR
power factor
Starting inrush current:
pu (multiple of full load current)
For SPC/Inverter Type Units:
viii. Terminal voltage:
ix. Line –interactive type (i.e. intended for
parallel operation with electric utility)
x. Power factor
xi. Battery backup provided
xii. Maximum fault current for terminal faults
xiii. Standards according to which built
xiv. Provide Manufacturer’s technical brochure
and specification sheet
PowerStream Inc.
Form B – Connection Impact Assessment Application
October 2014 – rev 1.6
V
Yes
No
Yes
A
No
Page 5 of 9
Form B - Connection Impact Assessment Application
For Synchronous Units:
v.
vi.
vii.
Nominal machine voltage:
kV
Minimum power limit for stable operation:
kW
Unsaturated reactances on:
kVA base
kV base
Direct axis subtransient reactance, Xd”
pu
Direct axis transient reactance, Xd’
pu
Direct axis synchronous reactance, Xd
pu
Zero sequence reactance, X0
pu
viii. Provide a plot of generator capability curve (MW output vs MVAR)
Document Number:
, Rev.
For Induction Units:
iv.
v.
vi.
Normal machine voltage:
kV
Unsaturated reactances on:
kVA base
kV base
Direct axis subtransient reactance, Xd”
pu
Direct axis transient reactance, Xd’
pu
Total power factor correction installed:
kVAR
- Number of regulating steps
- Power factor correction switched per step
kVAR
- Power factor correction capacitors are automatically switched off when generator breaker
opens
Yes
No
15. Interface Step-Up Transformer Characteristics:
a.
b.
c.
d.
e.
Transformer rating:
Nominal voltage of high voltage winding:
Nominal voltage of low voltage winding:
Transformer type:
Impedances on:
kVA
kV
kV
single phase
kVA base
R
pu,
X
f. High voltage winding connection:
delta
Grounding method of star connected high voltage winding neutral:
solid
ungrounded
impedance:
R
ohms X
g. Low voltage winding connection: :
delta
Grounding method of star connected high voltage winding neutral:
solid
ungrounded
impedance:
R
ohms X
three phase
kV base
pu
star
ohms
star
ohms
NOTE: The term “high voltage” refers to the intermediate voltage that is input into the interface step-up
transformer and “low voltage” refers to the generation or any other intermediate voltage.
16. Intermediate Transformer Characteristics (optional):
No intermediate transformer (if chosen, parts a. to h. are optional)
a.
b.
c.
d.
e.
Transformer rating:
Nominal voltage of high voltage winding:
Nominal voltage of low voltage winding:
Transformer type:
Impedances on:
f.
High voltage winding connection:
R
PowerStream Inc.
Form B – Connection Impact Assessment Application
October 2014 – rev 1.6
kVA
kV
kV
single phase
kVA base
pu,
X
delta
three phase
kV base
pu
star
Page 6 of 9
Form B - Connection Impact Assessment Application
Grounding method of star connected high voltage winding neutral:
solid
ungrounded
impedance:
R
ohms X
g. Low voltage winding connection:
delta
Grounding method of star connected high voltage winding neutral:
solid
ungrounded
impedance:
R
ohms X
ohms
star
ohms
NOTE: The term “high voltage” refers to the intermediate voltage that is input into the interface step-up
transformer and the “low voltage” refers to the generation voltage.
17. Load Information (optional):
a. Maximum load of the facility:
kVA
kW
b. Maximum load current (referred to the nominal voltage at the connection point to PowerStream system):
A
c. Maximum inrush current (referred to the nominal voltage at the connection point to PowerStream system):
A
Attached Documents:
Item #
Description
Reference Number
Number
of pages
Description
Reference Number
Number
of pages
1.
2.
3.
4.
5.
Attached Drawings:
Item #
1.
2.
3.
4.
5.
Check List:
Please ensure the following items are completed prior to submission. Your application will not be processed if any
part is omitted or incomplete:
 Form B – Connection Impact Assessment Application, stamped by a Professional Engineer (P. Eng.)
 Single Line Diagram, stamped by a Professional Engineer (P. Eng.)
PowerStream Inc.
Form B – Connection Impact Assessment Application
October 2014 – rev 1.6
Page 7 of 9
Form B - Connection Impact Assessment Application
Appendix A: Minimum Generation Output Information required for Load Displacement Generation Facilities
Figure A: Example Schedule with Minimum Information required for Load Displacement Projects
Load of
Facility
(kVAR,
lead or lag)
Load of
Facility
(kW)
Generation
Output (kW)
Generation
Output (kVAR,
lead or lag)
Maximum Load
Minimum Load
Appendix B: Minimum Control Strategy Information required for Energy Storage Facilities
Figure B-1: Peak Shaving
Peak Shaving
Description of Control
Strategy
When operating as a load
Switch In Time
Switch Out Time
Load kW (peak)
Load kVAR (peak,
leading/lagging)
When operating as a generator
Switch In Time
Switch Out Time
Generation kW (peak)
Generation kVAR (peak,
leading/lagging)
Figure B-2: Dynamic VAR Support
Dynamic VAR Support
Description of Control
Strategy
Switch In Condition
Switch Out
Condition
PowerStream Inc.
Form B – Connection Impact Assessment Application
October 2014 – rev 1.6
Generation kW (peak)
Generation kVAR (peak,
leading/lagging)
Page 8 of 9
Form B - Connection Impact Assessment Application
Figure B-3: Frequency Support
Frequency Support
Description of Control
Strategy
Switch In Condition
Switch Out
Condition
Generation kW (peak)
Generation kVAR (peak,
leading/lagging)
Figure B-4: Other
Other
Description of Control
Strategy and relevant
operating parameters
PowerStream Inc.
Form B – Connection Impact Assessment Application
October 2014 – rev 1.6
Page 9 of 9
Appendix 3(iii) – Form C - Micro-Generation Connection Application
Form C - Micro-Generation Connection Application
For Connection of Micro-Generation Facilities of ≤ 10kW
This form is applicable to individual or multiple generating units at the customer’s facility with a total
nameplate rating of 10 kW or less. Your generation facility must generate electricity from a renewable energy
source that is wind, water, solar radiation, or agricultural biomass.
Inverter-based generating units must not inject DC greater than 0.5% of the full rated output current at the
point of connection of the generating units. The generated harmonic levels must not exceed those given in the
CAN/CSA-C61000-3-6 Standards.
For generation size up to 10 kW, a Connection Impact Assessment will not be required and PowerStream will not
perform such an assessment. There may be a limitation on the number of micro-generation facilities that can be
connected to the same distribution feeder.
IMPORTANT: All fields below are mandatory, except where noted. Incomplete applications may be returned by
PowerStream.
If you have any questions contact PowerStream by email to egconnect@powerstream.ca or telephone 1-877-963-6900
extension 25001.
Return the completed form, fees and other required documents by mail, email or fax to:
PowerStream Inc.
Stations Design and Standards – Embedded Generation
161 Cityview Boulevard,
Vaughan, Ontario, L4H 0A9
Email: egconnect@powerstream.ca
Fax: 905-532-4447 – Attention: Stations Design and Standards – Embedded Generation
NOTE: Applications are cautioned NOT to incur major expenses until PowerStream approves to connect the proposed
generation facility.
Date:
(dd/mm/yyyy)
1. microFIT Reference Number:
(not required for Net Metering applications)
2. Project / Customer Name:
3. Proposed In-Service Date:
(dd/mm/yyyy)
4. Project Information
Owner
(mandatory)
Engineering Consultant (Electrical)
(optional)
Company / Person
Contact
Mailing address line 1
Mailing address line 2
Telephone
Cell
Fax
Email
PowerStream Inc.
Form C – Micro-Generation Connection Application
October 2014 – rev 1.5
Page 1 of 4
Form C - Micro-Generation Connection Application
For Connection of Micro-Generation Facilities of ≤ 10kW
5. Project Location: Address
City / Town / Township
Lot number(s)
Concession number(s)
6. Connection to PowerStream’s Distribution System:
a. Connection voltage to PowerStream’s distribution system:
b. Station:
c. Feeder:
kV
7. Program Type:
A.
microFIT (complete all sections)
B. Net Metering to microFIT Conversion
i.
Existing Net Metering customer upgrading generation size and/or technology/fuel type, up
to 10 kW (complete all sections)
ii.
Existing Net Metering customer with no upgrades in generation size and/or technology/fuel type,
up to 10 kW (complete sections 6, 7 and 8 only)
C.
Net Metering (complete all sections)
D.
Load Displacement
8. Customer Status
Are you an existing PowerStream customer?
If yes, PowerStream 12-digit account number:
Customer name registered on this account:
Are you a Goods and Service Tax (GST) registrant?
