Conditions Of
Service
SECTION
1 INTRODUCTION
1.1
Identification of Distributor and Territory
The Distributor is a corporation, incorporated under the laws of
the Province of Ontario to distribute electricity.
The Distributor is licensed by the Ontario Energy Board “OEB” to
supply electricity to Customers as described in the Distribution Licence issued
to the Distributor by the OEB. Additionally, there are requirements imposed on
the Distributor by the various codes referred to in the Licence and by the
Electricity Act, the Ontario Energy Board Act and other provincial legislation.
The Distributor is limited to operate distribution facilities
within their Licensed Territory as defined in the Distribution Licence.
1.1.1
General
Nothing contained in this document or in any contract for the
supply of electricity by the Distributor shall prejudice or affect any rights,
privileges, or powers vested in the Distributor by law under any Act of the
Legislature of Ontario or the Parliament of Canada, or any regulations
thereunder.
All operations performed by the Distributor and its agents shall
be performed within the rules and regulations set out by the appropriate
authorities including but not limited to: Electrical Safety Authority (ESA),
Ministry of Labour, Ministry of Transportation, etc.
The Distributor will normally provide one electrical service to each Customer
location at a nominal service voltage.
Modifications to an existing service must comply with the
requirements of the standards in effect at the time of the modifications.
The Customer or their authorized representative must make application for new
or upgraded electric services, temporary power services and generation
connections.
The Customer or their representative shall consult with the
Distributor concerning the availability of supply, the voltage of supply,
service location, metering and any other details. These requirements are
separate from and in addition to those of the Electrical Safety Authority. The
Distributor will confirm, in writing, the Characteristics of Electric Supply
available at a specific site.
The Customer is required to provide the Distributor sufficient
lead-time in order to ensure:
·
the timely provision of supply to new and upgraded premises or
·
the availability of adequate capacity for additional loads to be
connected in existing
premises or
·
the availability of adequate capacity for generation to be
connected to the specific location.
If special equipment is required or equipment delivery problems
occur, then longer lead times may be necessary. The Customer will be notified
of any extended lead times.
Customers will be required to pay the cost of repair or
replacement of the Distributors’ plant that has been damaged through the
Customers’ action or neglect.
The supply of electricity or a service connection is conditional
upon the Distributor being permitted and able to provide such a supply,
obtaining the necessary apparatus and material, and constructing works to
provide the service. Should the Distributor not be permitted to supply or not
be able to do so, it is under no responsibility to the Customer whatsoever.
The Customer shall not build, plant or maintain or cause to be
built, planted or maintained any structure, tree, shrub or landscaping that
would or could obstruct the running of distribution lines, endanger the
equipment of the Distributor, interfere with the proper and safe operation of
the Distributor’s facilities or adversely affect compliance with any applicable
legislation in the sole opinion of the Distributor.
Prior to commencing any service work, the Customer must consult
with the Distributor to ensure compliance with current requirements.
The Customer is responsible for selecting a qualified/competent
contractor. Careful selection of a contractor can significantly affect the cost
of a project. The Distributor shall be consulted prior to the selection of a
mutually acceptable contractor.
The Customer maintains the responsibility to ensure that all
work is done in accordance with the Distributor’s design and technical
standards and specifications.
The Distributor, at the expense of the Customer, reserves the
right to inspect the work throughout the duration of the project, and the
Contractor shall supply the Inspector such accommodations as the Inspector may
require. The Inspector shall request that the Contractor stop work at any time
the Inspector deems the Contractor is not proceeding in accordance with these
“Conditions of Service”. The Customer shall confer with the Distributor before
work recommences to mitigate undue cost and construction delays for the
project.
Customers may be required to pay Capital Contributions for the
addition of new and upgraded electrical services. In some instances, an
Economic Evaluation as defined in the Distribution System Code (DSC) may be
required. Customers installing distributed generation may be required to pay
for additions of new or upgraded Distributor electrical plant associated with
the connection of the generation and the associated engineering studies.
1.2
Related Codes and Governing Laws
The Distributor is limited in its scope of operation by the:
·
Electricity Act, 1998
·
Ontario Energy Board Act, 1998
·
Occupational Health and Safety Act
·
Energy Consumer Protection Act, 2010
·
Distribution Licence – Licence Numbers
·
Affiliate Relationships Code
·
Distribution System Code
·
Retail Settlement Code
·
Standard Service Supply Code
·
Conservation and Demand Management Code
·
Transmission System Code
·
Ontario Regulation 22/04 – Electrical Safety Authority (ESA)
·
Measurement Canada
·
Electricity and Gas Inspection Act, 1985
·
Municipal Freedom of Information and Protection of Privacy Act,
R.S.O. 1990
·
Accessibility for Ontarians with Disabilities Act. 2005
In the event of a conflict between this document and the Distribution
Licence or regulatory Codes issued by the OEB, or the Electricity Act, the
provisions of the Act, the Distribution Licence and associated regulatory Codes
shall prevail.
When planning and designing for electricity service, Customers
and their agents must refer to all applicable Provincial and Canadian
electrical codes, and all other applicable federal, provincial, and municipal
laws, regulations, codes and by-laws to also ensure compliance with their
requirements. The work shall be conducted in accordance with the Ontario
Occupational Health and Safety Act, the Regulations for Construction Projects
and the Electrical Utility Safety Rules (IHSA formally EUS&A) (or the OHSC
Safety) rulebook.
1.3
Interpretations
In these Conditions, unless the context otherwise requires:
·
Headings and underlining are for convenience only and do not
affect the interpretation of these Rules.
·
Words referring to the singular include the plural and vice
versa.
·
Words referring to a gender include any gender.
1.4 Amendments
and Changes
The provisions of these Conditions of Service and any amendments
made from time to time form part of any Contract made between the Distributor
and any connected Customer, Generator or their agents.
n the event of changes to this Conditions of Service a notice
shall be provided to Customers as required in the Distribution System Code and
copies made available at the Distributor’s office or on the Distributors’
Website.
The Customer is responsible for contacting the Distributor to
ensure that the Customer has, or to obtain the current version of the
Conditions of Service. The Distributor may charge a reasonable fee to recover
costs for providing the Customer with more than one copy of this document.
1.5
Contact Information
The Distributor and its agents can be contacted during normal
working hours. Please refer to the Contact Listing in the Appendices for phone
number of the Distributor servicing your area.
1.6
Customer Rights
In those instances where the Customer will own their secondary
or primary service, the Customer has the right to hire a Contractor to supply
and install the service.
The Customer has the right to demand identification from any
person purporting to be an authorized agent or employee of the Distributor.
A Customer, who believes that they have suffered damages to
their property or equipment as a result of negligence on the part of the
Distributor, may submit a written claim for damages to the Distributor. The
Distributor will investigate the claim and respond in writing within 10
business days of the receipt of the claim.
1.7
Distributor Rights
In those instances where the Customer has the authority to hire
a Contractor to construct plant which will become part of the Distributors’
system, the Distributor shall have the right to require the Contractor to
submit proof of previous experience and satisfactory performance, and, the
Distributor shall have the right to investigate such proof and approve the
Contractor prior to the Owner awarding a contract for the work to the Contractor.
The Distributor shall
have access to Customer property in accordance with section 40 of the
Electricity
Act, 1998.
1.8
Disputes
If, following good faith negotiations between a Customer or
other market participant and the Distributor, a resolution cannot be reached,
the dispute may be submitted to a dispute resolution process.
Any dispute which shall arise between the Distributor and a
Customer(s) and other market participants subject to the terms of these
Conditions of Service concerning the rights, duties or obligations of the
Distributor or others subject to these Conditions of Service, shall be subject
to the following dispute resolution procedure:
Mediation
·
Either party (the “Initiating Party”) may invoke the dispute
resolution procedure by sending a written notice to the other party (the
“Respondent Party”) describing the nature of the dispute and designating a
representative of the Initiating Party with appropriate authority to be its
representative in negotiations relating to the dispute. The responding Party
shall, within five business days of the receipt of such notice, send a written
notice to the Initiating Party, designating a representative of the Responding
party with the appropriate authority to be its representative in negotiations
relating to the dispute.
·
Within ten business days of the receipt by the Initiating Party
of the written notice of the Responding Party the designated representatives
shall enter into good faith negotiations with a view to resolving the dispute.
If the dispute is not resolved in thirty days of the commencement of such
negotiations, or such longer period as may be agreed upon, either party may, by
written notice to the other party, require that the parties be assisted in
their negotiations by the Ontario Energy Board. In accordance with the OEB
dispute resolution process, The Ontario Energy Board will complete its review
of the dispute within 150 days.
1.9
Service Quality Requirements
The level of service provided by the Distributor is defined in
specific terms within Section 7 of the DSC, or as the DSC may be amended from
time to time. The Distributor recognizes the requirements and will strive to
meet or exceed these requirements and the associated reporting to the OEB. The
reporting of these requirements forms public record available to the
Distributor’s Customers.
1.10
Liability
A Distributor shall only be liable to a Customer and a Customer
shall only be liable to a Distributor for any damages which arise directly out
of the willful misconduct or negligence:
·
Of the Distributor in providing distribution services to the
Customer;
·
Of the Customer in being connected to the Distributor’s
distribution system; or
·
Of the Distributor or Customer in meeting their respective
obligations under the Distribution
System Code, their licences and any other applicable law.
Despite the above; neither the Distributor nor the Customer
shall be liable under any circumstances whatsoever for any loss of profits or
revenues, business interruption 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.
1.11
Force Majeure
Neither party shall be held to have committed an event of
default in respect of any obligation under the Distribution System Code if
prevented from performing that obligation, in whole or in part, because of a
force majeure event.
Notwithstanding any of the foregoing, settlement of any strike,
lockout, or labor dispute constituting a force majeure event shall be within
the sole discretion of the party to the agreement involved in the strike,
lockout, or labour dispute. The requirement that a party must use its best
efforts to remedy the cause of the force majeure event, mitigate its effects,
and resume full performance under the Distribution System Code shall not apply
to strikes, lockouts, or labour disputes.
SECTION
2 DISTRIBUTION ACTIVITIES (GENERAL)
2.1
Connections
This section includes information that is applicable to all
Customer classes of the Distributor. Items that are applicable to only a
specific Customer class are covered in Section 3.
2.1.1
Obligations to Connect
As provided in Section 28 of the Electricity Act 1998 the
Distributor has the Obligation to Connect any Building that ‘lies along” its
distribution system subject to conditions outlined in section 2.1.3.
A building ‘lies along” a distribution line if it can be connected to the
Distributor distribution system without an expansion or enhancement.
A Building that appears to ‘lie along’ a distribution line may
be refused connection to that line should the distribution line not have
sufficient capacity for the requested connection. In such instances, the
Distributor shall make an offer to connect which will include the cost of the
enhancement.
As provided in Section 25.36 of the Electricity Act 1998 the
Distributor shall connect a renewable energy generation facility to its
distribution system in accordance to regulations, the market rules and any
licence issued by the Board if requested and all regulations, market rules,
orders or code have been met in respect to the connection.
Connection fees as noted within the Conditions of Service shall
apply. (See sections 3.1.3, 3.1.4, 3.2.3, 3.2.4, 3.3.3, 3.3.4 3.4.3, 3.4.4,
3.5.1 & 3.8.1)
2.1.2
Offer to Connect
The Distributor will make an Offer to Connect to any Customer
requesting a connection within the Distributors licensed territory. As required
by the Distribution System Code, the Offer to Connect must be fair and
reasonable and be based on the Distributors’ design standard. The Offer to
Connect must also be made within a reasonable time from the request for
connection and the receipt of all required information from the Customer.
The Distributor may require a Customer to pay all or a part of
the costs of electrical plant installed to supply only that Customer. Such
capital contributions will be calculated using the guidelines set out by the
OEB in the Distribution System Code. If an expansion or enhancement of the
distribution system is required to facilitate a connection, the Distributor may
need to perform an Economic Evaluation to establish the capital contribution
required from the Customer. The Customer should review the attached
Distribution Connection Process for further information.
The Distributor may require a Customer proposing to install
generation to pay the costs of electrical plant installed to facilitate the
connection of the generation. Such capital contributions will be calculated
using the guidelines set by the OEB in the Distribution System Code.
Reference: A Customer considering a generation project can find
additional information on the technical and administrative requirements in the
CHEC Generation Guide and Appendix E and Appendix F of the Distribution System
Code. A copy of these documents can be obtained from your local utility upon
request.
2.1.3
Connection Denial
The Distribution System Code in section 3.1 sets outs the conditions
for a Distributor to deny connections. A Distributor is not obligated to
connect a Customer within its service territory if the connection would result
in any of the following:
·
Contravention of existing Canadian Laws, and those of the Province
of Ontario including the Ontario Electrical Safety Code.
·
Violations of conditions in a Distributors’ Licence, the
Distributor’s Conditions of Service, or the Customer’s Connection Agreement.
·
Use of a distribution system line for a purpose that it does not
serve and that the Distributor does not intend to serve.
·
Adverse effect on the reliability and safety of the distribution
system.
·
Imposition of an unsafe work situation beyond normal risks
inherent in the operation of the
distribution system.
·
A material decrease in the efficiency of the Distributors’
distribution system.
·
A material adverse effect on the quality of distribution
services received by an existing
connection.
·
Discriminatory access to distribution services.
·
Potential increases in monetary amounts that already are in
arrears with the Distributor
·
Where the electrical connection to the distribution system does
not meet the Distributor’s
design requirements
·
Where the electrical connection violates the property rights of
property owners or other
agencies, such as railways, Ministries, or the Municipality
In addition to the above, the Distributor may deny connection to
any Customer for any of the following reasons:
·
Refusal by the Customer to sign any agreements required to be
executed by the Customer under these Conditions of Service;’
·
Failure to meet the Distributor’s security deposit policy
requirements as outlined in the Conditions of Service
The Distributor shall inform the person requesting the
connection of the reason(s) for not connecting and, where the Distributor is
able to provide a remedy, make an offer to connect. If the Distributor is
unable to provide a remedy to resolve the issue, it is the responsibility of
the Customer to do so before a connection may be made.
2.1.4
Inspections before Connections
The Distributor has the right to request an inspection prior to
any connection to ensure the connection meets the Distributor’s design
standards and requirements.
All Customer electrical installations shall be inspected and
approved by the Electrical Safety Authority, referred to herein as the ESA.
The Distributor requires notification from the ESA of this
approval prior to the connection of a Customer’s service.
Services that have been disconnected for a period of six months
or longer shall also be inspected and approved by the ESA prior to
reconnection.
Temporary services, for construction purposes, are approved by
the ESA for a period of twelve months and must be re-inspected should the
period of use exceed twelve months.
The Distributor reserves the right to inspect and approve
Transformer rooms, Vaults and Pads prior to, during, and following the
installation of equipment.
Provision for metering shall be inspected and approved by the
Distributor prior to connection.
Customer owned substations must be inspected by both the
Electrical Safety Authority and the Distributor, prior to connection to the
Distribution system.
Duct banks and road crossings shall be inspected and approved by
the Distributor prior to the pouring of concrete and again before backfilling.
The Distributor reserves the right to inspect any underground
trenches prior to backfilling.
The Distributor reserves the right to approve the installation and location of
all submarine cable. All documentation and permits required for laying of
submarine cable must be provided to the Distributor. The installation of
submarine cable must meet the requirements of all governing legislation.
All work done on existing Distributor plant must be authorized
by the Distributor and carried out in accordance with all applicable safety
acts and regulations.
In accordance with the Distribution System Code, if the
Distributor refuses to connect a building in its service territory that lies
along one of its distribution lines, the Distributor shall inform the person
requesting the connection of the reasons for not connecting, and where the
Distributor is able to provide a remedy, make an offer to connect. If the
Distributor is unable to provide a remedy to resolve the issue, it is the responsibility
of the Customer to do so before a connection can be made.
2.1.5
Relocation of Plant
The Distributor will, where feasible, accommodate requests to
relocate electrical plant such as poles and metal enclosed equipment.
The Customer will be required to pay all of the costs incurred
by the relocation.
Requests by civic
authorities to relocate distribution facilities will be done so in accordance
with the
appropriate regulations. See Public Service Works on
Highways Act.
2.1.5
2.1.6 Easements
To maintain the reliability, integrity and efficiency of the
distribution system, the Distributor has the right to have supply facilities on
private property registered against title to the property. Easements may be
required when the Distributors’ underground or overhead plant is to be located
on private property or crosses over an adjacent private property to service a
Customer.