If yes, provide your GST registration number:
Yes
Yes
-
No
No
RT
9. Project Size:
Number of units
Nameplate rating of each unit
Generator connecting on
Existing total nameplate capacity
Proposed total nameplate capacity
kW
single phase
kW
kW
three phase
10. Fuel Type:
Wind Turbine
Solar/Photovoltaic Cells – rooftop
Biomass
Bio-gas
PowerStream Inc.
Form C – Micro-Generation Connection Application
October 2014 – rev 1.5
Hydraulic Turbine
Solar/Photovoltaic Cells – ground mount
Bio-diesel
Other (please specify)
Page 2 of 4
Form C - Micro-Generation Connection Application
For Connection of Micro-Generation Facilities of ≤ 10kW
11. Customer Owned Step-up Interface Transformer (if applicable):
a. Transformer rating:
kVA
b. High voltage winding connection:
Delta
Star
Grounding method of star connected high voltage winding neutral
Solid
Ungrounded
Impedance grounded: R
c. Low voltage winding connection:
Delta
Star
Grounding method of star connected high voltage winding neutral
Solid
Ungrounded
X
Impedance grounded: R
ohms
X
ohms
Note: The term “high voltage” refers to the connection voltage to PowerStream’s distribution system and
“low voltage” refers to the generator / inverter output voltage.
12. Generator / Inverter Information:
(For generation facilities installing more than one type of generator, complete section 10.)
a.
b.
c.
d.
e.
f.
g.
Manufacturer:
Model Number:
Number of phases:
single phase
three phase
Nameplate rating:
kW
Generator/Inverter AC output voltage:
Volts
Type of inverter:
Self-commutated
Line-commutated
Other (specify)
Are power factor correction capacitors automatically switched off when generator breaker opens?
Yes
No
h. Is the generator/inverter paralleling equipment and/or design pre-certified and meets anti-islanding test
requirements?
Yes
No
i. If answer to the above question is Yes, to which standard(s)? e.g. CSA C22.2 No.107.1-01, UL1741, etc.
j. Method of synchronizing the generator/inverter to PowerStream’s system?
k. Maximum inrush current upon generator or inverter connections (I inrush/Irated)
Manual
per unit
Automatic
13. Grid Interface Controller (if applicable):
a. Manufacturer:
Model Number:
14. Type of Connection:
Select the Single Line Diagram below that is appropriate for your connection to the PowerStream distribution
system.
a.
b.
Diagram 1 – Net Metering Connection
Diagram 2 – Parallel Metering Connection
PowerStream Inc.
Form C – Micro-Generation Connection Application
October 2014 – rev 1.5
Page 3 of 4
Form C - Micro-Generation Connection Application
For Connection of Micro-Generation Facilities of ≤ 10kW
a. Diagram 1 – Net Metering Connection
b. Diagram 2 – Parallel Metering Connection
By submitting a Form C, the Proponent authorized the collection by PowerStream of the information set out in the
Form C and other wise collected in accordance with the terms thereof, the terms of PowerStream’s Conditions of
Service, PowerStream’s Privacy Policy and the requirements of the Distribution System Code and the use of such
information for the purposes of the connection of the generation facility to PowerStream’s distribution system.
PowerStream Inc.
Form C – Micro-Generation Connection Application
October 2014 – rev 1.5
Page 4 of 4
Appendix 3(iv) - MicroFIT Generator Information Package
Information Package
microFIT Generator (≤10kW)
Prepared by: Station Design – Embedded Generation
Revision: 2
Date: June 2013
microFIT Generators
Information Package
Revision 2
This guideline provides a set of references that are intended to familiarize PowerStream customers with the
overall process, requirements, and approvals that apply to embedded generators connecting on the
PowerStream distribution or the sub-transmission system. This is a guide only; final design approval for all
generators will be made by the Embedded Generation Department.
Contents:
1.
2.
3.
4.
5.
Connection Process
Estimated Costs
Reference Links
PowerStream Contact Information
Design Requirements
Single Phase Design
Single Phase Metering
Three Phase Design
Three Phase Metering
Appendix:
A.
B.
C.
D.
E.
F.
G.
H.
I.
J.
K.
L.
Construction Standard 25-130 A-120/240V Residential Meter Socket
Construction Standard 25-230 - Commercial / Industrial Meter Socket
Sample Installation Photos with lamacoid plates
Ontario Electrical Safety Code-Bulletin 50-1-2 - Tapping Into Load Side Disconnect Reference
Construction Standard 25-100 A - Dual Metering Wiring Schematic
Construction Standard 25-100 B - 400 Amps Meter Base
Commissioning Verification Form
Connection Agreement Sample
Single Phase Sample SLD
Three Phase Sample SLD
Net Metering/ Load Displacement Single Phase Sample SLD
Net Metering/ Load Displacement Three Phase Sample SLD
2 of 18
microFIT Generators
Information Package
Revision 2
1. Connection Process - microFIT
The following is the connection process overview for generators that are less than or equal to 10kW and
operate at voltages below 50kV:
a) Customer (Generator) proposing the installation of a generation facility with PowerStream must
first contact the Ontario Power Authority (OPA) and complete their microFIT application.
b) OPA issues the project a 7-digit microFIT reference number when the application is processed.
c) Customer submits a Connection Request to PowerStream when the project’s application status is
set to “Pending LDC Offer to Connect”. (Connection Request consists of Form C-Micro
Generation Connection Application and Single Line Diagram).
d) PowerStream notifies the OPA when the Connection Request Package is received.
e) PowerStream provides a Service Design (Offer to Connect) to the customer with the necessary
design requirements and construction costs to connect the generator.
f) PowerStream informs the OPA when the Connection Request is approved.
g) Customer reviews PowerStream requirements and develops an installation plan following receipt
of the Application Approval Notice from the OPA.
h) Customer pays PowerStream fees as per the Service Design.
i) Customer installs the project.
j) Customer makes an appointment with New Connections for the Disconnect/ Reconnect.
k) Generation site approval by ESA.
l) PowerStream installs generation meter.
m) Customer completes the Commissioning Verification Form and submits to PowerStream.
n) PowerStream issues a Connection Agreement to the customer.
o) Customer signs and returns the Connection Agreement to PowerStream.
p) PowerStream updates the OPA with the project’s connected status.
q) OPA issues a Contract to the customer.
r) Customer accepts the OPA Contract.
s) OPA informs PowerStream of a new OPA Contract.
t) PowerStream starts payments as per PowerStream billing cycle.
2. Estimated Costs
The following are the estimated customer connection costs as of the creation date of this document
(These costs are for reference only, actual costs will be provided on the PowerStream service layout):
a) $625.00 (approximate), for new meter with installation
b) $30.00, new account fee (one time)
c) $5.25, monthly service charge
3 of 18
microFIT Generators
Information Package
Revision 2
3. Reference Links
PowerStream:
a) PowerStream’s Embedded Generation Home Page:
http://www.powerstream.ca/app/pages/connecting-gen.jsp
b) PowerStream’s “How to connect a generator to PowerStream’s distribution through the FIT and
microFIT programs of the Ontario Power Authority (OPA)”:
http://www.powerstream.ca/app/pages/EG_Overview.jsp
c) Conditions of Service:
http://www.powerstream.ca/app/pages/Conditions-2010.jsp
d) Form C - micro-Generations Connection Application:
http://www.powerstream.ca/ContentMgr/attachments/FormC-v1-5.doc
Ontario Power Authority:
microFIT Rules:
http://microfit.powerauthority.on.ca/program-rules
4. PowerStream Contact Information
a) General Information:
Embedded Generation:
Email: egconnect@powerstream.ca
Phone: 1-877-963-6900 x 25001 or x 24545
b)
Disconnect/Reconnect Requests
New Connections:
Phone: 1-877-963-6900 x26572
4 of 18
microFIT Generators
Information Package
Revision 2
5. Design Requirements:
5.1 Single Phase
Single Line Diagram Requirements:
As per sample in Appendix I.
*SLD should include the following items:
•
•
•
•
Show disconnects
Show step-up transformer (if-applicable)
Show meter locations
Show where parallel connections to existing service are to be made.
5.2 Single Phase Metering Requirements:
•
•
•
•
•
•
•
New 2 gang meter socket required, which conforms to PowerStream’s construction standards
(see Appendix A). It is the responsibility of the customer/contractor to ensure existing service
wire can be terminated as is.
Meter base wired according to Standard 25-100A in Appendix E
All metering and disconnect equipment to be located outside and to be accessible to
PowerStream staff.
Micro-generation disconnects to be within 1 meter of micro-generations meter.
ESA inspection required to energize.
PowerStream to install one bi-directional meter.
Clearly label with lamacoid plates (i.e. riveted engraved plates) illustrating the following:
a) Consumption meter
b) Generation meter
c) Micro-generation disconnect
*See Appendix C for installation with lamacoid plates.
.
5 of 18
microFIT Generators
Information Package
Revision 2
5.3 Three Phase
Single Line Diagram Requirements:
As per sample in Appendix I.