The Customer shall acquire and grant in the Distributors name,
at no cost to the Distributor, where required, an easement to permit installation
and maintenance of service. The width and extent of this easement shall be
determined by the Distributor. The easement shall be granted prior to
connection of the service.
The Owner shall furnish to the Distributor, free and clear of
all encumbrances, sufficient easements to enable the servicing of all existing
or proposed developments or subdivisions from plants located on the Owners’
property.
Sufficient property at suitable locations shall be made
available for the purpose of the installation of Distributors’ assets.
The Customer will prepare at its own costs a reference plan and associated
easement documents to the satisfaction of the Distributors’ solicitor prior to
its registration and register the easement plan. Details will be provided upon
application for service.
Where surface restoration by the Distributor is required
following any repairs or maintenance to a service, the Distributor will in so
far as is practicable, restore the property to its original condition; and
provide compensation for any damages caused by the entry that cannot be
repaired.
2.1.7
Contracts
Standard Form of Contract –
All Customers will be requested to complete and sign the standard form of
contract to apply for a connection. A Standard Contract for service shall be considered
as being in force from the date it is signed by the Customer and the
Distributor and shall remain in force until terminated by either party.
Special Contracts –
Special contracts that are customized in accordance with the service requested
by the Customer normally include, but are not necessarily limited to, the
following examples:
·
construction sites
·
mobile facilities
·
non-permanent structures
·
special occasions, etc.
·
Generation
In all cases of special contracts, the terms and conditions of
all regulations, conditions and charges as established by the Distributor shall
apply to the Customer connection unless specifically noted in the special
contract.
2.2
Disconnection
The Distributor shall not be liable for any damages or claims as
a result of disconnection of service.
2.2.1
Refusal to Connect/Right to Disconnection
The Distributor has the right to refuse and/or obligation to
disconnect the supply of electrical energy or service to a Customer for causes
including but not limited to:
(a) contravention of the laws of Canada or the Province of
Ontario including the Ontario Electrical Safety Code;
(b) violation of conditions in a Distributor’s licence;
(c) materially adverse effect on the reliability or safety of the distribution
system;
(d) imposition of an unsafe worker situation beyond normal risks inherent in
the operation of the distribution system;
(e) a material decrease in the efficiency of the Distributor’s distribution
system;
(f) inability of the Distributor to perform planned inspections and
maintenance;
(g) a materially adverse effect on the quality of distribution services
received by an existing connection; and
(h) if the person requesting the connection owes the Distributor money for
distribution services, or for non-payment of a security deposit.
(i) compliance with a court order
(j) by order of the Electrical Safety Authority or IESO
2.2.2
Unauthorized Energy Use
The Distributor shall use its discretion in taking action to
mitigate unauthorized energy use. Upon identification of possible unauthorized
energy use, the Distributor shall notify, if appropriate, Measurement Canada,
The Electrical Safety Authority, Police Officials, Retailers that service
Customers affected by an authorized energy use, or other entities.
The Distributor may recover from the parties responsible for the
unauthorized energy use all costs incurred by the Distributor arising from
unauthorized energy use, including an estimate of the energy used, inspection
and repair costs.
A service disconnected due to unauthorized use of energy shall
not be reconnected until such time as all arrears resulting from the
unauthorized use has been resolved to the satisfaction of the Distributor.
Prior to reconnection, the Distributor shall require proper
authorization from applicable authorities.
2.3
Conveyance of Electricity
2.3.1
Guaranty of Supply
The Distributor agrees to use reasonable diligence in providing
a regular and uninterrupted supply but does not guarantee a constant supply or
the maintenance of unvaried frequency or voltage and will not be liable in
damages to the Customer by reason of any failure in respect thereof.
Customers requiring a high degree of security of supply or power
quality are responsible to provide their own back-up or standby facilities.
Customers requiring power for human life support equipment must
provide their own equipment to ensure an uninterrupted supply of power.
Customers on life support equipment are encouraged to contact the Distributor
to inform them of their medical needs and the backup equipment which is in
place.
When power is interrupted, or the Customer is experiencing power
quality problems the Customer, or their electrical contractor shall first
ensure that interruption is not due to problems within the Customer owned
installation. If after verifying that the cause of the problem does not reside
on the Customers’ installation, the Customer shall contact the Distributor. The
Distributor will respond to and take reasonable steps to restore power. The
Distributor reserves the right to claim and take any actions or legal
proceedings for recovery or compensation as a result of costs due to
inconvenience, disruption of schedule, and/or loss of efficiency or
productivity of any nature whatsoever related to misidentification of power
quality issues or outages by the customer or its contractor and/or
subcontractors, suppliers, and/or or materialmen of any tier.
Although it is the Distributors’ policy to minimize
inconvenience to Customers, it is necessary to occasionally interrupt a
Customers’ supply to maintain or improve the Distributors’ system, or to
provide new or upgraded services to other Customers. Whenever practical and
cost effective, as determined by the Distributor, arrangements suitable to the
Customer and the Distributor may be made to minimize any inconvenience. The
Distributor will endeavor to provide the Customer with reasonable advance
notice, except in cases of emergency, involving danger to life and limb, or
impending severe equipment damage.
The Distributor will endeavor to notify Customers prior to
interrupting the supply to any individual service. However, if an unsafe or
hazardous condition is found to exist, or if the use of electricity by
apparatus, appliances, or other equipment is found to be unsafe or damaging to
the Distributor or the public, service may be discontinued without notice.
Depending on the outage duration and the number of Customers
affected, the Distributor may notify affected customers of the outage. The
method of notification is at the discretion of the Distributor (i.e.: App,
Social Media, etc.).
2.3.2
Power Quality
The Distributor will respond to and take reasonable steps to
investigate consumer power quality complaints and report to the consumer on the
results of the investigation. The method and level of investigation will be at
the discretion of the Distributor.
If the source of a power quality problem is caused by the
consumer making the complaint, the Distributor may seek reimbursement for the
time and cost spent to investigate the complaint.
If the source of a power quality problem is caused by a
consumer, the Distributor may direct the consumer to take corrective action. If
the Consumer does not take such action within a reasonable time, the
Distributor may disconnect the supply of power to the Customer (see Section
2.2).
2.3.3
Electrical Disturbances
There are levels of voltage fluctuation and other disturbances
that can cause flickering lights and more serious difficulties for Customers
connected to the Distributor distribution system.
Some types of electronic equipment, such as video display
terminals, can be affected by the close proximity of high electrical currents
that may be present in transformer rooms.
No electrical equipment, which may produce an undesirable system
disturbance, shall be connected by a Customer to a Customer’s service without
prior approval of the Distributor.
Examples of equipment, which may cause disturbance, are large
motors, welders, generators and variable speed drives. In planning the
installation of such equipment, the Customer is required to consult with the
Distributor.
The following limits apply to users connected to systems where
the rated voltage at the PCC (Point of Common Coupling) is 120 V to 69 kV.
Maximum harmonic current distortion in percent of IL
Individual
harmonic order (odd harmonics)
|
ISC/IL |
3 ≤ h <11 |
11≤ h < 17 |
17 ≤ h < 23 |
23 ≤ h < 35 |
35 ≤ h ≤ 50 |
TDD |
|
< 20c |
4.0 |
2.0 |
1.5 |
0.6 |
0.3 |
5.0 |
|
20 < 50 |
7.0 |
3.5 |
2.5 |
1.0 |
0.5 |
8.0 |
|
50 < 100 |
10.0 |
4.5 |
4.0 |
1.5 |
0.7 |
12.0 |
|
100 < 1000 |
12.0 |
5.5 |
5.0 |
2.0 |
1.0 |
15.0 |
|
> 1000 |
15.0 |
7.0 |
6.0 |
2.5 |
1.4 |
20.0 |
Even
harmonics are limited to 25% of the odd harmonic limits above.
Current
distortions that result in a dc offset, e.g. half-wave converters, are not
allowed.
All
power generation equipment is limited to these values of current distortion,
regardless of actual Isc/IL.
Where:
Isc = maximum short-circuit current at PCC.
IL = maximum demand load current (fundamental frequency component) at PCC.
TDD = Total demand distortion (RSS), harmonic current distortion in % of
maximum demand load current (15 or 30 min demand). PCC = Point of common
coupling.
Taken
from IEEE Standard 519-2014 (Revision of IEEE Standard 519-1992).
Please note: In the event of a discrepancy, the latest version of IEEE Standard
Recommended Practice and Requirements for Harmonic Control in Electric Power
Systems will be taken as correct.
The Distributor will endeavour to maintain voltage variation
limits, under normal operating conditions, at the Customers’ Delivery Points,
as specified by the latest edition of the Canadian Standards Association, C235.
However, more sensitive electronic equipment such as computers can be seriously
affected by variations in quality of supply voltage. Customers who need
electrical power of high quality and with rigid voltage tolerances are
responsible for providing their own power conditioning equipment.
Customers requiring a three-phase supply should install
protective apparatus to avoid damage to their equipment, which may be caused by
the interruption of one phase, or non-simultaneous switching of phases of the
Distributors’ supply.
The Customer shall provide such protective devices as may be
necessary to protect his property or equipment from any disturbance beyond the
control of the Distributor.
The Distributor shall not be held liable for the failure to
maintain supply voltages within standard levels due to Force Majeure.
The Customer installing generation will install a Distributor
approved system configuration and voltage level. In general, where the
connection of generation will be to the service supply the generation will be
required to be the same voltage and number of phases.
2.3.4
Standard Voltage Offerings
2.3.4.1
For Secondary Voltage
The Supply Voltage governs the limit of supply capacity for any
Customer. General guidelines for supply from overhead street circuits are as
follows:
·
at 120/240 Volts single phase, or
·
at 120/208 Volts three phase, four wire, or
·
at 347/600 Volts three phase, four wire,
OR
Where street circuits are buried, the Supply Voltage and limits
will be determined upon application to the Distributor.
OR
Where the Customer or Developer provides a pad on private
property;
·
at 120/240 Volts single phase, or
·
at 120/208 Volts three phase, four wire, or
·
at 347/600 Volts three-phase, four-wire
2.3.4.2
For Primary Voltage
Primary supplies to transformers or Customer-owned substations
will be one of the following as determined by the Distributor:
·
2,400/4,160 Volts 3 phase 4 wire
·
4,800/8,320 Volts 3 phase 4 wire
·
7,200/12,400 Volts 3 phase 4 wire
·
8,000/13,800 Volts 3 phase 4 wire
·
16,000/27,600 Volts 3 phase 4 wire
·
44,000 Volts 3 phase 3 wire
The Customer shall contact the Distributor when planning their
service to verify standard transformer availability and supply capacity.
2.3.5
Voltage Guidelines
The Distributor maintains service voltage at the Customers’
service entrance within the guidelines of C.S.A. Standard CAN3-C235 (latest
edition – see table below) which specifies maximum variations from “normal
operating conditions” and for “extreme operating conditions”.
[chart]
Where voltages lie outside the indicated limits for Normal
Operating Conditions but within the indicated limits for Extreme Operating
Conditions, improvement or corrective action will be taken on a planned and
programmed basis, but not necessarily on an emergency basis.
Where voltages lie outside the indicated limits for Extreme
Operating Conditions, improvement or corrective action will be taken on an
emergency basis. The urgency for such action will depend on many factors such as
the location and nature of load or circuit involved, the extent to which limits
are exceeded with respect to voltage levels and duration, etc.
Where concern exists with the service voltage level Customers
are encouraged to contact the Distributor to confirm the allowed variations and
to determine whether corrective action is required.
2.3.6
Back-up Generators
Customers with portable or permanently connected emergency
generation capability shall comply with all applicable criteria of the Ontario
Electrical Safety Code and in particular, shall ensure that Customer emergency
generation does not back-feed on the Distributors’ system.
To access the Ontario Electrical Code which specifies the
requirements for the connection of generators and to further review the Standby
Generator Safety Checklist review Generator Safety Info.
Customers with permanently connected emergency generation
equipment shall notify the Distributor regarding the presence of such
equipment.
The Distributor reserves the right to have the connection of
this equipment inspected.
Generation systems found to be feeding into the Distribution system without
proper approval of the Distributor shall be subject to immediate disconnection.
2.3.7
Metering
2.3.7.1
General
2.3.7.1.1 Access
The Distributor or its agents shall have the right to access,
read and safely maintain any of the Distributors’ electricity meters on the
Customer’s premises.
All metering installations shall be accessible from a public
area.
2.3.7.1.2 Costs
All the Distributor metering equipment located on the Customer’s
premises are in the care and at the risk of the Customer and if destroyed or
damaged, other than by normal usage, the Customer will pay for the cost of
repair or replacement.
Regardless of any charges for metering installations, all meters
and meter instrumentation equipment shall remain the property of the
Distributor and maintenance of this equipment shall be the Distributors’
responsibility. Where primary metering is utilized the Customer may own the
current and potential transformers.
2.3.7.1.3 Voltage
Generally, metering will be at utilization voltage. Where the
Distributor provides primary transformation, primary voltage metering will be
allowed only in special circumstances following full discussion with the
Distributor.
Customer-owned substations may require primary metering. The
provisions required for these installations shall be specified and approved by
the Distributor for each application.
2.3.7.1.4 Primary Metering
Primary metering units may be installed outdoors or within an
electrical vault as outlined in the current Electrical Safety Code. Where the
Customer prefers not to provide an approved electrical vault, the Distributor
at additional cost can provide a metering unit with non-flammable coolant.
2.3.7.1.5 Bulk Metering
Non-residential or mixed-use buildings will normally be bulk
metered by a single meter. However, where specific areas are clearly and
permanently defined and in other respects as a separate entity, individual
metering of the loads may be required.
Individual residential condominium or apartment units should be
metered individually to empower the residents with control over their
individual costs. In such instances, one or more bulk meters may still be
required at the facility for the purpose of calculating house loads and/or
transformer allowances (on Customer owned transformers) where applicable.
Individual suite metering can be installed and operated by the
Distributor or an OEB Licensed Sub- Meter Contractor. The installation and
operations of systems will comply with the requirements as outlined in the
Energy Consumer Protection Act, 2010 S.O. 2010, Chapter 8.
In all installations where the Customer requests revenue
metering remote from the secondary entrance equipment or downstream from a
Customer-owned transformer, provisions are required for a bulk meter directly
after the main switch. This bulk metering is required in addition to any public
metering provisions. The Customer will be required to contribute to the cost of
the metering installation.
Where more than one meter is required, the meters shall be
grouped where practical.
The Customer shall permanently and legibly identify all metered
services with respect to correct municipal 911 address and unit #. The
identification shall be applied to all service switches and breakers and to all
meter cabinets and meter mounting devices that are not immediately adjacent to
the service switch. The Customer shall insure that all service identifications
are accurate and by not doing so will be held responsible. The Distributor
shall issue a Meter Verification Sheet for this purpose to the owner or
contractor.
In any case, a copy of the metering layout plan shall be
forwarded to the Distributor for review and approval.
If the distribution of the metered load circuit is in dispute,
(ie: circuits from one premise is found to supply a second premise) the
Distributor reserves the right to transfer all accounts into the Property
Owners’ name until such time as the problem has been resolved, and the
individual metering can be clearly identified with the individual units.
2.3.7.1.6 Locks
All devices on the line side of the Distributor metering shall
have provisions for padlocking.
For commercial and industrial services, the Customer’s main
switch shall have provisions for padlocking the switch handle in the open
position, and the switch cover (or door) in the closed position.
When a disconnect device has been locked in the “OFF” position
by the Distributor, under no circumstances shall anyone other than the
Distributor or its authorized agent remove the lock.
At the discretion of the Distributor, a dual locking
arrangement, a Distributor master key arrangement, a key box arrangement, or a
copy of the access key will be required for access.
2.3.7.1.8 Maintenance of Metering Equipment
Unless owned by the Distributor, the Customer is responsible for
maintaining the integrity of the meter base and cabinets, ensuring they meet
the required mechanical, electrical, and safety standards.
For residential meters the meter base is considered Customer
owned and is to be maintained by the property owner. Any requirement for
maintenance should be coordinated with the Distributor and completed in
accordance to all applicable standards.