*SLD should include the following items:
•
•
•
•
Show two disconnects (one on either side of generation meter)
Show step-up transformer (if-applicable)
Show meter locations in electrical room
Show where parallel connections to existing service are to be made.
5.4 Three Phase Metering Requirements:
Embedded Generation projects can be connected to the following service types:
Service Type
120/208V 3-phase 4-wire WYE
120/208V Network (2-phase 3-wire)
on a 3-phase 4-wire WYE system
347/600 3-phase 4-wire WYE
600V 3-phase 3-wire DELTA
Project
Size
Max Amps
per Phase
<=57kW
160A
Meter Requirements (Use
PowerStream Standards
for details)
7 Jaw Meter Socket Base
<=40kW
160A
5 Jaw Meter Socket Base
<=200A
<=170kW
N/A
160A
N/A
7 Jaw Meter Socket Base
N/A
<=200A
N/A
Disconnect
Size
<=200A
Customer to:
•
•
•
•
Supply and mount a single line diagram and a plan view (showing main service and
generation meter) next to the main meter.
Parallel service connections in switchgear must be made ahead (outside) of the metering
compartment.
Install an isolation device immediately adjacent to microFIT generation metering
cabinet/base on both line and load side.
Ensure location of installed microFIT generation meter socket is building and fire code
compliant, to ensure safe accessibility.
6 of 18
microFIT Generators
Information Package
•
Clearly label with lamacoid plates (i.e. riveted engraved plates) the following:
a)
b)
c)
d)
•
•
Revision 2
Consumption meter
microFIT generation disconnect
Caution – main building service – 2 power supplies
Caution – microFIT generation service – 2 power supplies
ESA to provide connection authorization to PowerStream prior to energization.
Generation will be metered at three phase 347/600V or 120/208V complete with neutral.
PowerStream to:
•
Supply and install one new bi-directional meter for the parallel microFIT metering standard
configuration.
*See Appendix C for installation with lamacoid plates and Appendix D for a sample of connections
to the utility grid, including the main disconnect switch, according to the ESA(2009 – ESA Binder
50-1-1).
5.5 Design Notes:
1. Electrical Hot Splitter Requirements:
PowerStream requires this type of Legacy Design to be upgraded to include a Main
Disconnect prior to the splitter to allow for building isolation.
2. Three Phase Metering:
All three phase metering installations are required to be in electrical rooms. Outside
installations are not acceptable.
7 of 18
microFIT Generators
Information Package
Appendix A - 120/240V Meter Socket Standard
8 of 18
Revision 2
microFIT Generators
Information Package
Appendix B – Meter Socket Installation Design Standard
9 of 18
Revision 2
microFIT Generators
Information Package
Revision 2
Appendix C – Sample Installation Photos
All equipment to be labeled
with lamacoid plates (engraved
and riveted)
Gang meter socket required
standard 25-130 Top of socket 6’
from finished grade
Consumption
meter
Bi-directional
generation meter
Generated power
from inverter
Line side underground feed
from pad-mount
transformer
Micro-generation disconnect to be
installed within 1 meter of meter socket
To breaker panel
in basement
microFIT Generation – Parallel – Single Phase
To be labeled with lamacoid
plates (engraved and riveted)
Disconnect Switch
Disconnect Switch
microFIT Generation – Parallel – Three Phase
10 of 18
microFIT Generators
Information Package
Appendix D – Ontario Electrical Safety Code-Bulletin 50-1-2Tapping into Load Side Disconnect Response (Commercial Application)
11 of 18
Revision 2
microFIT Generators
Information Package
Appendix E – Dual Metering Wiring Schematic Standard
12 of 18
Revision 2
microFIT Generators
Information Package
Appendix F – 400 Amps Meter Base Schematic Standard
13 of 18
Revision 2
microFIT Generators
Information Package
Revision 2
Appendix G – Commissioning Verification Form (≤10KW)
This commissioning verification form is required for inverter-based Micro Embedded Generators applying for
connection with PowerStream. This document must be signed by the contractor or project electrician and the
owner of the project.
Facilities Information
OPA MicroFIT Reference Number
(if applicable)
Project Address
Project Nameplate Capacity (kW)
Commissioning Test Contact Information
Name
Title
Mailing address
Telephone
Email
Commissioning Anti-Islanding Test:
a) Turn Off Utility-Side DG Disconnect:
Verification
Yes/No
Initials
Date
Comments
Yes/No
Initials
Date
Comments
Did the inverter indicate a loss of the utility grid?
After a loss of the utility grid, is there voltage on the
output of the inverter?
Did the inverter shut down as required?
b) Turn On Utility-Side DG Disconnect:
Verification
Did the inverter turn back on upon reconnection with
the utility grid?
Did the inverter return to its normal operating state?
Generator Protective Relay Settings
The inverter-based Micro Embedded Generator must confirm that the inverter equipment meets the IEEE 1547
over/under frequency and over/under voltage protection requirements indicated below.
a. Over Frequency/Under Frequency Protection:
Table 1 – Over/Under Frequency Protection Set Points and Clearing Times
14 of 18
microFIT Generators
Information Package
Revision 2
b. Over voltage/Under voltage Protection:
Table 2 - Over/Under Voltage Protection Setting and Clearing Time
By signing this form, the commissioning test representative acknowledges that all required verifications
specified under this commissioning verification form have been completed and inverter equipment meets the
IEEE 1547 protection requirements outlined in the Generator Protective Relay Settings section of this
document.
_____________________________________________
Signature of Commissioning Test Representative
(Must be the project contractor or project electrician)
__________________________________________
Signature of the owner of the project
____________________________________
Name (Print)
____________________________________
Name (Print)
____________________________________
Title
____________________________________
Date
Return the completed document by mail, email or fax to:
PowerStream Inc.
Stations Design and Construction – Embedded Generation
161 Cityview Boulevard,
Vaughan, Ontario, L4H 0A9
Email: egconnect@powerstream.ca
Fax: 905-532-4447 – Attention: Stations Design and Construction – Embedded Generation
15 of 18
microFIT Generators
Information Package
Revision 2
Appendix H – Micro-Embedded Generation Facility Connection Agreement
In consideration of PowerStream Inc. (PowerStream) agreeing to allow you to connect your 10 kW name-plate rated capacity or
smaller generation facility to the PowerStream’s distribution system, you hereby agree to the following terms and conditions.
1.0
Eligibility
1.1 You agree that your generation connection shall be subject to all applicable laws and bound by the terms and
conditions of the PowerStream’s Conditions of Service as amended from time-to-time, which have been filed with
the OEB and are available on request.
2.0
Technical Requirements
2.1 You represent and warrant that you have installed or will install prior to the connection of your generation facility to
the PowerStream’s distribution system, an isolation device satisfying Section 84 of the Ontario Electrical Safety
Code, located outside typically near the meter, and agree to allow the PowerStream’s staff access to and operation of
this as required for the maintenance and repair of the distribution system.
2.2 You agree to perform regular scheduled maintenance to your generation facility as outlined by the manufacturer in
order to assure that connection devices, protection systems, and control systems are maintained in good working
order and in compliance with all applicable laws.
2.3 You agree that during a power outage on the PowerStream system your generation facility will shut down, unless
you have installed special transfer and isolating capabilities on your generation facility. You agree to the automatic
disconnection of your generation facility from the PowerStream’s distribution system, as per the generator protective
relay settings set out in this Agreement, in the event of a power outage on the PowerStream distribution system or
any abnormal operation of the PowerStream distribution system.
2.4 You covenant and agree that the design, installation, maintenance, and operation of your generation facility are
conducted in a manner that ensures the safety and security of both the generation facility and the PowerStream’s
distribution system.
2.5 Due to PowerStream’s obligation to maintain the safety and reliability of its distribution system, you acknowledge
and agree that in the event PowerStream determines that your generation facility (i) causes damage to; and/or (ii) is
producing adverse effects affecting other distribution system customers or PowerStream’s assets, you will
disconnect your generation facility immediately from the distribution system upon direction from the PowerStream
and correct the problem at your own expense prior to reconnection.
3.0
Liabilities
3.1 You and PowerStream will indemnify and save each other harmless for all damages and/or adverse effects resulting
from either party’s negligence or willful misconduct in the connection and operation of your generation facility or
the PowerStream distribution system.
3.2 PowerStream and you shall not be liable to each other under any circumstances whatsoever for any loss of profits or
revenues, business interruptions losses, loss of contract or loss of goodwill, or for any indirect, consequential,
incidental or special damages, including but not limited to punitive or exemplary damages, whether any of the said
liability, loss or damages arise in contract, tort or otherwise.
16 of 18
microFIT Generators
Information Package
4.0
Revision 2
Compensation and Billing
4.1
If you are not embedded retail generator, you agree that, subject to any applicable law:
a)
PowerStream will not pay you for any excess generation that results in a net delivery to the
PowerStream between meter reads; and
b) There will be no carryover of excess generation from one billing period to the next unless you are, at
the relevant time, a net metered generator (as defined in section 6.7.1 of the Distribution System
Code).