Commercial/Industrial installations result in varying ownership
of cabinets and equipment. The property owner is to maintain any metering
equipment under their control. Any requirement for maintenance should be
coordinated with the Distributor and completed in accordance to all applicable
standards.
2.3.7.2
Current Transformer Boxes
Where a current transformer box is required, it shall be CSA
approved, of a size and type as stipulated by the Distributor and include a
provision for padlocks. A removable plate shall be provided in the box for
mounting the equipment.
As an alternative to a separate CT box and meter, a single
enclosure combining both functions may be feasible. Contact the Distributor for
details.
In cases where the CTs only meter a portion of the metal clad
switchgear (such as house loads), a separate disconnect switch must be
installed ahead of the metering compartment so that the service can be
de-energized without any interruption to the main service supply.
Generally, one house load meter only will be allowed. Additional
house load meters will require authorization from the Distributor.
An appropriate CT box must be used to enable conductors to be
trained in place. Where parallel conductors are used, the sum of the conductors
will determine the size of the CT box to use. In all cases the Customer shall
supply suitable cable termination lugs.
On all electrical services that require current transformers and
the neutral for metering, an isolated neutral block shall be provided in the
current transformer box.
Customer/Contractor must receive Distributor authorization
regarding size, type and location of meter cabinets before installation of
apparatus.
2.3.7.3
Interval Metering
The Distribution System Code, as amended from time to time,
requires the Distributor to meter Customers of specific load levels with
pulse-recording meters, or interval meters, which are interrogated remotely.
The Distributor, at its’ sole discretion, may also require such metering on any
Customer whose load characteristics may have a significant impact on the Net
System Load Shape, or where reasonable access to the meter for the purpose of
acquiring metering data may be limited due to location.
A Customer that requests interval metering shall compensate a
Distributor for all incremental costs associated with that meter, including the
capital cost of the interval meter, installation costs associated with the
interval meter, ongoing maintenance (including allowance for meter failure),
verification and re-verification of the meter, installation and ongoing
provision of communication line or communication link with the Customer’ s
meter, and cost of metering made redundant by the Customer requesting interval
metering. The communication system utilized for interval meters shall be in
accordance with the Distributors’ requirements.
Where such metering exists, the Distributor will consider
Customer requests to provide a secondary pulse for load control or
Customer-owned metering at the Customers’ expense.
In keeping with the intent of the Legislation and accompanying
amendments, once an interval meter installation is processed as part of the
Distributors’ settlement process and has affected the relevant changes to the
Distributors net system load, the installation must not be changed back to a
non- interval meter installation.
Where a Customer submits a request to read their own interval
meter, the Distributor shall make this access available given the following
conditions are met:
·
The meter has the capability of read-only password protection
·
The Customer provides a signed copy of the “Interval Metering
Access Agreement” to the Distributor.
2.3.7.3.1 Interval Metering Communications
Solid-state recorders and/or Electronic Interval Meters
installed by the Distributor have provision for remote interrogation. When a
phone line is required for this purpose, the Owner will facilitate the
provision of a telephone line in the metering cabinet for the Distributors’
metering purposes.
At its’ sole discretion, for metering installations where loss
of metering data would cause a substantial impact on the Distributors
Settlement System and other Customers, the Distributor may require the phone
line to be dedicated for metering purposes only. When such dedicated phone
lines are required, phone lines must be installed and functioning prior to the
new service being energized.
A dedicated phone line is a voice quality telephone line, which
is active 24 hours a day to the metering location extension jack, which is
mounted on the metering board.
When the communication system relies on radio frequency the
Owner will facilitate the provision of a location of an external antenna. The
Distributor will install the antenna and the associated wiring.
2.3.7.3.2 Smart Meters
The Ontario Government has mandated the installation of Smart
Meters as a replacement to current metering technology. The Distributor will
install smart meters in accordance with regulations and policies set out by
Government authorities.
Residential and small General Service Customers, who are billed
on an energy-only basis, will be provided with a smart meter. Metering
requirements for Large General Service Customers will be reviewed in concert
with any new Regulations.
Where the Customer installation requires by-directional metering
(example for generation connections) the additional cost of the metering may be
charged as an additional fee.
2.3.7.4
Meter Reading
The Distributor will read all meters on a regularly scheduled
basis whenever possible. If an actual meter reading is not obtained, the Customer
shall pay a sum based on an estimated demand and/or energy for electricity used
since the last meter reading.
2.3.7.5
Final Meter Reading
When a service is no longer required, or the Customer is
switching Energy Providers, the Customer shall provide the Distributor
sufficient notice of the date so that a final meter reading can be obtained.
The Customer shall provide access to the Distributor or its agents for this
purpose.
If a final meter reading is not obtained, the Customer shall pay
a sum based on an estimated demand and/or energy for electricity used since the
last meter reading. Estimates will be based on available historical
consumption.
Where Smart Meters are installed the final reading can be
accommodated through remote interrogation. If at the time of final read remote
access to the meter is not available an estimate of consumption will be made
based on meter reading system data calculated to estimate the final billing.
2.3.7.6
Faulty Registration of Meters
Metering electricity usage for the purpose of billing is
governed by the Federal Electricity and Gas Inspection Act and associated
regulations, under the jurisdiction of Measurement Canada, Industry Canada. The
Distributors’ revenue meters are required to comply with the accuracy specifications
established by the regulations under the above Act.
In the event of incorrect electricity usage registration, the
Distributor will determine the correction factors based on the specific cause
of the metering error and the Customer’s electricity usage history. The
Customer shall pay for all the energy supplied, a reasonable sum based on the
reading of any meter formerly or subsequently installed on the premises by the
Distributor, due regard being given to any change in the character of the installation
and/or the demand.
If the incorrect measurement is due to reasons other than the
accuracy of the meter, such as incorrect meter connection, incorrect connection
of auxiliary metering equipment, or incorrect meter multiplier used in the bill
calculation, the billing correction will apply for the duration of the error.
The Distributor will correct the bills for that period in accordance with the
regulations under the Act.
Where the Distributor has under billed a Customer or retailer,
the maximum period of under billing for which the Distributor is entitled to be
paid will be as specified in the latest revision of the Acts and Codes. Where
the Distributor has over billed a Customer or retailer, the maximum period of
over billing for which the Customer or retailer is entitled to be repaid will
be as specified in the latest revision of the Acts and Codes.
2.3.7.7
Meter Dispute Testing
The Distributor will attempt to resolve billing enquiries.
However, to give Customers confidence in the accuracy of electricity meters,
the Distributor will conduct an internal investigation to verify the accuracy
of any meter the Customer believes to be recording incorrectly. If the internal
investigation does not resolve the matter, the Customer or the Distributor may
request Measurement Canada to test the meter as per the Federal Electricity and
Gas Inspection Act.
If the test indicates that the meter is not accurate, the
Customer’s historic billing will be adjusted, and the Distributor shall pay the
full costs of the meter dispute testing.
2.3.7.8
Location
The location of the indoor or outdoor meter shall be readily
accessible at all times and acceptable to the Distributor. If a meter is
recessed or enclosed after installation, without the prior approval of the
Distributor, the service may be subject to disconnection.
The location of the service entrance, routing of duct banks,
metering, and all other works will be established through consultation with the
Distributor. Failure to comply may result in relocation of the service plant at
the Owner’s expense.
In all locations where Commercial/Industrial revenue metering is
accessible to the general public, a lockable enclosure or a room for service
equipment and meters, shall be provided by the Owner at the discretion of the
Distributor, as follows:
·
An electrical room reserved solely for metering equipment or
·
Metal enclosed switchgear approved by the Distributor or
·
A suitable metal metering cabinet or
·
A vandal proof cage.
2.3.7.9
Meter Mounting Heights
Provision for metering shall facilitate a practical mounting
height for revenue meters in compliance with the Distributor’s standard
specifications and all applicable codes and regulations.
2.3.7.10
Environment
The following requirements apply to the areas allocated for
revenue metering.
The Customer to the satisfaction of the Distributor shall
provide where there is the possibility of danger to workmen, or damage to
equipment from moving machinery, dust, fumes, or moisture, protective
arrangements.
A clear safe working space of not less than 1.2 m (48″) in
front of the installation from the floor to ceiling with a minimum ceiling
height of 2.1 m (84″) provided to insure the safety of the Distributor or
other authorized employee(s) who may be required to work on the installation.
Where excessive vibration may affect or damage metering
equipment, adequate shock-absorbing mounting shall be provided and installed by
the Customer.
2.3.7.11
Meter Sockets
The owner will supply and install a meter socket as specified by
the Distributor. Meter sockets will be directly accessible to the Distributors’
staff and remain in a safe and maintainable status.
A listing of approved revenue metering sockets is available from
the Distributor.
2.3.7.12
Cabinets
Where required by these Conditions of Service the Owner shall
supply and install a meter cabinet to the Distributors’ requirements.
Meter cabinets shall be installed indoors, except where special
permission is granted by the Distributor to install the meter cabinet outside.
In such cases, an approved weather proof, lockable, C.S.A. approved meter
cabinet shall be provided by the Customer.
2.3.7.13
Metering Loops
Three-phase, four-wire services will require a loop for
metering, within the meter cabinet, for all three phases.
Mineral insulated, solid, or hard drawn wire conductors are not
acceptable as metering loops.
2.3.7.14
Metal Enclosed Switchgear
The following regulations apply to the installation of
instrument transformers and metering equipment within metal enclosed
switchgear.
The Distributor will provide the following revenue metering
equipment as required:
·
Colour coded secondary wiring
·
Revenue meters
The Owner shall:
• Consult with The Distributor regarding the installation of
metering equipment, which may include:
·
Potentialtransformers
·
Potentialtransformerfuseholdersandfuses
·
Currenttransformers
·
Phonelineforremoteinterrogationofmeters
·
DuplicatePulseInitiators
·
Provide complete shipping instructions for instrument
transformers for those projects
where these are to be provided by the Distributor for installation by the
switchboard
manufacturer.
·
Installinstrumenttransformers,meteringcabinetandconduit.
·
Each main bus bar to be drilled and tapped (10-32) or (10-24) on
the line side of the
removable current transformer link.
·
ReceiveDistributor’sapprovalforaccess/location
• Submit two copies of the manufacturer’s switchboard drawings,
for approval, dimensioned to show provision for and arrangement of the
Distributors’ metering equipment.
Meters shall be installed by the Distributor in a Customer-owned
metal cabinet of a size and type pre- approved by the Distributor, mounted at
an approved location separate from the switchgear.
Tamper proof or sealable rigid conduit or any equally approved
conduit of a size and type specified by the Distributor shall be installed
between the CT compartment of the switchgear and the meter cabinet.
For conduit installations greater than 30 m (100′), in
length or where several bends are necessary, larger conduits or other special
provision may be required, at the discretion of the Distributor.
2.3.7.15
Switchgear Connected to Wye Source
Where a Wye source neutral connection is to be used or grounded,
the Owner shall provide a conductor sized to the requirements of the Ontario
Electrical Safety Code from the instrument transformer compartment to the
neutral connection.
2.3.7.16
Four Quadrant Metering (Generation)
All Ontario Energy Board-licensed generators connected to the
distribution system that sell energy and settle through the Distributor’s
retail settlement process shall be required to install metering that meets the
requirements of the Distribution System Code as approved by the Ontario Energy
Board, and/or the Market Rules as approved by the Independent Electricity
System Operator.
2.3.7.17
Net Metering for Embedded Generation
Customers with specific generation facilities may reduce their
net energy costs by exporting surplus generated energy back onto the utility
distribution system. Surplus energy exported onto the utility distributions
system will be calculated as a credit against the energy the Customer consumes
from the distribution system.
All Customers wishing to become a Net Metering participant must
meet all of the following conditions:
·
The electricity is generated primarily for the Customer’s own
use;
·
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;
·
The Customer conveys the electricity that is generated directly
from the point of generation
to another point for the generator’s own consumption without reliance on the
Distributor’s
distribution system
·
The customer conveys any electricity that is in excess of what
is consumed by the Customer
into the Distributor’s distribution system; and
·
The customer is not a party to any contract or agreement, other
than a net metering agreement to which this Regulation applies, that provides
for the sale, in whole or in part, of the electricity that the generator
conveys into the distributor’s distribution system
– (Reference – Ontario Regulation 541/05 – Net Metering, Section 7)
In order to participate in the Net Metering program, the
Customer will be required to meet all the parallel generation requirements for
Connecting Micro-Generation Facilities, as applicable to the generator size, as
found in Section 3.5 – Embedded Generation Facilities
Meters for Net Metering may be either one-way or bi-directional
at the discretion of the Distributor.
Reference: A Customer considering a generation project can find
additional information on the technical and administrative requirements in the
CHEC Generation Guide and Appendix E and Appendix F of the Distribution System
Code. A copy of these documents can be obtained from your local utility upon
request.
2.3.7.18
Metering for Embedded Generation
Generating facilities will connect directly to the distribution
system at a voltage of 44kV or less. Output from the generating facility shall
be metered in a manner to ensure proper collection of required information for settlements.
Such metering may include:
·
a. for generators of 10 kW or less and connected to the line
side of the load meter
(i) a bi-directional kWh meter to measure energy consumed and energy exported;
or
(ii) a bi-directional interval meter to
measure hourly energy consumed and energy exported
·
b. for all other generators, an interval meter must be
installed.
In some instances, the load meter may also have to be changed in
order to accommodate proper settlement calculations. The generator will be
responsible for costs associated with the connection to the distribution system
and any required metering installation as defined by the relevant Codes and
Acts.
2.4
Tariffs and Charges
22.4.1
Service Connection
Charges for Service Connections are set out in the Distributors
approved rates, (Miscellaneous Rates and Charges) and may be obtained by
request from the Distributor. Notice of Rate revisions may be published in the
local newspapers and or mailed out to all Customers with the first billing
issued at revised rates.
2.4.2
Energy Supply
The Distributor shall provide Customers connected to the
Distribution System with access to electricity through Standard Supply Service
as defined in the Standard Supply Service Code, the Retail Settlement Code or
as mandated though Legislation or Regulations issued by the OEB or the Ministry
of Energy.
Disputes arising from charges relating to Standard Supply
Service shall be directed to the Distributor.
Customers will be switched to a licensed Retailer of choice only
if the retailer has a Service Agreement with the Distributor. The Customer’s
authorized Retailer through the Electronic Business Transaction system (EBT)
must make the Service Transfer Request (STR) in accordance with the rules
established and amended from time to time by the Ontario Energy Board.
Disputes arising from charges relating to Retailer Service shall
be directed to the Retailer.
The Distributor may, at its discretion, refuse to process a
Service Transfer Request for a Customer to switch to a Retailer if that
Customer owes money to the Distributor for Distribution Services and or
Standard Supply Service.
2.4.2.1
Wheeling of Power
Customers considering delivery of electricity through the
Distributors’ Distribution System shall contact the Distributor for technical
requirements and current applicable Rates.
2.4.3
Security Deposits & Agreements
Whenever required by the Distributor, the Customer shall provide
a security deposit in accordance with the Distributor’s most recent Security
Deposit Policy.
Where a Customer proposes the development of premises that
requires the Distributor to place equipment orders for special projects, the
Customer is required to sign the necessary Supply Agreements and furnish a
suitable deposit before such equipment is ordered by the Distributor. If an
expansion or enhancement of the distribution system is required to facilitate a
connection, the Distributor may need to perform an Economic Evaluation to
establish the capital contribution required from the Customer. The Customer
should review the attached Distribution Connection Process for further
information.
2.4.4
Billing & Payment
The Distributor will bill Customers on a monthly basis. The
Distributor may elect to bill on a more frequent basis in order to manage
Customer non-payment risk, in accordance with the Distribution System Code
(DSC).
2.4.4.1
– Account Setup Charge:
A New Account Setup Fee (or Occupancy Charge) covers the cost of
setting up a new account and performing the final meter reading when an account
is closed. The New Account Setup fee will apply to all new accounts that move
from one location to another.
2.4.4.2
– Equal Payment Plan:
The Distributor shall offer to all non-seasonal residential
Customers and general service < 50kW Customers receiving standard supply an
equal monthly billing plan option as outlined in the Standard Supply Service
Code.
2.4.4.3
– Estimated Billing:
Where a smart meter or interval meter has been installed, a
Distributor shall issue a bill to a residential or general service < 50 kW
Customer based on an actual meter read.
Despite the above, to account for exceptional circumstances, a
Distributor may issue a bill to a residential or general service < 50kW
Customer with a smart meter or interval meter based on estimated consumption
twice every 12 months.
2.4.4.4
– Billing Errors
When a billing error has resulted in overbilling and Measurement
Canada is not involved, the Customer shall be credited with the erroneously
paid amount for a period not exceeding two (2) years, starting from the date
that can be reasonably proven when the problem/condition began. If the billing
error is not a result of the Distributor’s standard documented billing
practices, the Distributor shall pay interest on the amount credited to the
Customer, equal to the rate as dictated by the Retail Settlement Code.
The Customer shall be refunded the overbilled amount by either a
credit to their account or by cheque. If there are outstanding arrears on the
account, the Distributor will apply the refund to the account, first.
When a billing error has resulted in under billing and
Measurement Canada is not involved, the Customer will normally be charged with
the amount erroneously under billed for a period not exceeding two (2) years,
in the case of a Customer who was not responsible for the error, or the
duration of the defect for any proven cases of willful damage or Energy
Diversion.
In the case of under billing, the Customer, upon request, may be
permitted to re-pay the amount over a period of time mutually agreed by both
the Distributor and the Customer, but, no longer than the duration of the
error. In cases of overbilling, the Distributor shall refund the amount owed to
the Customer upon the completion of the investigation and over a period of time
mutually agreed to by both the Distributor and the Customer, but, no longer
than the duration of the error.
The Distributor will not charge interest on amounts owing due to
billing errors, provided that the Customer was not aware of the defect or has
not tampered with or damaged the metering installation. In cases where
tampering has occurred, the interest charge will be at the discretion of the
Distributor.
In cases in which Measurement Canada is involved, Measurement
Canada will act as an arbitrator and determine the appropriate adjustment.
Billing corrections shall be calculated using the actual rates
in place at the time of the error.
2.4.4.5
– Payment:
Except as otherwise permitted by this policy, a Distributor
shall not treat a bill issued to a Customer as unpaid, and shall not impose any
late payment or other charges associated with non-payment, until a minimum
payment period of 20 days from the date on which the bill was issued to the
Customer has passed.
A Distributor may provide for longer minimum payment periods,
provided that any such longer minimum payment periods are documented in the
Distributor’s Conditions of Service.
2.4.4.6
– Method of Enforcement where Payment is Not Received:
Failure to pay bills on the due date will result in the
immediate implementation of the Distributor’s Collection Policy which may lead
to the discontinuation of electrical service.
For additional information on billing and payments, please refer
to the Distributor’s Billing and Payment Policy and/or the Distributor’s
Collection Policy.
2.4.5
Late Payment Charges & Other Charges
Bills are rendered for distribution services and electrical
energy used by the Customer.
Bills are due when rendered by the utility and are payable in
full by the due date. A Customer may pay the bill without the application of a
late payment charge up to a due date as specified in the Distribution System
Code. This due date shall be identified clearly on the Customer’s bill.
A late payment charge of 1.5% per month (19.56% annually) is
applied to all accounts not paid by the due date. This charge is applied to any
overdue amount, excluding final bills and arrears payment arrangements. If the
Customer has made a partial payment on or before the due date, the late payment
charge shall only apply to the amount of the bill outstanding at the due date,
inclusive of arrears from previous billings.
Where payment is made by mail or at a financial institution,
payment will be deemed to be made consistent with the requirements in the
Distribution System Code.
A partial payment will be applied to any outstanding arrears
before being applied to the current billing, unless special considerations have
been made by the utility or the conditions of the Distribution System Code
outlines an alternate process.
Outstanding bills are subject to the collection process and may
ultimately lead to the service being discontinued or limited. Service will be
restored once satisfactory payment has been made. Discontinuance of service
does not relieve the Customer of the liability for arrears.
The Distributor shall not be liable for any damage on the
Customer’s premises resulting from such discontinuance of service. A
reconnection charge may apply where the service has been disconnected due to
non-payment.
The Customer will be required to pay additional charges for the
processing of non-sufficient fund (N.S.F.) cheques.
A Customer Disconnected for non-payment will be required to pay
a Reconnection fee. The Distributor requires that a Person over the age of
eighteen (18) be at the Premise at the time of Reconnection. If a Distributor’s
representative arrives at the Premise and is not able to complete Reconnection
because there isn’t a Person over the age of eighteen (18) present, the request
will be closed, and a Reconnection charge will be applied to the Customer’s
account. The Customer will be required to arrange Reconnection again, with a
second Reconnection charge to be applied to the Customer’s account when the
Service Reconnection is completed.
For additional information on these and other charges, please
see the “POLICIES Relevant to Conditions of Service” section below.
2.5
Customer Information
The Distributor reserves the right to request specific
information from the Customer in order to facilitate the normal operation of
its business. Failure of a Customer to supply such information may prevent the
normal continuation of service.
The Retail Settlement Code as amended from time to time
specifies the rights of Customers and their retailers to access current and
historical usage information and related data and the obligations of
Distributors in providing access to such information.
Under these requirements, the Distributor shall upon
authorization by a Customer make the following information available to the
Customer or the Retailer that provides electricity to a Customer connected to
the Distributors’ distribution system:
·
The Distributors’ account number for the Customer,
·
The Distributors’ meter number for the meter or meters located
at the Customer’s service address
·
The Customer’s service address,
·
The date of the most recent meter reading,
·
The date of the previous meter reading,
·
Multiplied kilowatt-hours recorded at the time of the most
recent meter reading,
·
Multiplied kilowatt-hours recorded at the time of the previous
meter reading,
·
Multiplied kW for the billing period (if demand metered),
·
Multiplied kVA for the billing period (if available),
·
Usage (kWh’s) for each hour during the billing period for
interval-metered Customers
·
An indicator of the read type (e.g., Distributor read, consumer
read, Distributor estimate, etc.)
·
Average distribution loss factor for the billing period
his information will be provided to the Customer / Retailer upon
request twice per year at no charge. The Distributor may request a fee to
recover costs for additional requests. A request is considered to be data
delivered to a single address. Thus, a single request to send information to
three locations is considered three requests.
The Distributor acknowledges that no confidential information
regarding its’ Customers shall be released to a third party without the
expressed prior written consent of the Customer unless the request is
rightfully received from the third party requesting the information, or the
Distributor is legally required to disclose such information under the terms
and in accordance with the Municipal Freedom of Information and Protection of
Privacy Act, R.S.O. 1990, c. F.31.
SECTION
3 CUSTOMER SPECIFIC
3.1
Residential
This section refers to the supply of electrical energy to
Customers residing in residential dwelling units.
3.1.1
General
Energy is generally supplied as single phase, 3-wire, 60-Hertz,
having a nominal voltage of 120/240 Volts.
There shall be only one Demarcation Point to a dwelling.
In circumstances where two existing services are installed to a
dwelling, and one service is to be upgraded, the upgraded service will replace
both of the existing services.
All new single-family homes will be required to install their
primary and secondary service wires to the specifications contained within the
Distributors’ technical specification document.
Whether the method of supply will be overhead, or underground
will be at the discretion of the Distributor. The Distributor will adhere to
any existing regulations subject to requirements of authorities.
Unless specifically documented otherwise to the Customer, where
the Distributor has taken ownership of such plant all services installed by the
Distributor or by an approved contractor using approved materials, will be
maintained by the Distributor.
3.1.2
Early Consultation
The Customer shall supply a completed Site Planning document and
related information to the Distributor well in advance of installation
commencement. (see appendix) The information shall be supplied in a manner
requested by the Distributor at the time of the application.
3.1.3
Standard Connection Allowance
For the purposes of calculating Customer connection fees, the
Basic Connection for Residential consumers is defined as 100-amp 120/240 volt
overhead service.
The basic connection for each Customer shall include;
·
i. supply and installation of overhead distribution
transformation capacity or an equivalent credit for transformation equipment;
and
·
ii. up to 30 meters of overhead conductor or an equivalent
credit for underground services.
In the case of an upgrade to an existing service, where the
existing service is below the basic
connection, the credit up to the basic connection will apply.
Secondary services exceeding the basic 30-meter length may
require specific design approved by the Distributor to ensure power quality.
3.1.4
Variable Connection Fees
Any requirements above the defined basic connection shall be
subject to a variable connection charge to be calculated as the costs
associated with the installation of connection assets above and beyond the
basic connection. The Distributor may recover this amount from a Customer
through a connection charge or equivalent payment.
3.1.5
Point of Demarcation
In all cases the final Demarcation Point will be the decision of
the Distributor.
The Customer must obtain a Demarcation Point Location from the
Distributor before proceeding with the installation of any service. Failure to
do so may result in the Demarcation Point having to be relocated at the
Customer’s expense.
Maintenance of the portion of the Secondary Service owned by the
Distributor includes repair and like-for-like replacement of a wire or cable
that has failed irreparably. The Customer is responsible for all civil work,
supports, vegetation and landscaping associated with any such repair or
replacement of the portion of Secondary Service owned by the Distributor.
3.1.5.1
Secondary Service Connections
The Point of Demarcation for residential services up to and
including 400 amps is at the line side of the Meter Base for Underground
services, and at the top of the stack for Overhead services, beyond which the
Customer bears full responsibility for installation and maintenance.
The Point of Demarcation for residential services over 400 amps
is at the secondary side of the transformer.
For Secondary Services wholly owned and maintained by the
Customer, the Demarcation Point is the secondary connection at the transformer
or the service bus.
The Customer shall install, own, and maintain the secondary
conductor under any of the following conditions:
(a) conductor terminations are inside the Customer’s building;
(b) conductor is installed beyond the service entrance;
(c) conductor is connected to a Primary Service; or
(d) conductor is a non-standard installation.
3.1.5.2
Primary Service Connections
For Primary Service, the Demarcation Point is the primary
connection at the Distributor’s Distribution system.
3.1.6
Supply Voltage
A Residential building is supplied at one service voltage per
land parcel.
Depending upon the location of the building the supply voltage
will be one of the following:
·
120/240 Volts 1 Phase 3 Wire
·
120/208 Volts 3 Phase 4 Wire
·
347/600 Volts 3 Phase 4 Wire
The Owner shall make provision to take delivery at one of the
nominal utilization voltages as specified by the Distributor. The Owner shall
obtain prior approval from the Distributor for the use of any specific voltage
at any specific location.
3.1.7
Access:
At the Distributors discretion, service locations requiring
access to adjacent properties (mutual drives, narrow side setbacks, etc.) will
require the completion of an easement in the Distributors’ name, or a “Letter
of Permission” from the property owner(s) involved.
The Customer will provide unimpeded and safe access to the
Distributor at all times for the purpose of installing, removing, maintaining,
operating or changing metering and distribution plant.
3.1.8
Metering:
The owner will supply and install a meter socket complete with
collar acceptable to the Distributor and which meets the Ontario Electrical
Safety Code. Meter sockets will be directly accessible to the Distributor and:
·
Mounted 1.73 meters (5’- 8”) from the finished grade to the
center of the meter and, either on the exterior of the front of the building
or, within 3 meters of the front of the building, at the discretion of the
Distributor.
·
Installed ahead of (on the line side of) the main disconnect
switch.
·
Installed in a location, which is and will remain unobstructed
by fences, hedges, expansions,
sunrooms, porch enclosures, and any other impediments.
·
If the meter is not to be installed on the actual building, it
is important to contact the
Distributor for specific location instructions prior to installation.
·
Remain accessible, safe, and maintainable
For more details refer to
section 2.3.7 in these Conditions of Service.
3.1.9
Overhead Service
The Owner will provide service equipment to both the
Distributors’ and ESA requirements, and be of sufficient height to maintain
proper minimum clearances. The Owner’s main switch and the overhead service
conductors will be of compatible capacity.
3.1.10
Underground Service
Underground secondary services will be installed at the Owners’
expense, to the Distributor’s specifications. The Owner’s main switch and the
underground service conductors will be of compatible capacity.
3.1.11
Street Townhouses and Condominiums:
NOTE: Street
Townhouses and Condominiums requiring centralized or bulk metering will be
covered under section 3.2 of these Conditions of Service. Also 3.1.11.2
3.1.11.1
Service Information:
The Owner will enter into a Servicing Agreement with the
Distributor, governing the terms and conditions under which the electrical
distribution system and services will be designed and installed.
The Owner will provide all of the civil works to accommodate the
Distributor and will pay the complete cost of the electrical distribution
system, design and services.
·
The distribution system and services shall be underground unless
otherwise approved.
·
One service will be provided for each unit.
·
The nominal service voltage will be 120/240 volts, 1 phase, 3
wire.
·
The Distributor will approve the location of duct banks, service
routings and meter bases.
·
Distribution plant shall not be installed until grade is at +/-
150 mm of final grade unless
otherwise approved by the Distributor.
·
Street lighting will be to Municipal standards and installed at
the Owner’s expense.
3.1.11.2
Metering:
The Owner will supply and install meter sockets specified by the
Distributor.
Multiple or grouped meter bases will be accepted only when prior
approval has been given by the Distributor both as to type and proposed
location. A completed meter verification form shall be provided to the
Distributor prior to energization, and shall remain accessible, safe, and
maintainable.
Meter sockets will be located on the exterior front wall of the
units and will be directly accessible to the Distributor.
·
Mounted on the front wall 1.73 meters (5’ – 8”) above finished
grade to the center of the meter
·
Installed ahead of (on the line side of) the main disconnect
switch
·
Installed in a location, which is and will remain unobstructed
by fences, hedges, expansions,
sunrooms, porch enclosures, and any other impediments.
·
If the meter is not to be installed on the actual building, it
is important to contact the Distributor for specific location instructions
prior to installation.
Normally the service will not be energized until the outside
finish in the area of the revenue meter has been completed. If exceptions are
made to this, then the general contractor will be responsible for ensuring that
the meter is suitably protected while work is being done on the exterior wall
adjacent to the meter. The general contractor will be entirely responsible for
all costs for materials and labour for repairing or replacing a damaged meter.
Meters must always remain fully accessible for reading, replacement, repair,
and general maintenance. Customers and/or their contractors should contact the
Distributor prior to enclosing meters and/or meter bases to ensure that safety
and access are not compromised, or the Distributor may disconnect the service
until remedial action, as determined by the Distributor, are undertaken.
3.1.12
Seasonal and Remote Dwellings:
Due to the varied nature of Seasonal and Remote Dwellings some
special arrangements may be required to service these locations. Arrangements
will be made in such a manner to provide services such as restoring power,
maintenance of equipment or new construction requests to water access or remote
Customers, without endangering personnel or the public.
3.1.12.1
Service Information:
The Owner will enter into a Servicing Agreement with the Distributor,
governing the terms and conditions under which the electrical distribution
system services will be provided.
In the event of a power interruption, the Distributor will
respond to and take reasonable steps to restore power. The Distributor reserves
the right to claim and take any actions or legal proceedings for recovery or
compensation as a result of costs due to inconvenience, disruption of schedule,
and/or loss of efficiency or productivity of any nature whatsoever related to
misidentification of power quality issues or outages by the customer or its
contractor and/or subcontractors, suppliers, and/or or materialmen of any tier.
3.1.12.2
Access:
All operations performed by the Distributor and its agents shall
be performed within the rules and regulations set out by the appropriate
authorities including but not limited to: ESA, Ministry of Labour, Ministry of
Transportation, etc.
·
Night crossings
The Distributors’ transportation equipment will not be used to cross any water
1⁄2 hour before sunset and 1⁄2 hour after sunrise due to safety
concerns. It will be at the discretion of the Distributor whether they will
board Customer owned transportation equipment in these circumstances.
·
Ice conditions
Recognizing seasonal ice hazards, the Distributor reserves the right to suspend
water passage during freeze up and spring thaw, as well as any such time deemed
unsafe by the Distributor.
·
Severe weather conditions
Recognizing that severe weather conditions may pose undue safety hazards, the Distributor
reserves the right to postpone attempts to restore power until restoration can
be performed in a safe manner.
3.1.13
Inspection:
Prior to connection of the service the Distributor requires
notification from the Electrical Safety Authority that the electrical
installation has been inspected and approved for connection.
Provision for metering shall be inspected and approved by the
Distributor prior to connection.
The Distributor or Distributor-approved Contractor generally
installs all services. All work done shall be as per the specifications of the
Distributor and subject to inspection by the Distributor.