4.2 If you are an embedded retail generator selling output from the embedded generation facility to the Ontario Power
Authority under contract, you agree that PowerStream will pay you for generation in accordance with the Retail
Settlement Code.
4.3 If you are an embedded retail generator selling output to the PowerStream, you agree that PowerStream will pay you
for generation in accordance with the Retail Settlement Code.
5.0
Termination
5.1 You understand that you have the right to terminate this agreement at any time, and that by doing so you are
required to disconnect your generation facility and notify PowerStream of such action.
6.0
Assignment
6.1 You may assign your rights and obligations under this Agreement with the consent of PowerStream, which shall
not withhold its consent unreasonably. PowerStream shall have the right to assign its rights and obligations under
this Agreement without your consent.
I understand, accept and agree to comply with and be bound by the above terms and conditions governing the connection of my
generation facility to the PowerStream distribution system.
Customer Signature: _________________________________
Date: ____________________
Print name: _______________________________________________________________________
PowerStream Account Number:
Billing Address: _____________________________________________________________________
I confirm that the following information is true and accurate:
Nameplate rating of Generator: KW Total installed generation:
Project Location:
Connection Type (Parallel):
OPA Reference number:
Type:
Wind Turbine;
Photovoltaic (Solar);
Other _______________________________
Inverter Utilized:
Yes
No
17 of 18
KW
Hydraulic Turbine;
Fuel Cell;
microFIT Generators
Information Package
Inverter Certification:
C22.2 #107.1
UL 1741
Revision 2
Site Certified by the ESA
For Office use: Feeder: Date Connected:
Generator Protective Relay Settings
Table 1 - Inverter Based Generation
The following relay settings shall be used for inverters built to the CSA standard:
Source: CSA C22.2 No. 107.1-01 Table 16
System Voltage Vn = V
nominal V (Volts)
Frequency
F (Hertz)
Maximum number of cycles to
disconnect
Seconds
Cycle
V < 0.5 Vn
60
0.1
6
0.5 Vn < V < 0.88 Vn
60
2
120
1.10 Vn < V <1.37 Vn
V > 1.37 Vn
Vn
60
60
F < 59.5*
2
0.033
0.1
120
2
6
Vn
F > 60.5
0.1
6
* The UL1741 & IEEE P1547 Standards use F < rated-0.7 i.e. 59.3 Hz. To update if CSA C22.2 No. 107.1-01 is changed
Table 2 - Non - Inverter Generation
Requirements for Non-Inverter based generation are as follows:
System Voltage Vn =V
nominal V (Volts)
Frequency
F (Hertz)
Maximum clearing time*
Seconds
Cycles
V < 0.5 Vn
60
0.16
9.6
0.5 Vn ≤ V < 0.88 Vn
60
2
120
1.10 Vn ≤ V <1.20 Vn
60
1
60
V ≥ 1.20 Vn
60
0.16
9.6
Vn
F < 59.3
0.16
9.6
Vn
F > 60.5
0.16
9.6
*Clearing time is the time between the start of the abnormal condition and the generation ceasing to energize the PowerStream’s
distribution system
-
If you are uncertain about your generation equipment’s protective relay settings, please check with your generating
equipment supplier.
- Automatic reconnect setting time for your generator is after 5 minutes of normal voltage and
frequency on the PowerStream’s distribution system.
18 of 18
Appendix 3(v) - FIT Generator Information Package
Information Package
FIT Generator (>10kW)
Prepared by: Station Design – Embedded Generation
Revision: 1
Date: July 24 2014
Feed-In Tariff (FIT) Generator
Information Package
Revision-1
This guideline provides a set of references that are intended to familiarize PowerStream
customers with the overall process, requirements, and approvals that apply to embedded
generators connecting on the PowerStream distribution or sub-transmission system. This
is a guide only; final design approval for all generators will be made by the Embedded
Generation department.
Contents:
1.
2.
3.
4.
5.
Process
Estimated Costs
Reference Links
PowerStream Contact Information
Design Requirements
5.1
Three Phase Design
5.2
Three Phase Metering
Appendix:
A.
B.
C.
D.
Meter Cabinet Installation Design Standard
Commercial Meter Socket Standard
Sample Installation Photo
Three Phase Sample SLD
2 of 11
Feed-In Tariff (FIT) Generator
Information Package
Revision-1
1. Feed-In Tariff (FIT) Connection Process
The following is the connection process overview for generators that are greater than
10kW and operate at voltages below 50kV:
The PowerStream FIT application process is as follows:
a) Customer completes PowerStream Form A - Pre-FIT Consultation
Application and sends to egconnect@powerstream.ca.
b) PowerStream responds to Form A request with capacity and connection
information.
c) Customer completes an OPA FIT Application using the Form A information
and submits to the OPA.
d) Customer receives an OPA FIT contract number from the OPA and submits a
P.Eng stamped Form B and single line diagram to PowerStream for review.
e) PowerStream reviews application and issues Study Agreement outlining the
CIA (Connection Impact Assessment) cost and timeframe.
f) Customer signs the Study Agreement and makes CIA payment.
g) PowerStream performs CIA and issues report.
h) PowerStream issues a Service Design outlining the meter requirements and
payment information.
i) Once the Service Design payment and ESA approval is received by
PowerStream the meter can be installed.
j) PowerStream metering group installs generator meter.
k) Customer confirms that the phone line is installed and PowerStream is able to
communicate with the Bi-Directional Meter
l) PowerStream requests documentation for Connection Agreement:
1. Single Line Diagram (as built)
2. OPA FIT Contract
3. Contact information
4. Certificate of Insurance
5. Commissioning report
6. Clearing times for inverter trip limits
7. OPA Notice to Proceed
8. Confirmation of completion of Remote Monitoring for FIT projects
greater than 100kW
9. Customer provides OPA COD letter
m) PowerStream sends customer a PowerStream Connection Agreement.
n) Customer to return signed Connection Agreement.
o) PowerStream creates billing account based on OPA COD letter date.
See section 3 for links to Form A and Form B.
3 of 11
Feed-In Tariff (FIT) Generator
Information Package
Revision-1
2. Estimated Costs
a) The CIA fee for a small project (>10kW to <=500kW) is $1,500.00 + HST.
b) New Services Connection Fee for a three phase parallel metering
configuration is estimated at $2,000-$8,000. However, this estimate is subject
to change following a site visit from the metering department, which may
identify a transformer upgrade or any other additional costs.
c) There is a one time account set up fee of $30.00 and an account charge of
$5.25 per month.
3. Reference Links
PowerStream:
Form A - Pre-FIT Consultation Application:
http://www.powerstream.ca/ContentMgr/attachments/FormA-v1-2.doc
Form B - Connection Impact Assessment Application:
http://www.powerstream.ca/ContentMgr/attachments/FormB-v1-4.doc
PowerStream’s Embedded Generation Home Page:
http://www.powerstream.ca/app/pages/connecting-gen.jsp
PowerStream’s “How to connect a generator to PowerStream’s distribution
through the FIT and microFIT programs of the Ontario Power Authority (OPA)”:
http://www.powerstream.ca/app/pages/EG_Overview.jsp
Ontario Power Authority:
FIT Rules:
http://fit.powerauthority.on.ca/program-launch-rules
4 of 11
Feed-In Tariff (FIT) Generator
Information Package
4. PowerStream Contact Information
a. General Information:
Embedded Generation:
Email: egconnect@powerstream.ca
Phone: 1-877-963-6900 x 25001
b. Disconnect/Reconnect Requests
New Connections:
Phone: 1-877-963-6900 x25713
5 of 11
Revision-1
Feed-In Tariff (FIT) Generator
Information Package
Revision-1
5. Design Requirements:
5.1 Three Phase Single Line Diagram Requirements:
As illustrated in Appendix D, the SLD should include the following items:
•
•
•
Meter and disconnects, located in electrical room
Disconnects before and after FIT meter
Indicate location of parallel connection to existing service
5.2 Three Phase Metering Requirements:
Embedded Generation projects can be connected to the following service types:
Table 1: PowerStream FIT Meter and Disconnects
Customer to:
a) Supply and mount a single line diagram and a plan view (showing main
service and generation meter) next to main meter.
b) Parallel service connections in switchgear must be made ahead (outside)
of the metering compartment.
c) Install dedicated analog Bell lines at both meter locations (interval Jack
RJ45).
d) Install an isolation device immediately adjacent to FIT generation
metering cabinet/base on both line and load side (all metering to be inside
main electrical room, see table 1 above for standards)
e) Ensure location of installed FIT generation meter socket is building and
fire code compliant, to ensure safe accessibility.