(Refer to section 2.1.4
for further inspection details)
3.2
General Service (Below 50 kW)
3.2.1
General
This section refers to the supply of electrical energy to
General Service Buildings requiring a connection with a connected load less
than 50 kW, and Town Houses and Condominiums described in section 3.1.8 that
require centralized bulk metering.
General Service buildings are defined as buildings that are used
for purposes other than single- family dwellings.
3.2.2
Early Consultation
Detailed regulations cannot be stated which would be applicable
to all cases, therefore the Owner will consult with the Distributor in the
early planning stages to ascertain the Distributors’ requirements.
The Owner shall supply a completed Electrical Planning
Requirements Form to the Distributor well in advance of installation
commencement to allow the Distributor time for proper planning, ordering of
equipment etc.
3.2.3
Basic Connection Charge
All costs attributed to the connection of a new General Service
Customer (Below 50 kW) shall be recovered either as part of the Distributor’s
revenue requirements or through a basic connection charge to the Customer.
3.2.4
Variable Connection Charge
All costs associated with the installation of connection assets
shall be subject to a variable connection charge. The Distributor may recover
this amount from a Customer through a connection charge or equivalent payment.
If an expansion of the distribution system is required to facilitate a
connection, the Distributor may need to perform an Economic Evaluation to
establish the capital contribution required from the Customer. The Customer
should review the attached Distribution Connection Process for further
information.
3.2.5
Point of Demarcation
In all cases the final Demarcation Point will be the decision of
the Distributor.
The Customer must obtain a Demarcation Point Location from the
Distributor before proceeding with the installation of any service. Failure to
do so may result in the Demarcation Point having to be relocated at the
Customer’s expense.
Maintenance of the portion of the Secondary Service owned by the
Distributor includes repair and like for-like replacement of a wire or cable
that has failed irreparably. The Customer is responsible for all civil work,
supports, vegetation and landscaping associated with any such repair or
replacement of the portion of Secondary Service owned by the Distributor.
The Distributor shall perform the maintenance or replacement of
all underground looped cables that form part of the Distribution plant
circuits. Following maintenance, surface restoration by the Distributor will
include only soil, sod, gravel or asphalt.
Where damage can be shown to be the Owner’s liability,
maintenance and repair are at the Owners’ expense.
3.2.5.1
Secondary Service Demarcations
A General Service Customer Demarcation Point is at the secondary
side of the transformer, or as otherwise set by the Distributor, beyond which
the Customer bears full responsibility for installation and maintenance.
In some instances, where it is in the best interest of the
operation of the distribution system, the Distributor may establish the
Demarcation Point at the top of stack for overhead services or at the meter
base for underground services.
The Demarcation Point might be located on an adjacent property.
In such cases, a registered easement must exist.
3.2.5.2
Primary Service Demarcations
For Primary Service, the Demarcation Point is the primary
connection at the Distributor’s Distribution system.
3.2.6
Supply Voltage
A General Service building is supplied at one service voltage
per land parcel.
Depending upon the location of the building the supply voltage
will be one of the following:
·
120/240 Volts 1 Phase 3 Wire
·
120/208 Volts 3 Phase 4 Wire
·
347/600 Volts 3 Phase 4 Wire
The Owner shall make provision to take delivery at one of the
nominal utilization voltages as specified by the Distributor. The Owner shall
obtain prior approval from the Distributor for the use of any specific voltage
at any specific location.
3.2.7
Access:
At the Distributor’s discretion, service locations requiring
access to adjacent properties (mutual drives, narrow side setbacks, etc.) will require
the completion of an easement in the Distributors’ name, or a “Letter of
Permission “from the property owner(s) involved.
The Customer will provide unimpeded and safe access to the
Distributor at all times for the purpose of installing, removing, maintaining,
operating or changing metering and distribution equipment.
3.2.8
Metering:
The owner will supply and install a meter socket complete with
collar acceptable to the Distributor. Meter sockets will be directly accessible
to the Distributor and unless otherwise specified during the early consultation
process:
·
Mounted 1.73 meters (5’ – 8”) from the finished grade to the
center of the meter and, either on the exterior of the front of the building
or, within 3 meters of the front of the building, at the discretion of the
Distributor.
·
Installed ahead of (on the line side of) the main disconnect
switch.
·
Installed in a location, which is and will remain unobstructed
by fences, hedges, expansions,
sunrooms, porch enclosures, and any other impediments.
·
If the meter is not to be installed on the actual building, it
is important to contact the
Distributor for specific location instructions prior to installation.
·
Remain accessible, safe, and maintainable
For more details refer to
section 2.3.7 in these Conditions of Service.
3.2.9
Overhead Service:
In circumstances where Commercial buildings cannot reasonably be
supplied electrical energy by an underground service, the Distributor shall use
its’ sole discretion based on acceptable industry practices in establishing the
specific requirements for the service installation.
3.2.10
Underground Service:
Under normal circumstances, Commercial buildings are supplied
electrical energy by an underground service through a single point of entry for
each land parcel, at a location specified by the Distributor.
3.2.11
Supply of Equipment:
The Distributor supplies, installs and maintains subject to the
variable connection fee:
·
Primary switchgear.
·
Primary transformation equipment.
·
Meter and secondary metering transformers.
The Owner shall supply, install and maintain any additional
equipment required for the connection beyond the point of Demarcation.
3.2.12
Inspection:
Prior to connection of the service the Distributor requires
notification from the Electrical Safety Authority that the electrical
installation has been inspected and approved for connection.
Provision for metering shall be inspected and approved by the
Distributor prior to connection.
The Distributor or Distributor-approved Contractor generally
installs all services. All work done shall be as per the specifications of the
Distributor and subject to inspection by the Distributor.
(Refer to section 2.1.4
for further inspection details)
3.3
General Service (Above 50 kW)
3.3.1
General
This section refers to the supply of electrical energy to
General Service Customers requiring a connection with a connected load greater
than 50 kW.
3.3.2
Early Consultation
Detailed regulations cannot be stated which would be applicable
to all cases, therefore the Owner will consult with the Distributor in the
early planning stages to ascertain the Distributors’ requirements.
The Owner shall supply a completed Electrical Planning
Requirements Form to the Distributor well in advance of installation
commencement to allow the Distributor time for proper planning, ordering of
equipment etc.
3.3.3
Basic Connection Charge
All costs attributed to the connection of a new General Service
Customer (Above 50 kW) shall be recovered either as part of the Distributor’s
revenue requirements or through a basic connection charge to the Customer.
3.3.4
Variable Connection Charge
All costs associated with the installation of connection assets
shall be subject to a “variable connection charge”. The Distributor may recover
this amount from a Customer through a connection charge or equivalent payment.
If an expansion of the distribution system is required to facilitate a
connection, the Distributor may need to perform an Economic Evaluation to
establish the capital contribution required from the Customer. The Customer
should review the attached Distribution Connection Process for further
information.
3.3.5
Point of Demarcation
In all cases the final Demarcation Point will be the decision of
the Distributor.
The Customer must obtain a Demarcation Point Location from the
Distributor before proceeding with the installation of any service. Failure to
do so may result in the Demarcation Point having to be relocated at the
Customer’s expense.
Maintenance of the portion of the Primary Service or Secondary
Service owned by the Distributor includes repair and like for-like replacement
of a wire or cable that has failed irreparably. The Customer is responsible for
all civil work, supports, vegetation and landscaping associated with any such
repair or replacement of the portion of Secondary Service owned by the
Distributor.
The Distributor shall perform the maintenance or replacement of
all underground looped cables that form part of the Distribution plant
circuits. Following maintenance, surface restoration by the Distributor will
include only soil, sod, gravel or asphalt.
Where damage can be shown to be the Owner’s liability,
maintenance and repair are at the Owners’ expense.
The Distributor reserves the right to direct the operations of
any Customer owned switchgear connected to the distribution system including
those located beyond the point of demarcation.
3.3.5.1
Secondary Service Connections
A General Service Customer Demarcation Point for Customers above
50 kW is at the secondary side of the transformer, or as otherwise set by the
Distributor, beyond which the Customer bears full responsibility for
installation and maintenance.
In some instances, where it is in the best interest of the
operation of the distribution system, the Distributor may establish the Delivery
point at the top of stack for overhead services or at the meter base for
underground services.
The location of the service entrance, routing of duct banks and
all other works will be established through consultation with the Distributor.
Failure to comply may result in relocation of the service plant at the Owner’s
expense.
The Demarcation Point might be located on an adjacent property.
In such cases, a registered easement must exist.
3.3.5.2
Primary Service Connections
For GS > 50 kW class Customers, an electrical requirement in
excess of 300 kVA may require a Customer owned substation. In some instances,
primary metering may be required. (Note: 300 kVA is the threshold for a GS >
50 kW Customer class).
In General, the Demarcation Point for a General Service Customer
with a primary connection is on the primary side of the transformer at the
first available Distributor owned point of isolation, or as otherwise set by
the Distributor. This delivery point might be located on an adjacent property
from which the Distributor has an authorized easement. In all cases the final
Demarcation Point will be the decision of the Distributor.
The location of the service entrance, termination poles, routing
of duct banks, metering facilities, and all other works will be established
through consultation with the Distributor. Failure to comply may result in
relocation of the service plant at the Owner’s expense.
In some circumstances the owner may be required to construct a
private pole line. Primary conductors will be terminated complete with
cut-out(s) at the Demarcation Point by the Distributor at the owners’ expense.
Where a private pole line is to be constructed by the Owner with
an approved contractor, this shall be constructed to the ESA and the
Distributors’ requirements.
Where the Customer wishes an underground supply, the Customer
shall supply and install the underground cables and termination pole complete
with primary switch, fuses and lightning arresters. The installation shall be
subject to ESA inspection and specific approval of the Distributor. The
Customer owned termination pole must comply with items as prescribed by the
Distributor.
At the Distributors’ discretion, the Customers’ underground
service may be connected to a termination pole owned by the Distributor. In
such cases, the Distributor shall supply and install at the Customers expense,
any required primary switch, fuses, and lightning arrestors.
3.3.6
Supply Voltage
A General Service building is supplied at one service voltage
per land parcel.
Depending upon the location of the building the supply voltage will be one of
the following:
·
120/240 Volts 1 Phase 3 Wire
·
120/208 Volts 3 Phase 4 Wire
·
347/600 Volts 3 Phase 4 Wire
Depending upon the location of the building Primary supplies to
transformers and Customer owned Sub-Stations will be one of the following as
determined by the Distributor:
·
2,400/4,160 Volts 3 phase 4 wire
·
4,800/8,320 Volts 3 phase 4 wire
·
7,200/12,400 Volts 3 phase 4 wire
·
8,000/13,800 Volts 3 phase 4 wire
·
16,000/27,600 Volts 3 phase 4 wire
·
44,000 Volts – 3 Phase 3 Wire
The Owner shall make provision to take delivery at one of the
nominal utilization voltages as specified by the Distributor. The Owner shall
obtain prior approval from the Distributor for the use of any specific voltage
at any specific location.
3.3.7
Access:
At the Distributors discretion, service locations requiring
access to adjacent properties (mutual drives, narrow side setbacks, etc.) will
require the completion of an easement in the Distributors’ name, or a “Letter
of Permission “from the property owner(s) involved.
The Customer will provide unimpeded and safe access to the
Distributor at all times for the purpose of installing, removing, maintaining,
operating or changing metering and distribution plant.
3.3.8
Metering:
Meter installations will be directly accessible to the
Distributor. The owner will consult with the Distributor well in advance of
installation commencement to allow the Distributor time for proper planning and
ordering of equipment.
For more details refer to
section 2.3.7 in these Conditions of Service.
3.3.9
Overhead Service:
In circumstances where Commercial buildings cannot reasonably be
supplied electrical energy by an underground service, the Distributor shall use
its’ sole discretion based on acceptable industry practices in establishing the
specific requirements for the service installation.
3.3.10
Underground Service:
Under normal circumstances, Commercial buildings are supplied
electrical energy by an underground service through a single point of entry for
each land parcel, at a location specified by the Distributor.
3.3.11
Sub-transmission Service:
The Owner will pay for the full cost of sub-transmission
services and may in some circumstances be required to construct a private pole
line. The Distributor will terminate sub-transmission conductors complete with
live line loops and hardware at the Demarcation Point.
3.3.12
Supply of Equipment:
The Distributor supplies, installs and maintains subject to the
variable connection fee:
·
Primary switchgear.
·
Primary transformation equipment.
·
Meter and secondary metering transformers.
The Owner shall supply, install and maintain any additional
equipment required for the connection beyond the point of Demarcation.
3.3.13
Short Circuit Capacity:
The Owner shall ensure that the service entrance equipment has
an adequate short-circuit interrupting capability.
3.3.14
Inspection:
rior to connection of the service the Distributor requires
notification from the Electrical Safety Authority that the electrical
installation has been inspected and approved for connection.
Provision for metering shall be inspected and approved by the
Distributor prior to connection. The Distributor or Distributor-approved
Contractor generally installs all services. All work done shall be as per the
specifications of the Distributor and subject to inspection by the Distributor.
(Refer to section 2.1.4
for further inspection details)
3.4
General Service (Above 500 kW)
3.4.1
General
This section refers to the supply of electrical energy to
General Service Services requiring a connection at a connected load greater
than 500 kW.
3.4.2
Early Consultation
Detailed regulations cannot be stated which would be applicable
to all cases, therefore the Owner will consult with the Distributor in the
early planning stages to ascertain the Distributors’ requirements.
The Customer shall supply a completed Electrical Planning
Requirements Form to the Distributor well in advance of installation
commencement to allow the Distributor time for proper planning, ordering of
equipment, and coordination with ESA requirements etc.
Note: Larger services may require approval by the ESA to ensure
compliance with their design requirements. The Customer should contact the ESA
early in the planning stages.
The Distributor will:
·
Advise the Customer of the suitability of the in-service date
·
Arrange with the Customer for a Service Contract
·
Review the submitted drawings; return one set to the Customer
with comments and/or approval.
If requested by the Distributor, the Customer shall resubmit the drawings where
the comments
are extensive and require major changes
·
Specify the required main fuse link or relay setting for
co-ordination with the system. In case of
multiple transformer stations, a complete co-ordination study shall be
submitted by the
Customer for approval.
·
Make the final connection to the source of supply
·
Determine metering requirements
·
Advise the Transmitter of the particulars of the Customer owned
substation
3.4.3
Basic Connection
All costs attributed to the connection of a new General Service
Customer (Above 500 kW) shall be recovered either as part of the Distributor’s
revenue requirement or a basic connection charge to the Customer.
3.4.4
Variable Connection Charge
All costs associated with the installation of connection assets
shall be subject to a variable connection charge. The Distributor may recover
this amount from a Customer through a connection charge or equivalent payment.
If an expansion of the distribution system is required to facilitate a
connection, the Distributor may need to perform an Economic Evaluation to
establish the capital contribution required from the Customer. The Customer
should review the attached Distribution Connection Process for further information.
3.4.5
Point of Demarcation
In all cases the final Demarcation Point will be the decision of
the Distributor.
The Customer must obtain a Demarcation Point Location from the
Distributor before proceeding with the installation of any service. Failure to
do so may result in the Demarcation Point having to be relocated at the
Customer’s expense.
Maintenance of the portion of the Primary Service owned by the
Distributor includes repair and like for-like replacement of a wire or cable
that has failed irreparably. The Customer is responsible for all civil work,
supports, vegetation and landscaping associated with any such repair or
replacement of the portion of Secondary Service owned by the Distributor.
The Distributor shall perform the maintenance or replacement of
all underground looped cables that form part of the Distribution plant
circuits. Following maintenance, surface restoration by the Distributor will
include only soil, sod, gravel or asphalt.
Where damage can be shown to be the Owner’s liability,
maintenance and repair are at the Owners’ expense.
The Distributor reserves the right to direct the operations of
any Customer owned switchgear connected to the distribution system including
those located beyond the point of demarcation.
3.4.5.1
Service Installation
In General, the Demarcation Point for a General Service Customer
with a demand of over 500 kW is on the primary side of the transformer at the
first available Distributor owned point of isolation, or as otherwise set by
the Distributor. This delivery point might be located on an adjacent property
from which the Distributor has an authorized easement. In all cases the final
Demarcation Point will be the decision of the Distributor.
The location of the service entrance, routing of duct banks,
metering facilities, and all other works will be established through
consultation with the Distributor. Failure to comply may result in relocation
of the service plant at the Owner’s expense.