6 of 11
Feed-In Tariff (FIT) Generator
Information Package
Revision-1
f) Clearly label with lamacoid plates (i.e. riveted engraved plates) the
following:
1. Consumption meter
2. Generation meter
3. FIT generation disconnect
4. Caution – Main building service – 2 power supplies
5. Caution- FIT generation service – 2 power supplies
g) ESA to provide connection authorization to PowerStream prior to
energization.
h) Generation will be metered at three phase 347/600V or 120/208V
complete with neutral.
*See Appendix D for installation with lamacoid plates.
PowerStream to:
a) Supply and install one new bi-directional meter for the parallel FIT
configuration.
7 of 11
Appendix A:
8 of 11
Appendix B:
9 of 11
Appendix C:
FUSABLE
DISCONNECT
DISCONNECT
SWITCH
METERING
CABINET
AC INVERTER
DISCONNECT
LAMACOID
PLATES
Inverter
10 of 11
NOTE:
This sample SLD indicates PowerStream's
layout guidelines for FIT installations.
All projects must be inspected by the ESA.
** REQUIRED DATA FIELDS
Appendix 3(vi) - microFIT Generator Commissioning Verification Form
Commissioning Verification Form (≤10KW)
This commissioning verification form is required for inverter-based Micro Embedded Generators applying for
connection with PowerStream. This document must be signed by the contractor or project electrician and the
owner of the project.
Facilities Information
OPA MicroFIT Reference Number
(if applicable)
Project Address
Project Nameplate Capacity (kW)
Commissioning Test Contact Information
Name
Title
Mailing address
Telephone
Email
Commissioning Anti-Islanding Test:
a) Turn Off Utility-Side DG Disconnect:
Verification
Yes/No
Initials
Date
Comments
Yes/No
Initials
Date
Comments
Did the inverter indicate a loss of the utility grid?
After a loss of the utility grid, is there voltage on the
output of the inverter?
Did the inverter shut down as required?
b) Turn On Utility-Side DG Disconnect:
Verification
Did the inverter turn back on upon reconnection with
the utility grid?
Did the inverter return to its normal operating state?
Generator Protective Relay Settings
The inverter-based Micro Embedded Generator must confirm that the inverter equipment meets the IEEE 1547
over/under frequency and over/under voltage protection requirements indicated below.
PowerStream Inc.
Commissioning Verification Form
July 2012 – rev 1.0
Page 1 of 2
Commissioning Verification Form (≤10KW)
a) Over Frequency/Under Frequency Protection:
Table 1 – Over/Under Frequency Protection Set Points and Clearing Times
b) Over Voltage/Under Voltage Protection:
Table 2 - Over/Under Voltage Protection Setting and Clearing Time
By signing this form, the commissioning test representative and the owner of the project acknowledge that all
required verifications specified under this commissioning verification form have been completed and inverter
equipment meets the IEEE 1547 protection requirements outlined in the Generator Protective Relay Settings
section of this document.
____________________________________________
Signature of Commissioning Test Representative
(Must be the project contractor or project electrician)
___________________________________________
Signature of the owner of the project
____________________________________
Name (Print)
____________________________________
Name (Print)
____________________________________
Title
____________________________________
____________________________________
Date
Date
Return the completed document by mail, email or fax to:
PowerStream Inc.
Stations Design and Construction – Embedded Generation
161 Cityview Boulevard,
Vaughan, Ontario, L4H 0A9
Email: egconnect@powerstream.ca
Fax: 905-532-4447 – Attention: Stations Design and Construction – Embedded Generation
PowerStream Inc.
Commissioning Verification Form
July 2012 – rev 1.0
Page 2 of 2
Appendix 3(vii) - FIT Generator Commissioning Verification Form
Commissioning Verification Form
This commissioning verification form is required for inverter-based FIT generators applying for a Connection
Agreement with PowerStream. This document must be signed and sealed by a licensed Ontario Professional
Engineer (P.Eng.). A system commissioning report must be submitted in addition to this commissioning
verification form.
Facilities Information
OPA FIT Reference Number
Project Address
Project Nameplate Capacity (kW)
Commissioning Test Contact Information
Name
Title
Mailing address
Telephone
Email
Commissioning Tests
1. Anti-Islanding Test
a) Turn Off Utility-Side DG Disconnect:
Verification
Yes/No
Initials
Date
Comments
Yes/No
Initials
Date
Comments
Yes/No
Initials
Date
Comments
Did the inverter indicate a loss of the utility grid?
After a loss of the utility grid, is there voltage on the
output of the inverter?
Did the inverter shut down as required?
b) Turn On Utility-Side DG Disconnect:
Verification
Did the inverter turn back on upon reconnection with
the utility grid?
Did the inverter return to its normal operating state?
2. WiMax Provision Confirmation (if applicable):
a) Provisions for Remote Monitoring:
Verification
Does the inverter support multiple masters?
Does the inverter support DNP3 or Modbus over
Ethernet?
PowerStream Inc.
Commissioning Verification Form
June 2012 – Rev 2.0
Page 1 of 12
Commissioning Verification Form
b) Provisions for Transfer Trip:
Verification
Yes/No
Initials
Date
Comments
Does the inverter support a remote shut down
command via the data port?
3. Generator Protective Relay Settings
The inverter-based FIT generator must confirm that the inverter equipment meets the IEEE 1547 over/under
frequency and over/under voltage protection requirements indicated below.
a. Over Frequency/Under Frequency Protection:
Table 1 – Over/Under Frequency Protection Set Points and Clearing Times
b. Overvoltage/Undervoltage Protection:
Table 2 - Over/Under Voltage Protection Setting and Clearing Time
PowerStream Inc.
Commissioning Verification Form
June 2012 – Rev 2.0
Page 2 of 12
Commissioning Verification Form
By signing this form, the Commissioning Test Representative acknowledges that all required verifications
specified under this commissioning verification form have been completed and inverter equipment meets the
IEEE 1547 protection requirements outlined in the Generator Protective Relay Settings section of this document.
The Commissioning Test Representative acknowledges that the embedded generator meets the minimum
standards for facility design, construction and operation of generation facilities connected to a distribution
system as per the latest revision of the Distribution System Code Appendix F.2 – Technical Requirements
(attached).
_______________________________________________________ (Must affix P.Eng seal)
Signature of Commissioning Test Representative (Must be a P.Eng.)
____________________________________
Name (Print)
____________________________________
Title
____________________________________
Date
Return the completed document by mail, email or fax to:
PowerStream Inc.
Stations Design and Construction – Embedded Generation
161 Cityview Boulevard,
Vaughan, Ontario, L4H 0A9
Email: egconnect@powerstream.ca
Fax: 905-532-4447 – Attention: Stations Design and Construction – Embedded Generation
Check List:
Please ensure the following items are completed prior to submission. Your application will not be processed if any
part is omitted or incomplete:
 Commissioning Verification Form, stamped by a Professional Engineer (P. Eng.)
 System Commissioning Report
PowerStream Inc.
Commissioning Verification Form
June 2012 – Rev 2.0
Page 3 of 12
Commissioning Verification Form
PowerStream Inc.
Commissioning Verification Form
June 2012 – Rev 2.0
Page 4 of 12
Commissioning Verification Form
PowerStream Inc.
Commissioning Verification Form
June 2012 – Rev 2.0
Page 5 of 12
Commissioning Verification Form
PowerStream Inc.
Commissioning Verification Form
June 2012 – Rev 2.0
Page 6 of 12
Commissioning Verification Form
PowerStream Inc.
Commissioning Verification Form
June 2012 – Rev 2.0
Page 7 of 12
Commissioning Verification Form
PowerStream Inc.
Commissioning Verification Form
June 2012 – Rev 2.0
Page 8 of 12
Commissioning Verification Form
PowerStream Inc.
Commissioning Verification Form
June 2012 – Rev 2.0
Page 9 of 12
Commissioning Verification Form
PowerStream Inc.
Commissioning Verification Form
June 2012 – Rev 2.0
Page 10 of 12
Commissioning Verification Form
PowerStream Inc.
Commissioning Verification Form
June 2012 – Rev 2.0
Page 11 of 12
Commissioning Verification Form
PowerStream Inc.
Commissioning Verification Form
June 2012 – Rev 2.0
Page 12 of 12
Appendix 3(viii) - Net Metering Information Package
Net Metering
Information Package
Prepared by: Station Design – Embedded Generation
Revision: 1
Date: April 2014
Net Metering Generators
Information Package
Revision 1
This guideline provides a set of references that are intended to familiarize PowerStream customers with the
overall process, requirements, and approvals that apply to embedded generators connecting on the
PowerStream distribution or the sub-transmission system. This is a guide only; final design approval for all
generators will be made by the Embedded Generation Department.
Contents:
1) Connection Process
a) Micro Embedded Generators (<=10KW)
b) Small Embedded Generators (>10KW and <=500KW)
2) Estimated Costs
a) Micro Embedded Generators
b) Small Embedded Generators
3) Reference Links
4) PowerStream Contact Information
5) Micro Embedded Generator Design Requirements
a) Single Phase Design
b) Single Phase Metering
c) Three Phase Design
d) Three Phase Metering
e) Design Notes
6) Small Embedded Generator Design Requirements
a) Three Phase Design
b) Three Phase Metering
7) Appendices
Appendices:
A.
B.
C.
D.
E.
F.
G.
H.
I.
Construction Standard 25-130 - 120/240V Residential Meter Socket
Construction Standard 25-200 – Meter Cabinet Installation
Construction Standard 25-230 - Commercial / Industrial Meter Socket
Sample Installation With Lamacoid Plates
Commissioning Verification Form
Connection Agreement Sample
Net Metering/ Load Displacement Single Phase Sample SLD
Net Metering/ Load Displacement Three Phase Sample SLD
Net Metering-microFIT Single Phase Sample SLD
2 of 21
Net Metering Generators
Information Package
Revision 1
1. Connection Process
a. Micro Embedded Generator (<=10KW)
The following is the connection process overview for generators that are less than or equal to 10kW and
operate at voltages below 50kV:
a) Customer completes and submits a Form C-Micro Generation Connection Application and
Single Line Diagram (SLD) to PowerStream at egconnect@powerstream.ca.
b) PowerStream provides a Service Design to the customer with the necessary design requirements
and construction costs to connect the generator.
c) Customer reviews PowerStream requirements and develops an installation plan.
d) Customer pays PowerStream construction costs as per the Service Design.
e) Customer installs the project.
f) Generation site approval by ESA.
g) PowerStream installs bi-directional meter.
h) Customer completes PowerStream Commissioning Verification Form and submits to
PowerStream.
i) PowerStream issues a Connection Agreement to the customer.
j) Customer signs and returns the Connection Agreement to PowerStream.
k) Customer will receive a credit toward future energy bills. The credit can be carried forward for
up to 12 months.
See Section 3 for a link to the Form C.
b. Small Embedded Generator (>10KW and <=500KW)
The following is the connection process overview for generators that are greater than 10kW and less
than or equal to 500kW and operate at voltages below 50kV:
a) Customer completes and submits a P.Eng stamped Form B-Connection Impact Assessment
Application (indicating Net Metering on page 2) and SLD to Powerstream at
egconnect@powerstream.ca.
b) PowerStream reviews application and issues Study Agreement outlining the outlining the CIA
(Connection Impact Assessment) cost and timeframe for the Net Metering project.
c) Customer executes the Study Agreement and makes the CIA payment.
d) PowerStream performs CIA and issues report.
e) PowerStream may issue a Service Design (dependent on the metering requirement - if a new
bidirectional meter is required, a Service Design will be issued) outlining the meter requirements
and payment information.
f) Once the Service Design payment and ESA approval is received by PowerStream, the meter can
be installed.
g) PowerStream metering group installs generator meter.
h) PowerStream requests documentation
for Connection Agreement:
3 of 21
Net Metering Generators
Information Package
Revision 1
a. Single Line Diagram (as built)
b. Contact information
c. Certificate of Insurance
d. Commissioning report
e. Clearing times for inverter trip limits
i) PowerStream sends customer a PowerStream Connection Agreement.
j) Customer to return signed Connection Agreement.
k) Customer will receive a credit toward future energy bills. The credit can be carried forward for
up to 12 months.
See Section 3 for a link to the Form B.
2. Estimated Costs
a. Micro Embedded Generator
The following are the estimated customer connection costs as of the creation date of this document
(These costs are for reference only, actual costs will be provided on the PowerStream service layout):
a) $625.00 (approximate), for new bi-directional meter with installation
b. Small Embedded Generator
The following are the estimated customer connection costs as of the creation date of this document
(These costs are for reference only, actual costs will be provided on the PowerStream service layout):
a) The CIA fee for a small project (>10kW to <=500kW) is $1,500.00 + HST.
b) New Services Connection Fee for a three phase net metering configuration is estimated at $625$8,000. However, this estimate is subject to change following a site visit from the metering
department, which may identify a transformer upgrade or any other additional costs.
3. Reference Links
PowerStream:
a) PowerStream’s Embedded Generation Home Page:
http://www.powerstream.ca/app/pages/connecting-gen.jsp
b) PowerStream’s “How to Participate in the Net Metering Program”:
http://www.powerstream.ca/app/pages/EG_NetMetering.jsp
4 of 21
Net Metering Generators
Information Package
Revision 1
c) Conditions of Service:
http://www.powerstream.ca/app/pages/Conditions-2010.jsp
d) Form C - micro-Generations Connection Application:
http://www.powerstream.ca/ContentMgr/attachments/FormC-v1-5.doc
e) Form B - Connection Impact Assessment Application:
http://www.powerstream.ca/ContentMgr/attachments/FormB-v1-4.doc
4. PowerStream Contact Information
a) General Information:
Embedded Generation:
Email: egconnect@powerstream.ca
Phone: 1-877-963-6900 x 25001
b)
Disconnect/Reconnect Requests
New Connections:
Phone: 1-877-963-6900 x26572
5. Micro Generator Design Requirements:
5.1 Single Phase Single Line Diagram Requirements:
As per sample in Appendix I, the SLD should include the following items:




Show disconnect
Show step-up transformer (if-applicable)
Show meter location
Show where connection to existing service is to be made.
5 of 21
Net Metering Generators
Information Package
Revision 1
5.2 Single Phase Metering Requirements:





All metering and disconnect equipment to be located outside and to be accessible to
PowerStream staff.
Micro-generation disconnect to be within 1 meter of bi-directional meter.
ESA inspection required to energize.
PowerStream to install one bi-directional meter.
Clearly label with lamacoid plates (i.e. riveted engraved plates) illustrating the
following:
a) Bi-directional meter
b) Micro-generation disconnect
*See Appendix C for installation with lamacoid plates.
5.3 Three Phase Single Line Diagram Requirements:
As per sample in Appendix J, the SLD should include the following items:




Show disconnects
Show step-up transformer (if-applicable)
Show meter location in electrical room
Show where connection to existing service is to be made.
5.4 Three Phase Metering Requirements:
Embedded Generation projects can be connected to the following service types:
Service Type
120/208V 3-phase 4-wire WYE
120/208V Network (2-phase 3-wire)
on a 3-phase 4-wire WYE system
347/600 3-phase 4-wire WYE
600V 3-phase 3-wire DELTA
Project
Size
Max Amps
per Phase
<=57kW
160A
Meter Requirements (Use
PowerStream Standards
for details)
7 Jaw Meter Socket Base
<=40kW
160A
5 Jaw Meter Socket Base
<=200A
<=170kW
N/A
160A
N/A
7 Jaw Meter Socket Base
N/A
<=200A
N/A
Disconnect
Size
<=200A
Customer to:



Supply and mount a single line diagram and a plan view next to the main meter.
Install an isolation device immediately adjacent to generation metering cabinet/base on load
side, connected in parallel with distribution panel.
Ensure location of meter socket is building and fire code compliant, to ensure safe
6 of 21
Net Metering Generators
Information Package
Revision 1
accessibility.

Clearly label with lamacoid plates (i.e. riveted engraved plates) the following:
a) Bi-directional meter
b) Net metering generation disconnect
c) Caution – main building service – 2 power supplies


ESA to provide connection authorization to PowerStream prior to energization.
Generation will be metered at three phase 347/600V or 120/208V complete with neutral.
PowerStream to:

Supply and install one new bi-directional meter.
*See Appendix C for installation with lamacoid plates.
5.5 Design Notes:
1. Electrical Hot Splitter Requirements:
PowerStream requires this type of Legacy Design to be upgraded to include a Main
Disconnect prior to the splitter to allow for building isolation.
2. Three Phase Metering:
All three phase metering installations are required to be in electrical rooms. Outside
installations are not acceptable.
6. Small Generator Design Requirements:
6.1 Three Phase Single Line Diagram Requirements:
As per sample in Appendix D, the SLD should include the following items:


Meter and disconnects, located in electrical room
Show where connection to existing service are to be made
6.2 Three Phase Metering Requirements:
Embedded Generation projects can be connected to the following service types:
7 of 21
Net Metering Generators
Information Package
Revision 1
Table 1: PowerStream FIT Meter and Disconnects
Customer to:
a) Supply and mount a single line diagram and a plan view next to main meter.
b) Install dedicated analog Bell lines at meter location (interval Jack RJ45).
c) Install an isolation device immediately adjacent to generation metering cabinet/base on load
side, connected in parallel with distribution panel. (all metering to be inside main electrical
room, see Table 1 above for standards).
d) Ensure location of installed meter socket is building and fire code compliant, to ensure safe
accessibility.
e) Clearly label with lamacoid plates (i.e. riveted engraved plates) the following:
a. Bi-directional meter
b. Net metering generation disconnect
c. Caution – Main building service – 2 power supplies
f) ESA to provide connection authorization to PowerStream prior to energization.
g) Generation will be metered at three phase 347/600V or 120/208V complete with neutral.