The Distributor will install overhead supply lines and required
cut-outs to the first point of support on private property. The location of
this support must be approved by the Distributor and shall be within 30 metres
of the Distributors’ existing overhead plant. All costs for materials and
labour shall be at the Customers’ expense.
The service pole or first point of support on private property
shall be considered self-supported and shall be complete with suitable hardware
for attaching the suspension insulators. The Customer shall be responsible for
all costs associated with equipment, installation, and inspection.
Where the Customer wishes an underground supply, the Customer
shall supply and install the underground cables and termination pole complete
with primary switch, fuses and lightning arresters. The installation shall be
subject to ESA inspection and specific approval of the Distributor. The
Customer owned termination pole must comply with items as prescribed by the
Distributor.
At the Distributors’ discretion, the Customers’ underground
service may be connected to a termination pole owned by the Distributor. In
such cases, the Distributor shall supply and install at the Customers expense,
any required primary switch, fuses, and lightning arrestors.
When requested, the Customer shall make provision in the substation
switchgear or transformer, for loop feeding the Distributors’ supply cables via
load interrupter switches.
In some instances, primary metering may be required.
3.4.6
Supply Voltage
A General Service building is supplied at one service voltage
per land parcel.
General Service connections above 500 kW may require a Customer
owned substation (Note: 500 kW is the threshold for a GS > 500 kW Customer
class).
Depending upon the location of the building, primary supplies to
transformers and Customer owned Sub-Stations will be one of the following as
determined by the Distributor:
·
2,400/4,160 Volts 3 phase 4 wire
·
4,800/8,320 Volts 3 phase 4 wire
·
7,200/12,400 Volts 3 phase 4 wire
·
8,000/13,800 Volts 3 phase 4 wire
·
16,000/27,600 Volts 3 phase 4 wire
·
44,000 Volts – 3 Phase 3 Wire
The Owner shall make provision to take delivery at one of the
nominal utilization voltages as specified by the Distributor. The Owner shall
obtain prior approval from the Distributor for the use of any specific voltage
at any specific location.
At the Distributors discretion, service locations requiring
access to adjacent properties (mutual drives, narrow side setbacks, etc.) will
require the completion of an easement in the Distributors’ name, or a “Letter
of Permission “from the property owner(s) involved.
The Customer will provide unimpeded and safe access to the
Distributor at all times for the purpose of installing, removing, maintaining,
operating or changing metering and distribution plant.
Where the high voltage interrupting switches are located inside
a building, a direct outside entrance to the switchgear room must be provided.
The outside door providing direct access to the transformer or
switchgear room must be compliant with all applicable codes and requirements,
and of a quality to be approved by the Distributor.
3.4.8
Metering:
The owner will supply and install provisions for metering
following the details outlined both in these Conditions of Service, and
technical documents provided to the Customer during the consultation process.
For more details refer to
section 2.3.7 in these Conditions of Service.
3.4.9
Sub-transmission Service:
The Owner will pay for the full cost of sub-transmission
services and may in some circumstances be required to construct a private pole
line.
The Distributor will terminate sub-transmission conductors
complete with live line loops and hardware at the Demarcation Point.
3.4.10
Short Circuit Capacity:
The Owner shall ensure that the service entrance equipment has
an adequate short-circuit interrupting capability.
3.4.11
Drawings
Apart from the regular drawings submission to the ESA, the
Customer shall provide two sets of the following drawings and details to the
Distributor.
Survey Plan: prepared
by an Ontario Land Surveyor, showing the property limits, registered plan and
existing buildings or easements if any.
Site Plan: showing
the location of the station relative to buildings, structures and set back from
adjacent property lines. The site plan shall also include the exact location of
existing Distributor owned plant and the proposed route of the incoming supply.
Schematic or Single-Line
Diagram: indicating the major components of the station and their
electrical ratings. Where additions or alterations are being made, these shall
be clearly distinguished from unchanged portions of the installation.
Electrical Details: sufficient
details shall be provided in order to enable fast processing and approval of
the station drawings. The following represents the minimum data required.
·
Plan, elevation and profile views of the station structure,
switchgear, transformer(s), termination poles, duct banks, etc.
·
Dimensions to clearly indicate the electrical, physical and
working clearances as well as relative location of all equipment.
·
Pole or structure for dead-ending the Distributor lines shall be
complete with suitable hardware for attaching the suspension insulators that
will be supplied and installed by the Distributor.
·
Fencing arrangement.
·
Grounding details. (In the case of indoor metal enclosed switchgear,
when the Distributor has operating control of any interrupter switches, the
assembly shall further incorporate ground rod parking stands and stirrups per
the Distributors Specifications.)
·
Details of vault construction (if indoor substation).
·
Manufacturer’s drawings of metal-enclosed switchgear showing
internal arrangement of equipment, clearances, means of access, interlocking
and provision for personal safety. Where the Distributors’ cables terminate in
the switchgear, the Customer shall provide suitable terminators for the size
and type of cable as specified by the Distributor.
·
When the Customer’s switchgear is used for loop feeding the
Distributors’ supply cables, provision for padlocking the in and out load
interrupter switches and the associated bay doors shall be required.
·
Indoor and outdoor switchgear assemblies shall contain a space
heater and protective guard in each bay, along with thermostat(s), sized to
promote air circulation and to prevent condensation from forming.
·
At the discretion of the Distributor, the Customer shall make
provisions for a future system neutral connection to the Customer’s dead-ending
pole or structures installed by the Distributor. Where the Distributors’
neutral terminates in the Customer’s switchgear, the Customer shall provide a
suitable connector on the ground bus for the size and type of cable specified
by the Distributor.
3.4.12
Pre-Service Inspection
The Customer shall present to the Distributor a final
“Pre-service Inspection Report” a minimum of 3 working days before connection
can be affected.
The “Pre-Service Inspection Report” shall outline and document
the results of all tests and inspection carried out on the substation
components. The information contained in the report must be to the satisfaction
of the Distributor before connection can be authorized.
The “Pre-Service Inspection Report” shall be required in case
of:
·
New Substation: in which case all components of the substation
shall be reported upon.
·
Modified substation: in which case all components of the
substation shall be reported upon.
Prior to connection of the service the Distributor requires
notification from the Electrical Safety Authority that the electrical
installation has been inspected and approved for connection.
Provision for metering shall be inspected and approved by the
Distributor prior to connection.
The Distributor or Distributor-approved Contractor generally
installs all services. All work done shall be as per the specifications of the
Distributor and subject to inspection by the Distributor.
(Refer to section 2.1.4
for further inspection details)
3.5
Embedded Generation
3.5.1
General
An Embedded Generator shall provide the Distributor with proof
of compliance of the regulators’ registration requirements, permits and inspections
as required, including ESA and Licences as appropriate.
The Distributor shall collect costs reasonably incurred with
making an offer to connect a generator from the entity requesting the
connection. Costs reasonably incurred include but are not limited to costs
associated with:
·
Preliminary review for connection requirements. (Connection
Impact Assessment)
·
Detailed study to determine connection requirements. (Cost of
Connection)
·
Final proposal to the generator.
·
Connection costs for construction or make ready work for the
distribution system as per the
cost allocation methods in the DSC.
A Generator that is or wishes to become connected to the
Distributors’ distribution system shall enter into a Connection Agreement with
the Distributor as prescribed in Appendix E of the DSC.
A generator shall ensure that a disconnection method suitable to
the Distributor is installed to provide visible isolation of the generation.
If damage or increased operating costs result from a connection
with a Generator, the Generator shall reimburse the Distributor for these
costs.
The Embedded Generator is responsible for providing suitable
protection equipment to protect his plant and equipment for any conditions on
the Distributor and interconnected transmission systems such as reclosing,
faults and voltage unbalance.
To incorporate the connection of embedded generator to the
distribution system, the line/feeder protection including settings and breaker
reclosing circuits must be reviewed and modified if necessary, by the
Distributor or transmission authority. This process may be complex and may
require significant time.
The embedded generator greater than 10 kW must submit a proposed
single line diagram and protection scheme signed and sealed by a Professional
Engineer in the Province of Ontario for review to the Distributor contact as
identified by the Distributor.
Based on the transformer connection proposed by the embedded
generator additional significant protection cost may be incurred (e.g. delta HV
transformer winding may require 3 phase HV breaker / reclosure device). The
embedded generator shall not order the protection equipment and transformer
until the station line diagram is reviewed and accepted by the Distributor.
The purpose of the Distributor review is to establish that the
embedded generator electrical interface design meets the Distributor
requirements.
The protection schemes shall incorporate adequate facilities for
testing/maintenance.
Negative phase sequence protection shall be installed where
required, to detect abnormal system condition as well as to protect the
generator.
The embedded generator may be required to install utility grade
relays for those protections that could affect the Distributor or transmission
authority system.
The embedded generator may be required to submit a Ground
Potential Rise study for review by the Distributor, if telecommunications
circuits are specified for remote transfer trip protection.
Reference: A Customer considering a generation project can find
additional information on the technical and administrative requirements in the
CHEC Generation Guide and Appendix F of the Distribution System Code. A copy of
these documents can be obtained from your local utility upon request.
The generator in addition to the requirements of the host
Distributor may be required to meet the conditions of upstream Distributors.
The additional requirements will be communicated through the host Distributor.
3.5.2
Protection
The embedded generator should provide protection systems to cover
the following conditions:
3.5.2.1
Internal Faults:
The Generator should provide adequate protections to detect and
isolate generator and station faults.
3.5.2.2
External Faults:
The protection system should be designed to provide full feeder
coverage complete with a reliable DC supply. In some cases, redundancy in
protection schemes may be required.
Normally the following fault detection devices are required for
synchronous generator(s) installation(s).
3.5.2.3
Ground Faults:
When the HV winding of the Generator station transformer is wye
connected with the neutral solidly grounded, then ground over-current
protection in the neutral is required to detect ground faults.
If the Embedded generator station transformer HV winding
connected to the Distributor system is ungrounded wye or delta, then ground
under-voltage and ground over-voltage protections shall be required to detect
ground faults.
Depending on the size, type of generator and point of
connection, a Distributor may require the relaying system to be duplicated,
complete with separate auxiliary trip relays and separately fused DC supplies
to ensure reliable protection operation and successful isolation of the
embedded generator.
3.5.2.4
Phase Faults:
To detect phase faults, at least one of the following
protections should be installed with acceptable redundancy where required
depending on fault values:
·
Distance
·
Phase directional over-current
·
Voltage-restrained over-current
·
Over-current
·
Under-voltage
3.5.2.5
Islanding/Abnormal Conditions:
Voltage and frequency protections are required to separate the
embedded generator from the distribution system for an islanded condition and
thus maintain the quality of supply to distribution system Customers. This also
will enable speedy restoration of the distribution system.
Typically, the protections required to detect islanding/abnormal
conditions are:
·
Over-voltage
·
Under-voltage
·
Over-frequency
·
Under-frequency
·
Voltage-balance
The above protections should be timed to allow them to ride
through minor disturbances.
3.5.3
Induction Generator
Due to the operating characteristics of the induction generator
the protection package required is normally less complex than the synchronous
generator. An embedded generator should design the protection scheme to trip
for the same conditions as stated for synchronous generators. An induction
generator is an asynchronous machine that requires an external source such as a
healthy distribution system to produce normal 60 Hz power. Alternatively, if
there is an outage in the distribution system then there is unlikely to be 60
Hz output from the induction generator. In certain instances, an induction
generator may continue to generate electric power after the source is removed.
This phenomenon, known as self-excitation, can occur whenever there is
sufficient capacitance in parallel with the induction generator to provide the
necessary excitation and when the connected load has certain resistive
characteristics.
3.5.4
DC Remote Tripping/Transfer Tripping
Remote or transfer tripping may be required between the
Generator and the feeder circuit breaker if the Generator is connected at a
critical location in the distribution system. This feature will provide for
isolation of the embedded generator when certain faults or system disturbances
are detected at the feeder circuit breaker location.
Additional Protection Features, such as Remote Trip and
Generator end open signal, may be required in some applications. Remote Trip
Protection will often involve the participation of a neighboring or Host
Distributor. Early consultation is important to ensure a timely connection to
the system.
3.5.5
Maintenance
An Embedded Generator shall have a regular scheduled maintenance
plan to assure the Distributor that all connection devices and protection &
control systems are maintained in good working order. These provisions shall be
included in the Connection Agreement. A complete copy of the inspection report
shall be delivered to the Distributor within 30 days.
In developing a maintenance plan, the Generator should consider
the following requirements:
·
Qualified personnel should carry out all inspections and
repairs.
·
Prior to completing any testing or repairs on the system the
Distributor shall be contacted to coordinate the work.
·
Periodic tests should be performed on protection systems to
verify that the system operates as designed. Testing intervals for protection
systems should not exceed four (4) years for microprocessor-based systems and
two (2) years for electro-mechanical based systems.
·
Isolating devices at the point of connection should be operated
at least once per year.
·
The Generator facility should be inspected visually at least
once per year to note obvious maintenance problems such as broken insulators or
other damaged plant.
·
Any deficiencies identified during inspections shall 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 Generator) and financial and material requirements. The Distributor shall
be notified of any deficiencies involving critical protective equipment.
·
The Distributor shall be provided with copies of all relevant
inspection and repair reports that may affect the protection and performance of
the Distributors’ systems. The Distributor has the right to witness any
relevant test being performed by the generator.
·
Testing & inspection requirements specified by the
Distributor.
3.5.6
Post Connection Changes
Any changes to the system after the initial connection will be
communicated to the Distributor prior to implementation.
Where any of these proposed changes alter the protection
associated with the installation the Distributor will be provided with
sufficient information to allow review of the protection scheme and the
potential impacts on the distribution system.
Where the Customer makes changes which result in the need for
additional studies, protection changes or alterations to the distribution
system the Customer will be responsible for the costs incurred by the Distributor
as allowed by the various codes and regulations.
3.5.7
Micro-Embedded Generation
The following are the minimum requirements for Micro-Embedded
Generation. The Distributor may require other information.
A Distributor shall require a person that applies for the
connection of a Micro-Embedded Generation facility to the Distributor’s
distribution system to provide, upon making the application, the following
information:
·
The name-plate rated capacity of each unit of the proposed generation
facility and the total name-plate rated capacity of the proposed generation
facility at the connection point;
·
The fuel type of the proposed generation facility;
·
The type of technology to be used; and
·
The location of the proposed generation facility including the
address and account number
with the Distributor, where available.
Reference: A Customer considering a generation project can find
additional information on the technical and administrative requirements in the
CHEC Generation Guide and Appendix F of the Distribution System Code. A copy of
these documents can be obtained from your local utility upon request.
3.6
Embedded Market Participant
An Embedded Market Participant shall provide the Distributor
with proof of compliance of IESO registration requirements, and appropriate
Licences.
Where the Conditions of Service of this Distributor exceed the
technical requirements of any other licence or participant obligations, these
Conditions of Service shall take precedence.
The Embedded Market Participant must meet at a minimum, the
standards as set out in these Conditions of Service in order to connect to the
Distributors’ distribution facilities.
3.7
Embedded Distributor
An Embedded Distributor shall provide the Distributor with proof
of compliance of IESO and OEB registration Requirements, and appropriate
Licences.
Where the Conditions of Service of this Distributor exceed the
technical requirements of any other licence or participant obligations, these
Conditions of Service shall take precedence.
The Embedded Distributor must meet at a minimum, the standards
as set out in these Conditions of Service in order to connect to the
Distributors’ distribution facilities.
Metering requirements of the Embedded Distributor shall be at
the discretion of the Host Distributor.
3.8
Unmetered Scattered Load (Miscellaneous Small Services)
This section pertains to the supply of electrical energy for
Street Lighting, Traffic Signals, Bus Shelters, Telephone Booths, Cable T.V.
Amplifiers, Decorative Street Lighting, Bill Boards, and other similar small
loads.
These small services may be required to be metered by the
Distributor.
To facilitate these installations the Distributor may have
standard designs which are to be followed by parties requesting the attachment.
In addition, any attachments made to the Distributor’s system
will be required to conform to Ontario Regulation 22/04 and Ontario Electrical
Safety Code. The Distributor will provide direction to the Owner with respect
to any special requirements under Regulation 22/04.
3.8.1
Rights and Responsibilities:
Unmetered Customer
Responsibilities:
·
Comply with the Distributor’s requirements for new connections,
which may require the signing of a formal agreement for
services. Unmetered Customers cannot use power from the Distributor’s
Distribution system without written or implied consent from the Distributor.
·
Comply with the requirements of the Distributor’s standards for
power quality and reliability and the Ontario Electrical Safety Code to ensure
public safety. Where compliance is breached, the unmetered Customer may be
billed for subsequent restoration costs, and/or may be permanently removed from
the Distributor’s electrical system.
·
Retain all information provided to and by the Distributor per
the terms outlined in this Conditions of Service. The Distributor may not
retain record details for each unmetered service and thus will not be held
responsible for any incomplete records.
·
Install, operate, and maintain its secondary conductor from the
Distributor’s designated Supply Point to the intended load.
·
Provide timely and accurate electrical profile, power quality
and usage data to the Distributor as outlined in these Conditions of Service.
Provision of data to the Distributor constitutes consent to the Distributor to
share or release load detail, plus energy and demand data, however, the
Customer’s identity shall remain confidential.
·
Accept energy consumption based on either 1) the maximum
continuous calculated load, or 2) the results of a Distributor’s meter analysis.
·
Allow no external party to connect to its unmetered service or
its unmetered secondary bus.
·
Relocate, at the unmetered Customer’s cost, the secondary
conductors of an unmetered
service to another designated Supply Point at the Distributor’s request.
·
Submit revised unmetered data that affects energy consumption
and/or billing determinants
to the Distributor within 30 days, or as otherwise specified by the
Distributor.
·
Understand that the unmetered connection facility is not
intended for an unmetered Customer to generate back into the Distributor’s
distribution system. If an unmetered Customer has generation facilities, the
connection shall meet the Distributor’s specification(s) for
standby generation.
Unmetered Customer
Responsibilities:
·
Provide a service layout for each unmetered service location
that identifies the Supply Point and prescribes any applicable Distributor’s
standards and conditions.
·
Strive to make new unmetered service connections within 10
working days of having all Distributors’ connection conditions met.
·
Provide reasonable notice to the unmetered Customer should the
Supply Point require relocation:
o Planned Supply Point relocations – 90 day written notice.
o Emergency Supply Point relocations – when possible.
·
Ensure that unmetered service billing information accurately
reflects calculated electrical
consumption by unit, quantity, load profile and demand. Devices of the same
class by type or load, where possible, can be grouped together and assigned the
same billing determinants.
3.8.1
Rights and Responsibilities:
A Distributor will strive to ensure that unmetered service
billing information accurately reflects calculated electrical consumption by
unit, quantity, load profile and demand, based on information supplied by the unmetered
Customer. An unmetered Customer, at its cost, has the following options
available for submitting data:
New Unmetered Services –
Unmetered Customers shall provide the Distributor with electrical profile,
power quality, and usage accuracy studies prior to new unmetered equipment
being introduced to a Distributors electrical system. Acceptable examples for
collecting and providing such data are:
·
An in-house test plan (covering scope, applicability,
conditions, quality control, measurement devices, timing, staff competencies,
control documents, error resolution process, and external references) that
meets the Distributors approval. Final results and report shall be signed and
sealed by a Professional Engineer of Ontario;
·
A signed and sealed certified test report from the Standards
Council of Canada, an ANSI compliant laboratory, or other similarly qualified
laboratory having competencies in electrical equipment testing; or
·
Having the Distributor meter specific unmetered nodes of their
choice to determine accurate data. With the advent of Smart Metering the
metering of actual consumption data is available and preferred by most
Distributors.
Existing Unmetered
Services – Throughout the lifecycle of the unmetered service,
unmetered Customers are required to submit updated and accurate data to the
Distributor when it becomes known by the unmetered Customer or requested by the
Distributor.
At the very least, the unmetered Customer must provide written
notification to the Distributor by January 31st each year that no material
changes to the technical data or number of unmetered service nodes has
occurred.
3.8.3
General Billing Conditions:
An unmetered service is deemed to be “in-service” once it has
been connected and energized by the Distributor. Once energized, the
Distributor will bill the unmetered Customer based on the billing standards
outlined in these Conditions of Service and/or by the Distributors billing
policies.
Where possible, the unmetered Customer shall work with the
Distributor to classify like energy devices such that similar devices can be
consolidated to similar energy usage profiles for energy billing purposes. When
requested by the Distributor, the unmetered Customer shall consolidate their
separate unmetered billing accounts down to at least the number of similar
energy profile classifications. Security deposits, billing, and payment options
are handled as specified in these Conditions of Service and/or by the
Distributor’s billing policies.
Unmetered Customers are responsible for ensuring their
electrical consumption is accurate on an ongoing basis. The Distributor
encourages voluntary data disclosure to ensure data quality and billing
accuracy is maintained. Upon the Distributors receipt of updated unmetered load
data, the Distributor shall have a period of up to 90-days to review and adjust
its billing determinants.
To ensure the quality of unmetered data, the Distributor
encourages the unmetered Customer to cooperate in a joint audit, at a minimum
interval of every 5 years, or earlier upon written notice from the Distributor.
Unmetered Customers who participate in a joint audit will be responsible for
their associated audit costs.
If the unmetered Customer provides the Distributor with poor
unmetered data (i.e.: not to audit standards, no data, late data, etc.) a
unmetered Customer shall be responsible to pay the Distributor for
verification, data correction and usage costs for the duration the unmetered
connection has been energized on the Distributor’s system.
In the event that the Distributor or the unmetered Customer
identify or cause a billing error, the Distributor will rectify the matter
consistent with the polices outlined in these Conditions of Service and/or the
Distributor’s billing policies.
Billing of the energy and fixed charges will continue until the
Distributor has been duly notified and the unmetered service has been
permanently removed from the Distributor’s electrical system.
Failure to comply with any of the above USL requirements could
result in disconnection from the distribution system as per these Conditions of
Service and/or the Distributors Disconnection/Reconnection Policy. Reconnection
to the system would be subject to the reconnection requirements and costs as
outlined in these Conditions of Service and/or the Distributors Disconnection /
Reconnection policy.
3.8.4
Record Retention:
The unmetered Customer shall retain information provided to and
by the Distributor for a minimum period of seven years while the unmetered
service is energized on the Distributors electrical system. Once the service
has been permanently removed, the retention period shall be a minimum of two
years.
The retained information shall include yet, not be limited to,
the information outlined above, and any other relevant correspondence or
agreements regarding the unmetered account including the associated service
connections and load.
The unmetered Customer who fails to retain such records shall be
responsible for costs related to the Distributor researching and reconstructing
such missing information.
3.8.5
General
At the discretion of the Distributor, the service voltage will
be:
·
120/240 volts, single phase three wire or
·
120 volts, single phase two wire or
·
120/208 volts, three phase, four wire
·
347/600V three phase, four wire
The method and location of the supply will vary based on the
conditions present on the Distributors’ plant and will be established for each
application through consultation with the Distributor.
Where specified by the Distributor during the Early Consultation
process, the Customer will provide underground ducts to the Distributor’s
specifications.
The Owner shall be responsible for all costs associated with the
supply and installation of service conductors.
The Distributor will install required transformation and may charge
the Owner the cost.
Prior to energization of a service the Distributor will require
notification from the ESA that the installation has been inspected and approved
for connection.
The Owner will be required to maintain any equipment in proper
and safe working order. Where the equipment is found to be in disrepair or
present a hazard the Distributor may disconnect, remove and charge the costs to
the owner.
3.8.6
Early Consultation
The Owner shall supply a completed Electrical Planning
Requirements Form to the Distributor well in advance of installation
commencement to allow the Distributor time for proper planning, ordering of
equipment etc. Information required includes:
·
Required in-service date
·
Requested Service Entrance Capacity and voltage rating of the
service entrance equipment
·
Locations of other services, gas, telephone, water and cable TV
·
Survey plan and site plan indicating the proposed location of
the service equipment with
respect to public rights-of way and lot lines.
The Distributor after reviewing the information provided may
require the owner to provide further information or approved drawings signed by
a Professional Engineer ensuring that the installation is consistent with the
requirements of Regulation 22/04.
3.8.7
Street Lighting
Where the street lighting is installed, owned and maintained by
the Municipality or a third party, a Joint Use Agreement may be required for
attachment to the Distribution system. Installations shall meet Ontario
Regulation 22/04 and Ontario Electrical Safety Code.
The owner will be required to ensure qualified personnel are
engaged to work on the streetlight system and that the system is maintained in
a manner as to not represent a hazard to the distribution system and the
public.
Proper records of the street light system shall be maintained by
the owner to facilitate identification of equipment, appropriate record
management and the ability to locate any underground plant associated with the
system.
3.8.8
Traffic Signals
Traffic Signals and Crosswalk Lights are owned and maintained by
the applicable road authority. Any traffic signals and crosswalk lights, if
attached to the distribution system will be required to be in compliance with
Regulation 22/04.
3.8.9
Bus Shelters
Bus Shelter Lighting is owned and maintained by the Customer.
3.8.10
Decorative Street Lighting
Such installations could be lighting for festive occasions or
“neighbourhood character” street-scaping and will be maintained by the
Customer.
Where such lighting represents a barrier to distribution system
maintenance the Distributor may remove to facilitate work on the system in a
safe manner. The owner will be responsible for reinstalling any equipment
removed by the Distributor.
3.9
Attachments to Distribution Plant
The Distributor reserves the right to refuse any attachment to
the Distribution Plant.
Customer attachments require written consent of the Distributor.
Generally, consent will only be provided to licensed franchisees such as Bell
Canada, Rogers Cable, and registered Telecom Companies. The Distributor
reserves the right to refuse attachments to its poles.
Pole attachments will require a signed contract between the
Distributor and the Customer. Each pole attachment is subject to a yearly joint
use charge and installation must conform to Regulation 22/04. Requesting
parties will be responsible for meeting the requirements of Regulation 22/04
and the associated costs. No Customer owned wires or apparatus are to be
installed on the Distributor’s poles prior to entering into a contract and
confirming that the installation meets the requirements.
Where make ready work is required to accommodate the requested
attachment the requesting party will be responsible for all costs associated
with the make ready work.
Any attachments not approved will be removed by the Distributor
at the owner’s expense.
To meet engineering, safety, congestion and aesthetic
considerations only three locations are generally allowed for the attachment of
support strands and communications cables in the communication space of the
Distributor’s poles. Each Customer requesting attachment in the communication
space is allowed to install one support or communications cable only and this
applies to all its associates as defined by the Ontario Business Corporation
Act.
The owner of any third-party plant shall be responsible to
maintain their plant in a safe and proper condition compliant with Regulation
22/04 and relevant standards including any specific Distributor Standards.
The owner of any third-party plant will be responsible for
transfers of their plant in a timely manner as required by the Distributor.
3.9.1
Miscellaneous Attachments
Owners of miscellaneous equipment wishing to attach to the
Distributor’s system shall make written application for review and where appropriate
approval by the Distributor.
Failure to obtain written authorization from the Distributor and
or to enter into a Joint Use Agreement will result in the removal of the
equipment and any associated plant by the Distributor at the owner’s expense.
3.9.2
Joint Use Agreements
This section pertains to owners of plant who wish to make
attachments to the Distribution System which have a direct or indirect
influence on the performance, appearance and safety of the support structure or
the Distributor’s ability to make access and maintain it. For greater clarity
this section applies to companies such as communication companies, CATV
companies, and municipalities, but may be extended to others interested in
making attachments.
All construction, installation and maintenance of attachments by
the third party will conform to Ontario Regulation 22/04 and follow the
appropriate guidelines. The requirements of Regulation 22/04 provide direction
on design, material standards, construction and verification of the installations.
To facilitate good construction and project planning and
compliance with Regulation 22/04 any party requesting to make an attachment
shall contact the Distributor in writing well in advance of the proposed
installation date.
Prior to making any attachments the owner of the plant will be
required to enter into a Joint Use Agreement with the Distributor or if a Joint
Use Agreement has been previously entered into, to follow the process for new
attachments or modifications to existing attachments as specified in the Joint
Use Agreement.
The owner of any third-party plant shall be responsible to
maintain their plant in a safe and proper condition compliant with Regulation
22/04 and the conditions of the Joint Use Agreement.
SECTION
4 GLOSSARY OF TERMS
“Basic Connection” means
a new residential 100A overhead, single-phase, secondary service including
transformation capacity, standard metering, 30 meters of overhead conductor;
“Board” means
the “Ontario Energy Board” (OEB);
“Bulk Meter” means
a revenue class Measurement Canada approved meter and/or installation that is
used as a single point of measurement which the Distributor uses to bill the
Customer’s energy account for a Premise. A Bulk Meter is not a Customer-owned
revenue meter or a meter which is owned and operated by a licensed Sub-Metering
provider;
“Conditions of Service” means
the document developed by the Distributor in accordance with subsection 2.3 of
the Distribution System Code, that describes the operating practices and
connection rules for the Distributor;
“Condominiums” are
located on common land, which is the property of a condominium corporation or
is owned by the Owner of all of the units (rental property). These units
usually front onto internal roads that are also privately owned;
“Condominium Development” is
a structure or complex of structures each containing more than two residential
units. A single residential Customer would occupy each unit and have direct
outside access at ground level;
“Connection” means
the process of installing and activating connection assets in order to
distribute electricity;
“Connection Agreement” means
an agreement entered into between a Distributor and a person connected to its
distribution system that delineates the conditions of the connection and
delivery of electricity to or from that connection;
“Connection assets” means
that portion of the distribution system used to connect a Customer to the
existing main distribution system, and consists of the assets between the point
of connection on a Distributors’ main distribution system and the ownership
Demarcation Point with that Customer;
“Connection Impact
Assessment” (CIA) is an analysis of an Energy Resource Facility’s
impact to the Grid, outlining project feasibility, initial technical
specifications, and the effect the project would have on the Grid. The CIA may
be preliminary or detailed providing different level of information, options,
and responsibilities. Any Customer changes to its information used for the CIA
will require an application for a CIA revision;
“Consumer” means
a person who uses, for the person’s own consumption, electricity that the
person did not generate;
“Customer” means
a person that has contracted for or intends to contract for connection of a
building or an embedded generation facility. This includes developers of
residential or commercial sub-divisions;
“Demand” means
the average value of power measured over a specified interval of time, usually
expressed in kilowatts (kW). Typical Demand intervals are 15, 30 and 60
minutes;
“Demand meter” means
a meter that measures a consumer’s peak usage during a specified period of
time;
“Demarcation Point” means
the point at which the obligation of the Distributor ends and those of the
Customer begin for the purposes of maintenance and repair of the distribution
service;
“Disconnection” means
a deactivation of connection assets, which results in cessation of distribution
services to a consumer;
“Distribute”, with
respect to electricity, means to convey electricity at voltages of 50 kilovolts
or less;
“Distributed Generation” means
any type of electrical generator or static inverter producing alternating
current that has the capability of Parallel Operation with the Distributor
distribution system or is designed to operate separately from the Distributor
system and can supply a load that can also be fed by the Distributor system.
“Distribution losses” means
energy losses that result from the interaction of intrinsic characteristics of
the distribution network such as electrical resistance with network voltages
and current flows;
“Distribution loss
factor” means a factor(s) by which metered loads must be
multiplied such that when summed equal the total measured load at the supply
point(s) to the distribution system.;
“Distribution services” means
services related to the distribution of electricity and the services the Board
has required Distributors to carry out.