*See Appendix D for installation with lamacoid plates.
PowerStream to:
a) Supply and install one new bi-directional meter.
8 of 21
Net Metering Generators
Information Package
Revision 1
Appendix A - 120/240V Meter Socket Standard
9 of 21
Net Metering Generators
Information Package
Revision 1
Appendix B - Meter Socket Installation Design Standard
10 of 21
Net Metering Generators
Information Package
Revision 1
Appendix C – Commercial Meter Socket Standard
11 of 21
Net Metering Generators
Information Package
Revision 1
Appendix D – Sample Installation
Gang meter socket required
See Standard 25-130
Generated power
from inverter
Bi-directional
meter
All equipment to be labeled
with lamacoid plates (engraved
and riveted)
Line side underground
feed from transformer
Disconnect to be installed within 1
meter of meter socket
To breaker panel
in basement
Net Metering Generation – Single Phase
12 of 21
Net Metering Generators
Information Package
Revision 1
Appendix E – Commissioning Verification Form (≤10KW)
This commissioning verification form is required for inverter-based Micro Embedded Generators applying for
connection with PowerStream. This document must be signed by the contractor or project electrician and the
owner of the project.
Facilities Information
OPA MicroFIT Reference Number
(if applicable)
Project Address
Project Nameplate Capacity (kW)
Commissioning Test Contact Information
Name
Title
Mailing address
Telephone
Email
Commissioning Anti-Islanding Test:
a) Turn Off Utility-Side DG Disconnect:
Verification
Yes/No
Initials
Date
Comments
Yes/No
Initials
Date
Comments
Did the inverter indicate a loss of the utility grid?
After a loss of the utility grid, is there voltage on the
output of the inverter?
Did the inverter shut down as required?
b) Turn On Utility-Side DG Disconnect:
Verification
Did the inverter turn back on upon reconnection with
the utility grid?
Did the inverter return to its normal operating state?
Generator Protective Relay Settings
The inverter-based Micro Embedded Generator must confirm that the inverter equipment meets the IEEE 1547
over/under frequency and over/under voltage protection requirements indicated below.
a. Over Frequency/Under Frequency Protection:
Table 1 – Over/Under Frequency Protection Set Points and Clearing Times
13 of 21
Net Metering Generators
Information Package
Revision 1
b. Over voltage/Under voltage Protection:
Table 2 - Over/Under Voltage Protection Setting and Clearing Time
By signing this form, the commissioning test representative acknowledges that all required verifications
specified under this commissioning verification form have been completed and inverter equipment meets the
IEEE 1547 protection requirements outlined in the Generator Protective Relay Settings section of this
document.
_____________________________________________
Signature of Commissioning Test Representative
(Must be the project contractor or project electrician)
__________________________________________
Signature of the owner of the project
____________________________________
Name (Print)
____________________________________
Name (Print)
____________________________________
Title
____________________________________
Date
Return the completed document by mail, email or fax to:
PowerStream Inc.
Stations Design and Construction – Embedded Generation
161 Cityview Boulevard,
Vaughan, Ontario, L4H 0A9
Email: egconnect@powerstream.ca
Fax: 905-532-4447 – Attention: Stations Design and Construction – Embedded Generation
14 of 21
Net Metering Generators
Information Package
Revision 1
Appendix F – Micro-Embedded Generation Facility Connection Agreement
In consideration of PowerStream Inc. (PowerStream) agreeing to allow you to connect your 10 kW name-plate rated capacity or
smaller generation facility to the PowerStream’s distribution system, you hereby agree to the following terms and conditions.
1.0
Eligibility
1.1 You agree that your generation connection shall be subject to all applicable laws and bound by the terms and
conditions of the PowerStream’s Conditions of Service as amended from time-to-time, which have been filed with
the OEB and are available on request.
2.0
Technical Requirements
2.1 You represent and warrant that you have installed or will install prior to the connection of your generation facility to
the PowerStream’s distribution system, an isolation device satisfying Section 84 of the Ontario Electrical Safety
Code, located outside typically near the meter, and agree to allow the PowerStream’s staff access to and operation of
this as required for the maintenance and repair of the distribution system.
2.2 You agree to perform regular scheduled maintenance to your generation facility as outlined by the manufacturer in
order to assure that connection devices, protection systems, and control systems are maintained in good working
order and in compliance with all applicable laws.
2.3 You agree that during a power outage on the PowerStream system your generation facility will shut down, unless
you have installed special transfer and isolating capabilities on your generation facility. You agree to the automatic
disconnection of your generation facility from the PowerStream’s distribution system, as per the generator protective
relay settings set out in this Agreement, in the event of a power outage on the PowerStream distribution system or
any abnormal operation of the PowerStream distribution system.
2.4 You covenant and agree that the design, installation, maintenance, and operation of your generation facility are
conducted in a manner that ensures the safety and security of both the generation facility and the PowerStream’s
distribution system.
2.5 Due to PowerStream’s obligation to maintain the safety and reliability of its distribution system, you acknowledge
and agree that in the event PowerStream determines that your generation facility (i) causes damage to; and/or (ii) is
producing adverse effects affecting other distribution system customers or PowerStream’s assets, you will
disconnect your generation facility immediately from the distribution system upon direction from the PowerStream
and correct the problem at your own expense prior to reconnection.
3.0
Liabilities
3.1 You and PowerStream will indemnify and save each other harmless for all damages and/or adverse effects resulting
from either party’s negligence or willful misconduct in the connection and operation of your generation facility or
the PowerStream distribution system.
3.2 PowerStream and you shall not be liable to each other under any circumstances whatsoever for any loss of profits or
revenues, business interruptions losses, loss of contract or loss of goodwill, or for any indirect, consequential,
incidental or special damages, including but not limited to punitive or exemplary damages, whether any of the said
liability, loss or damages arise in contract, tort or otherwise.
15 of 21
Net Metering Generators
Information Package
Revision 1
4.0
Compensation and Billing
4.1
If you are not embedded retail generator, you agree that, subject to any applicable law:
a)
PowerStream will not pay you for any excess generation that results in a net delivery to the
PowerStream between meter reads; and
b) There will be no carryover of excess generation from one billing period to the next unless you are, at
the relevant time, a net metered generator (as defined in section 6.7.1 of the Distribution System
Code).
4.2 If you are an embedded retail generator selling output from the embedded generation facility to the Ontario Power
Authority under contract, you agree that PowerStream will pay you for generation in accordance with the Retail
Settlement Code.
4.3 If you are an embedded retail generator selling output to the PowerStream, you agree that PowerStream will pay you
for generation in accordance with the Retail Settlement Code.
5.0
Termination
5.1 You understand that you have the right to terminate this agreement at any time, and that by doing so you are
required to disconnect your generation facility and notify PowerStream of such action.
6.0
Assignment
6.1 You may assign your rights and obligations under this Agreement with the consent of PowerStream, which shall
not withhold its consent unreasonably. PowerStream shall have the right to assign its rights and obligations under
this Agreement without your consent.
I understand, accept and agree to comply with and be bound by the above terms and conditions governing the connection of my
generation facility to the PowerStream distribution system.
Customer Signature: _________________________________
Date: ____________________
Print name: _______________________________________________________________________
PowerStream Account Number:
Billing Address: _____________________________________________________________________
I confirm that the following information is true and accurate:
Nameplate rating of Generator: KW Total installed generation:
Project Location:
Connection Type (Parallel):
OPA Reference number:
Type:
Wind Turbine;
Photovoltaic (Solar);
Hydraulic Turbine;
Other _______________________________
Inverter Utilized:
Yes
KW
No
16 of 21
Fuel Cell;
Net Metering Generators
Information Package
Revision 1
Inverter Certification:
C22.2 #107.1
UL 1741
Site Certified by the ESA
For Office use: Feeder: Date Connected:
Generator Protective Relay Settings
Table 1 - Inverter Based Generation
The following relay settings shall be used for inverters built to the CSA standard:
Source: CSA C22.2 No. 107.1-01 Table 16
System Voltage Vn = V
nominal V (Volts)
Frequency
F (Hertz)
Maximum number of cycles to
disconnect
Seconds
Cycle
V < 0.5 Vn
60
0.1
6
0.5 Vn < V < 0.88 Vn
60
2
120
1.10 Vn < V <1.37 Vn
V > 1.37 Vn
Vn
60
60
F < 59.5*
2
0.033
0.1
120
2
6
F > 60.5
Vn
0.1
6
* The UL1741 & IEEE P1547 Standards use F < rated-0.7 i.e. 59.3 Hz. To update if CSA C22.2 No. 107.1-01 is changed
Table 2 - Non - Inverter Generation
Requirements for Non-Inverter based generation are as follows:
System Voltage Vn =V
nominal V (Volts)
Frequency
F (Hertz)
Maximum clearing time*
Seconds
Cycles
V < 0.5 Vn
60
0.16
9.6
0.5 Vn ≤ V < 0.88 Vn
60
2
120
1.10 Vn ≤ V <1.20 Vn
60
1
60
V ≥ 1.20 Vn
60
0.16
9.6
Vn
F < 59.3
0.16
9.6
Vn
F > 60.5
0.16
9.6
*Clearing time is the time between the start of the abnormal condition and the generation ceasing to energize the PowerStream’s
distribution system
-
If you are uncertain about your generation equipment’s protective relay settings, please check with your generating
equipment supplier.