“Distribution system” means
a system for distributing electricity, and includes any structures, equipment
or other things used for that purpose. A distribution system is comprised of
the main system capable of distributing electricity to many Customers and the
connection assets used to connect a Customer to the main distribution system;
“Distribution System
Code” means the code, approved by the Board, and in effect at
the relevant time, which, among other things, establishes the obligations of a
Distributor with respect to the services and terms of service to be offered to
Customers and retailers and provides minimum technical operating standards of
distribution systems;
“Distributor” means
a person who owns or operates a distribution system;
“Economic Evaluation” refers
to the evaluation used to determine the net servicing cost based on the
distributor’s standards for the Customer to which this applies;
“Electricity Act” means
the Electricity Act, 1998, S.O. 1998, c.15, Schedule A; “Energy Competition
Act” means the Energy Competition Act, 1998, S.O. 1998, c. 15;
“Electrical Safety
Authority” or “ESA” means the person or body designated under the
Electricity Act regulations as the Electrical Safety Authority;
“Embedded Distributor” means
a Distributor who is not a wholesale market participant and that is provided
electricity by a host Distributor;
“Embedded Generation
Facility” means a generator whose generation facility is not
directly connected to the IESO-controlled grid but instead is connected to a
distribution system;
“Embedded Load
Displacement Generation Facility” means an embedded
generation facility connected to the Customer side of the revenue meter where
the generation facility does not inject electricity into the distribution
system for the purpose of sale;
“Embedded Market
Participant” means 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;
“Emergency” means
any abnormal system condition that requires remedial action to prevent or limit
loss of a distribution system or supply of electricity, or that could adversely
affect the reliability of the electricity system;
“Emergency backup
generation facility” means a generation facility that has a transfer switch
that isolates it from a distribution system;
“Enhancement” means
a modification to an existing distribution system that is made for purposes of
improving system operating characteristics such as reliability or power quality
or for relieving system capacity constraints resulting, for example, from
general load growth;
“Expansion” means
an addition to a distribution system in response to a request for additional
Customer connections that otherwise could not be made; for example, by
increasing the length of the distribution system;
“Four-quadrant Interval
Meter” means an interval meter that records power injected into a
distribution system and the amount of electricity consumed by the Customer;
“Generate”, with
respect to electricity, means to produce electricity or provide ancillary
services, other than ancillary services provided by a transmitter or
Distributor through the operation of a transmission or distribution system;
“Generation Facility” means
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” means
a person who owns or operates a generation facility;
“Good Utility Practice” means
any of the practices, methods and acts engaged in or approved by a significant
portion of the electric utility industry in North America during the relevant
time period, or any of the practices, methods and acts which, in the exercise
of reasonable judgment in light of the facts known at the time the decision was
made, could have been expected to accomplish the desired result at a reasonable
cost consistent with good practices, reliability, safety and expedition. Good
utility practice is not intended to be limited to the optimum practice, method,
or act to the exclusion of all others, but rather to be acceptable practices,
methods, or acts generally accepted in North America;
“Holiday” means
a Saturday, Sunday, statutory holiday, or any day as defined in the Province of
Ontario as a legal holiday;
“Host Distributor” means
the Distributor who provides electricity to an Embedded Distributor; “IESO”
means the Independent Electricity System Operator established under the
Electricity Act;
“IESO-Controlled Grid” means
the transmission systems with respect to which, pursuant to agreements, the
IESO has authority to direct operation;
“Interval meter” means
a meter that measures and records electricity use on an hourly or sub- hourly
basis;
“Large Embedded
Generation Facility” means an embedded generation facility with a name-plate
rated capacity of 10MW or more;
“Lies Along” means
a property can be connected to the Distributor distribution system without an
expansion or enhancement, and meets the conditions listed in the Conditions of
Service of the Distributor who owns or operates the distribution line.
“Load” means
any device (i.e., equipment, apparatus) or collection of devices that rely on
electricity to function;
“Market Rules” means
the rules made under section 32 of the Electricity Act;
“Measurement Canada” means
the Special Operating Agency established in August 1996 by the Electricity and
Gas Inspection Act, 1980-81-82-83, c. 87, and Electricity and Gas Inspection
Regulations (SOR/86-131);
“Medium Sized Embedded
Generation Facility” means an embedded generation facility with a name-plate
rated capacity of less than 10 MW and:
·
a) more than 500 kW in the case of a facility connected to a
less than 15kV line;
·
b) more than 1 MW in the case of a facility connected to a 15 kV
or greater line;
“Meter Service Provider” means
any entity that performs metering services on behalf of a Distributor,
generator, or registered market participant;
“Meter Installation” means
the meter and, if so equipped, the instrument transformers, wiring, test links,
fuses, lamps, loss of potential alarms, meters, data recorders,
telecommunication equipment and spin-off data facilities installed to measure
power past a meter point, provide remote access to the metered data and monitor
the condition of the installed equipment;
“Metering Services” means
installation, testing, reading and maintenance of meters;
“Micro Embedded Load
Displacement Generation Facility” means an embedded
load displacement generation facility with a name-plate rated capacity of 10 kW
or less;
“Net Metering” means
a settlement process for Embedded Generation behind a Load Customer meter as
defined by Ontario Regulation 541/05
“Offer to Connect” means
the Distributor’s specific requirements for a Customer to connect to their
Distribution System;
“Ontario Electrical
Safety Code” means the code adopted by O. Reg. 164/99 as the Electrical
Safety Code;
“Ontario Energy Board
Act” means the Ontario Energy Board Act, 1998, S.O. 1998, c.15,
Schedule B;
“Operational Demarcation
Point” means the physical location at which a Distributors’
responsibility for operational control of distribution equipment including
connection assets ends at the Customer;
“Ownership Demarcation
Point” means the physical location at which a Distributors’ ownership
of distribution equipment including connection assets ends at the Customer;
“Point of Supply” with
respect to an embedded generation facility, means the connection point where
electricity produced by the generation facility is injected into a distribution
system;
“Rate” means
any rate, charge or other consideration, and includes a penalty for late
payment;
“Rate Handbook” means
the document approved by the Board that outlines the regulatory mechanisms that
will be applied in the setting of Distributor rates;
“Reconnection” means
reactivation of Connection assets and results in the Customer’s ability to use
their electrical Service;
“Regulations” means
the regulations made under the Act or the Electricity Act;
“Regulation 22/04” Electrical
Distribution Safety: means the regulation made under the Electricity Act
establishes objective based electrical safety requirements for the design,
construction, and maintenance of electrical distribution systems owned by
licensed Distributors.
“Retail”, with
respect to electricity means,
·
a) To sell or offer to sell electricity to a consumer
·
b) To act as agent or broker for a retailer with respect to the
sale or offering for sale of
electricity, or
·
c) To act or offer to act as an agent or broker for a consumer
with respect to the sale or offering
for sale of electricity.
“Retail Settlement Code” means
the code approved by the Board and in effect at the relevant time, which, among
other things, establishes a Distributors’ obligations and responsibilities
associated with financial settlement among retailers and Customers and provides
for tracking and facilitating Customer transfers among competitive retailers;
“Retailer” means
a person who retails electricity;
“Service” means
the conductor and equipment for transferring electrical Energy between the
Distributor’s Distribution System and the Customer’s premise;
“Service Area” with
respect to a Distributor, means the area in which the Distributor is authorized
by its licence to distribute electricity;
“Small Embedded Generation
Facility” means an embedded generation facility which is not a
micro-embedded 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;
“Smart Meter” means
a device that measures electrical energy use (kilowatt-hours, kWh) on an hourly
or sub-hourly basis and is part of an integrated data management system. The
meter records, stores and transmits date and time-stamped meter readings to a
utility’s computer to facilitate Time- of-Use and Hourly billing. Smart meters
may also include other capabilities and features to aid in load management and
energy conservation.
“Standard Offer” means
a settlement process for distribution connected Embedded Generation under
contract for supply with the IESO.
“Sub-metering” or “Unit
Sub-metering” shall have the meaning ascribed to it in Part II of the
Energy Consumer Protection Act, 2010, S.O. 2010, c.8;
“Total losses” means
the sum of distribution losses and unaccounted for energy;
“Townhouses” are
usually a free hold property, the land is owned by the individual Owners of
each unit, fronting onto a municipal street;
“Townhouse Development” is
a structure or complex of structures each containing more than two residential
units. A single residential Customer would occupy each unit, and have direct
outside access at ground level;
“Transmission System” means
a system for transmitting electricity, and includes any structures, equipment
or other things used for that purpose;
“Transmission System
Code” means the Board approved code that is in force at the
relevant time, which regulates the financial and information obligations of the
Transmitter with respect to its relationship with Customers, as well as
establishing the standards for connection of Customers to, and expansion of a
transmission system;
“Transmit” with
respect to electricity, means to convey electricity at voltages of more than 50
kilovolts;
“Transmitter” means
a person who owns or operates a transmission system;
“Unmetered Scattered
Load” means electricity consumption that is not metered and is
billed based
on estimated usage and its Load profile if it can be determined.
“Unaccounted-for Energy” means
all energy losses that cannot be attributed to distribution losses. These
include measurement error, errors in estimates of distribution losses and
un-metered loads, energy theft and non-attributable billing errors;
“Un-metered loads” means
electricity consumption that is not metered and is billed based on estimated
usage;
“Validating, Estimating
and Editing (VEE)” means the process used to validate, estimate and edit raw
metering data to produce final metering data or to replicate missing metering
data for settlement purposes;
“Wholesale Market
Participant” means a person that sells or purchases electricity or
ancillary services through the IESO-administered markets;
SECTION
5 APPENDICIES
Please note the following appendices:
· Policies Relevant to the Conditions of Service
· Contact Information
· Distribution Connection Process
· Request for Connection Form
· Electrical Planning Requirements Document
· Electric Service Meter Base/ Service Verification Form
POLICIES
Relevant to Conditions of Service:
The following CHEC standard policies provide additional
information on a Distributor’s processes. Please contact your Distributor to
obtain the most recent copy of the policy:
·
Policy 2.01 – Security Deposit
·
Policy 2.02 – Billing and Payment
·
Policy 2.04 – Eligible Low-Income Customer
·
Policy 2.05 – Opening and Closing of Accounts
·
Policy 2.06 – Collection
·
Policy 2.08 – Disconnection/Reconnection
·
Policy 2.10 – Customer Complaint Process
Please Note: The above policies are CHEC standard policies. A
Distributor’s Conditions of Service and/or a Distributor’s policies may
supersede the CHEC standard policies.
CHEC
Distributor Information:
For a complete and
current list of CHEC members, please see the members map located on the CHEC
Website at https://checenergy.ca/members/
[Chart – Distribution Connection]
Distribution
Connection Developments & General Service Customers
If you are planning on building a Subdivision, Commercial
Building, or an Industrial Development, the process of connecting to the Local
Distribution Infrastructure will require coordination with the Distributor.
The following information in conjunction with the preceding
chart is designed to assist the parties in meeting their respective obligations
and facilitate the required connection. It is important to note although the
steps identified in both the chart and the following descriptions need to be
followed in proper order, some of the steps may be combined to help speed up
the process if all the required information is provided in a timely manner.
Step
1 – Request for Connection
Customer submits a connection request to the Distributor.
Initial request should at a minimum include the following information:
·
a) Location of proposed development
·
b) General description of development
·
c) Proposed construction date
·
d) Contact information for Development
Step
2 – Initial Meeting
Customer and Distributor meet to review proposed new development
and connection requirements. Initial meeting will provide both parties with an
opportunity to gain a better understanding of the proposed development and
identify any issues related to timing and connection to the Distribution
System.
Based on the information provided by the Customer prior to the
meeting, the Distributor will be able to provide at a high level:
a) An initial concept of the type of work that may be required
to facilitate a connection. ie:
·
a. Extension of an existing Feeder
·
b. Potential requirement for a new DS
·
c. Add a second or third phase to an existing feeder
b) An understanding of the of the Customer responsibilities
c) An understanding of what must be managed by the Distributor
d) An understanding of what may be contracted by the Customer
e) An estimated timeline required to provide connection facilities
f) An initial estimate of required expansion costs – note: more detailed
estimates on costs will be provided with the Offer to Connect should the
Customer choose to continue to Step 4.
Step
3 – Customer Decision
Based on the results of the initial meeting, the Customer
decides on proceeding with the process or withdrawing their Request for
Connection.
Step
4 – Customer Provides Required Information
If the Customer decides to proceed with the process for
acquiring a connection, the Customer notifies the Distributor and provides the
relevant detailed information as noted below:
a) A statement noting if the Customer intends on managing the
contestable work noted during the consultation
b) Number of Residential Connections
c) Residential – Type, Number, and size of units
d) Number of Commercial / Industrial Connections
e) Estimated Average Monthly consumption (at minimum winter & summer
estimates)
f) Estimated annual facility connections over five years from date of
Distributor system connection
The following information is also required however the
Distributor reserves the right to perform the work internally or through an
external consultant:
a) Design and engineering specifications including but not
limited to stamped site service drawings
b) Determination of required Transformation based on estimated building loads
c) Estimated Capital costs of facilities which would be assumed by the
Distributor following energization
To assist the Customer in providing the required information, a
submission summary sheet is provided as an attachment to this document.
Step
5 –Initial Economic Evaluation
Upon receipt of the required information from the Customer, if
an expansion of the distribution system is required, the Distributor will
perform an Initial Economic Evaluation following the process as required in the
Distribution System Code.
The Initial Economic Evaluation will assist the Distributor in
calculating what (if any) portion of the Capital Costs the Distributor will
invest and will be used in the preparation of the Offer to Connect.
Step
6 – Offer to Connect
Using the information provided by the Customer, and following
the completion of the Preliminary Economic Evaluation, the Distributor will
prepare an “Offer to Connect”. The Offer to Connect will contain the following
information:
a) A statement as to whether the offer is a firm offer or an
estimate to be revised after the actual costs are known
b) The estimated amount of Capital Contribution that will be required from the
Customer
c) The estimated amount of the Expansion Deposit that will be required from the
Customer
d) A description of the costs related to the Capital Contribution
e) The costs for inspections
f) A description of the deliverables required from the Customer before Connection
g) An estimated Connection Date
Step
7 – Customer Decision
Customer Reviews Offer to Connect and decides if they would like
to continue with the project as planned. Three options are available to the
Customer:
a) Customer elects to drop the project, a notice of withdrawal
of the Request for Connection shall be provided to the Distributor.
b) Customer would like to revise their Connection request, a notice informing
the Distributor of the requested changes shall be provided to the Distributor
(go back to Step 4)
c) Customer agrees with the Offer to Connect,
Step
8 – Construction Agreement
Once the Customer accepts the Distributor’s Offer to Connect,
the parties shall enter into an agreement covering the construction and
connection requirements and responsibilities.
The Customer and the Distributor sign the agreement and the Customer provides
the financial deposits and/or guarantees as required.
Step
9 – Construction
Following receipt of signed Construction Agreement and required
financial deposits and/or guarantees from the Customer, both parties shall
begin ordering materials and begin construction.
Step
10 – Connection Authorization
Once construction is completed, both parties will ensure that
inspections are completed, and all required connection authorizations are in
place. After receipt of a signed connection agreement and any additional
financial contributions, the Distributor will authorize and connect the
facility. If the Customer is coordinating the work on the expansion facilities within
the development, the Customer is also required to provide “As-Built” drawings
and a detailed material listing to ensure the Distributor has sufficient
information in hand to verify system security prior to energization.
Step
11 – Exchange Updated Information
The Customer and the Distributor shall exchange any required
updated information on the project including, but not limited to:
h) All applicable Connection Authorizations
i) All applicable Warranties
j) Any new information that was provided as an estimate in Step 4
k) Actual costs of any “capital works” related to the expansion facilities
within the development l) Detailed site plan with appropriate Municipal Address
information for individual services
Step
12 –Final Economic Evaluation
As required, the Distributor shall copy the Initial Economic
Evaluation to a new file, to be known as the Final Economic Evaluation. The
Final Economic Evaluation shall be updated using actual information acquired
during and following the construction process. This Final Economic Evaluation
shall determine the capital contribution required to transfer the assets to the
Distributor.
Step
13 – Annual Economic Evaluation Update
If the development includes estimated connections that are not
energized at the time of the initial Connection, the Distributor shall re-run
the Economic Evaluation on an annual basis using actual Customer connection
information during the five (5) year connection horizon used in the initial
Economic Evaluation. The Distributor will annually return the percentage of the
expansion deposit in proportion to the actual connections that materialized in
each year. The Distributor shall be permitted to retain the remaining portion
of the expansion deposit for any forecasted connections that have not materialized
during the five (5) year connection horizon.
If a third-party (not the Distributor – see Step 4 above)
competed the majority of the work, the Distributor shall retain at least ten
(10) percent of the expansion deposit for a warranty period of at least two
years. This portion of the expansion deposit can be applied to any work
required to repair the expansion facilities within the two-year warranty
period. The two-year warranty period begins:
·
(a) when the last forecasted connection in the expansion project
materializes (for residential developments) or the last forecasted demand
materializes (for commercial and industrial developments); or
·
(b) at the end of the five-year customer connection horizon,
whichever is first. The distributor shall return any remaining
portion of this part of the expansion deposit at the end of the two-year
warranty period.
[Request for Connection –
Sample Form]