- Automatic reconnect setting time for your generator is after 5 minutes of normal voltage and
frequency on the PowerStream’s distribution system.
17 of 21
Appendix 4(i) - Remote Monitoring and Control Requirements
EG Information Package (RM & RS)
Rev 1.4 – April 2014
Embedded Generation
Information Package for Projects with
“Single Inverter Configuration”
Remote Monitoring (RM)
Remote Shutdown (RS)
Prepared by: Station Design – Embedded Generation
Revision: 1.4
April 2014
Page 1 of 6
EG Information Package (RM & RS)
Rev 1.4 – April 2014
1. Background:
Embedded Generators on the distribution grid pose potential operating and safety concerns for those
working to control and maintain the network. In response, PowerStream requires generators to
maintain a Remote Monitoring System with capability to support a Generator Remote Shutdown
directive.
2. References:
•
•
•
•
Connection Impact Assessment (CIA)
IEEE-1547 Standard for Interconnecting Distributed Resources with Electric Power Systems
RTAC SEL-3530-4 Real-Time Automation Controller Installation Guideline
RuggedMAX™ WiN5200 Installation Guideline.
3. Purpose:
This procedure is intended to act as a guideline for Generators needing to purchase, install, and
commission a Remote Monitoring and Remote Shutdown System when required by the Generator’s
Connection Impact Assessment (CIA).
4. Introduction:
Remote Monitoring provides the PowerStream Remote Monitoring (RM) Control Room with real-time
data from the Embedded Generator. This information increases PowerStream’s ability to manage the
efficiency and safety of power on the distribution grid.
The Remote Monitoring system is comprised of an Automated Control unit which polls the Generator for
information, and an Antenna which wirelessly transmits the information back to PowerStream’s control
room via the communication link. The following schematic illustrates the relationship between the
Generator and the Communication Link.
PowerStream’s Remote Monitoring system is designed in compliance with IEEE Std. 1547.
Page 2 of 6
EG Information Package (RM & RS)
Rev 1.4 – April 2014
All Generator Remote Monitoring equipment is located on the Embedded Generator’s premises.
Generators are expected to have functioning Remote Monitoring systems prior to Generation
Connection to the grid. In the event of a monitoring system breakdown, it is expected that the
Generator will have the link repaired within 3 days of the failure.
5. Connection Procedure:
1.
2.
3.
4.
5.
6.
7.
8.
Customer reviews Remote Monitoring requirements outlined in this document.
Customer purchases and installs equipment to PowerStream’s specification.
Customer returns completed RM Control Form to PowerStream
PowerStream Embedded Generation team receives the completed RM Control Form and
reviews it for technical completion.
The Embedded Generation Team provides the customer with the corresponding IP
addresses and forwards the approved and completed RM Control Form to the customer and
Engineering for processing.
PowerStream Engineering processes the RM Control Form, applies for the necessary
licensing with Industry Canada, and issues a connection order for the WiMax Network.
Customer configures equipment to PowerStream’s specification.
PowerStream commissions the WiMax Communication Link.
6. Specifications:
6.1.
Equipment
Item
6.1.1.
Equipment
Manufacturer
Part Number
1
Real Time Automation Controller (RTAC)
Schweitzer Engineering
Laboratories
SEL 3530-4
2
WiMax Subscriber Unit (CPE)
RuggedCOM
Win5218
Real Time Automation Controller (RTAC)
•
•
The SEL RTAC communicates with most devices using built-in client/server
protocols. It converts data between protocols, performs math/logic functions,
and executes output logic for real-time control.
Dimensions are approximately 222mm x 216mm x 43mm (LxWxH).
Page 3 of 6
EG Information Package (RM & RS)
Rev 1.4 – April 2014
Front
6.1.2.
Back
WiMax Subscriber Unit (CPE)
•
•
The WiN5218 is a high-performance outdoor radio antenna that provides
broadband wireless access. The self-learning subscriber unit automatically
detects the PowerStream link station using the best signal available allowing
for plug and play installation and low maintenance operation.
Dimensions are approximately 60mm x 305mm x 305mm (LxWxH).
Front
6.1.3.
Back
Uninterruptible Power Source (UPS)
•
•
It is recommended that the SEL RTAC and WiMax Subscriber Unit are powered
by an Uninterruptible Power Source to maintain data transmission during an
outage.
At this time, PowerStream does not specify a particular UPS make or model.
Page 4 of 6
EG Information Package (RM & RS)
Rev 1.4 – April 2014
6.2.
Installation
6.2.1.
Real Time Automation Controller (RTAC)
•
•
•
•
6.2.2.
WiMax Subscriber Unit (CPE)
•
•
•
•
•
•
6.3.
The SEL RTAC can be ordered as rack
mount or surface mount.
The unit is installed indoors in a dry
location, relatively close to the
Generator’s control equipment.
Network connections to the Generator
equipment use Cat-5 Ethernet cable
or serial cable.
Installation should conform to the
RTAC SEL-3530-4 Installation
Guideline.
The Subscriber Unit is mounted
outdoors at a height of 8m or higher
and must be securely mounted to a
rigid structure or pole.
The mounting height must provide line
of site between the antenna and
PowerStream’s Base Station.
An LED Indicator is provided on the
Subscriber to aid in aligning with
PowerStream’s Base Station.
The unit is Powered Over Ethernet
(POE).
Outdoor rated Cat-5 Ethernet cable is
required.
Installation must conform to
RuggedMAX™ WiN5200 Installation
Guidelines.
Communication
6.3.1.
Remote Monitoring
•
Generator Remote monitoring data is to be provided to the RTAC via a DNP3 or
Modbus over Ethernet protocol, via Ethernet data port. If Ethernet is not
available, a serial data port using Modbus or DNP3 data protocol is acceptable.
Page 5 of 6
EG Information Package (RM & RS)
Rev 1.4 – April 2014
6.3.2.
Remote Shutdown
•
6.3.3.
Radio License
•
•
6.3.4.
A remote shutdown command will be sent to the Generator Breaker’s
controller from the RTAC by means of a ‘Trip’ or ‘Shutdown’ Command.
PowerStream’s WiMax Radio Network operates in the 1.8GHz licensed
microwave band.
PowerStream will secure and manage the appropriate licensing for each
generator.
Wireless Connection
•
The Subscriber Antenna is pointed in the direction of the appropriate Link
Station. Link Station coordinates are provided below:
WiMax Base Station
Node:
Alliston
Aurora
Barrie
Markham
Vaughan
Station Co-ordinates (NAD 83)
Latitude
Longitude
44 09 02 N
079 51 44 W
43 57 56 N
079 29 12 W
44 24 29 N
079 41 40 W
43 50 55 N
079 18 39 W
43 48 37 N
079 28 41 W
7. Responsibilities:
7.1.
Embedded Generator
•
•
•
•
•
•
•
•
7.2.
Purchase specified equipment from PowerStream approved vendors.
Install specified equipment.
Have SEL RTAC configured as per PowerStream direction.
Have WiMax CPE Configured as per PowerStream direction.
Aim WiMax antenna toward specified link station.
Return completed RM Control Form to PowerStream with network drawings and
technical contact information.
Support Remote Monitoring Link Commissioning
On-going Maintenance of remote monitoring system.
PowerStream
•
•
•
•
Provide remote monitoring specifications.
Secure appropriate 1.8GHz licensing with Industry Canada.
Provide network IP and DNP addresses.
Commission Remote Monitoring Link.
Page 6 of 6
EG Information Package (RM & RS)
Rev 1.4 – April 2014
8. Installation Contractors:
For your reference and convenience, PowerStream has worked with the following contractors who can
assist you with the Remote Monitoring System purchase and installation.
RBI – Robertson Bright Inc.
Dave Graham
Vice President – Operations
Phone: (905) 813-3005 Ext. 205
Cell: (416) 677 9107
Email: daveg@rbigroup.net
RuggedCOM Inc.
Adam McGregor
Regional Manager, Central Canada
Cell: 416-258-3535
Email: adammcgregor@ruggedcom.com
SEL – Schweitzer Engineering Laboratories
David Bowen
Integration Application Specialist
(705) 722–8484
Phone: (705) 722-8484
Email: david_bowen@selinc.com
Page 7 of 6