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For Hydro Ottawa Use Only © 2016 ECG0016 R0 Page 1 of 33 TITLE: Working Procedure RECOMMENDED: S. Evelyn NO: REV: APPROVED: C. Malone P. Eng. ECG0016 0 REV. DATE: 2016-03-04 Energy Resource Facility (ERF) Process Guideline

Transcript of TITLE: Working Procedure - Hydro Ottawa · 2017-10-05 · or greater. This process guide does not...

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For Hydro Ottawa Use Only © 2016 ECG0016 R0 Page 1 of 33

TITLE:

Working Procedure

RECOMMENDED: S. Evelyn NO: REV:

APPROVED: C. Malone P. Eng. ECG0016 0 REV. DATE: 2016-03-04

Energy Resource Facility (ERF) Process Guideline

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REVISION SHEET

Revision Description of Change Date Initial

0 Original Document 2016-03-04 se/csm

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TABLE OF CONTENTS PAGE

1.0 Introduction ...................................................................................................... 4

2.0 References ......................................................................................................... 4 3.0 Scope .................................................................................................................. 6 4.0 Definitions, Abbreviations, and Acronyms .................................................... 6 5.0 Project Process .................................................................................................. 9

5.1 Initial Consultation ............................................................................................. 9 5.2 Formally Submitting CIA Applications (Form B) ........................................... 11

5.3 Project Setup ..................................................................................................... 12 5.4 Distribution Connection Impact Assessment (DCIA) ...................................... 12 5.5 Kick-Off Meeting ............................................................................................. 13

5.6 Offer-to-Connect .............................................................................................. 14 5.7 Letter of Equivalency ....................................................................................... 15 5.8 Isolation/Reconnection ..................................................................................... 15

5.9 Metering Installation ........................................................................................ 16 5.9.1 Information for GIS .......................................................................................... 16

5.10 Electrical Operating and Maintenance Agreement .......................................... 17 5.11 Requesting Commissioning .............................................................................. 18 5.12 Commissioning ................................................................................................. 18

5.13 Confirmation of Settlement .............................................................................. 19 5.14 Project Close Out .............................................................................................. 20

6.0 Planning and Legislative Considerations ..................................................... 22 6.1 Conditions of Service – Premise Upgrade ....................................................... 22

6.2 Analysis of CIA Application ............................................................................ 22 6.4 FIT Milestone Tracking .................................................................................... 24

6.5 Timelines .......................................................................................................... 24

7.0 Design Criteria ................................................................................................ 25 7.1 ERF Metering ................................................................................................... 25

7.2 Monitoring and Control Box ............................................................................ 26 7.3 Loss-of-Phase Protection .................................................................................. 26

7.4 Single Line Diagram ........................................................................................ 27 7.5 Site Plan and Equipment Layout Diagrams ..................................................... 27

7.6 Protection Schema Document .......................................................................... 28

Appendix A: PROCESS FLOW CHART ........................................................................... 30

Schedule 1: FIT MILESTONE TRACKING SHEET ....................................................... 33

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1.0 Introduction

This document outlines the detailed process guideline for the connection of Provincial FIT

Energy Resource Facility (ERF) projects. With minor process exemptions or exceptions

described herein, this guide can also be applied for processing Net-Metering, Load Displacement

or Stand-Alone ERFs. This process guideline is intended for use by internal personnel at Hydro

Ottawa Limited (HOL). It is not meant to be a technical guideline, but rather a process guide

that can be applied at any stage of the FIT project’s lifecycle. This guideline is for Capacity

Allocation Exempt (CAE) FIT Generation, as defined by the Ontario Energy Board (latest

revision) as: generation less than 250kW for less than 15kV and 500kV for connections at 15kV

or greater. This process guide does not incorporate microFIT or microNET Generation (less than

10kW).

2.0 References

Hydro Ottawa – DFS0002 – Electrical As-Built Construction Drawings.

Hydro Ottawa – ECG0005 – Commercial Primary Service Electrical Ownership

Demarcation Customer Owned Transformer.

Hydro Ottawa – ECG0006 – Embedded Generation Connection Guideline.

Hydro Ottawa – ECG0008 – Distribution System Voltage and Power Quality.

Hydro Ottawa – ECG0009 – Commercial Primary Service Electrical Ownership

Demarcation Hydro Ottawa Owned Transformer.

Hydro Ottawa – ECG0015 – Distributed Generation Secondary Commercial Service

≤500kW Single Phase and Three Phase – Single Line Detail.

Hydro Ottawa – ECS0012 – Hydro Ottawa Limited Conditions of Service.

Hydro Ottawa – ECS0038 – Distributed Generation Modelling Using CYME – Tutorial.

Hydro Ottawa – ECS0039 – Site Specific Loss Adjustment for Typical Customer Loads and

Energy Resource Facilities.

Hydro Ottawa – GAP0006 – Paper & Lan Folder Layout for Distribution Asset Management

Projects.

Hydro Ottawa – GCS0008 – Metering Specification.

Hydro Ottawa– GDG0010 – Project Coach.

Hydro Ottawa – MCS0057 – Distributed Generation Secondary Commercial Service

≤500kW, <200A Single Phase and Three Phase.

Hydro Ottawa – MCS0058 – Distributed Generation Secondary Commercial Services

≤500kW Single Phase and Three Phase – Construction Detail.

Hydro Ottawa – MCS0063 – Distributed Generation Secondary Service ≤500kW Single or

Three Phase Multiple Services – Construction Detail.

Hydro Ottawa – MCS0064 – Distributed Generation Secondary Service ≤500kW, Single or

Three Phase Meter Centre – Construction Detail.

Hydro Ottawa – MCS0075 – Distribution Generation Outdoor Metering Secondary

Equipment Installation ≤200A – Construction Detail.

Hydro Ottawa – MCS0076 – Distribution Generation Outdoor Metering Secondary

Equipment Installation 400A and 600A – Construction Detail.

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Hydro Ottawa – MCS0079 – Distribution Generation, 3-Phase, 4-Wire, 400A – 600A,

Secondary Service Meter Wiring – Construction Detail.

Hydro Ottawa – MCS0083 – Distributed Generation, Secondary Residential Service, 1-

Phase, <=200A, Load-Displacement Using Net-Metering –

Construction Detail

Hydro Ottawa – MCS0084 – Distributed Generation, Secondary Service, 1-PH, 400A, Load

Displacement Using Net-Metering & Ganged Meter Trough –

Construction Detail

Hydro Ottawa – MCS0085 – Distributed Generation, Transformer Rated Secondary Service,

1-Phase, 400A, Load Displacement Using Net-Metering –

Construction Detail

Hydro Ottawa – MCS0086 – Distributed Generation, Secondary Service, 1-PH, 400A or

600A, Displacement Using Net-Metering & Splitter Trough –

Construction Detail

Hydro Ottawa – MCS0088 – Upgrade – Existing 120V/240V 1-PH, 3-Wire, 400A

Residential Service To Combination Base Load Displacement

Using Net Metering – Construction Detail

Hydro Ottawa– MCS0102 – Placement of Warning Lamacoids and Stickers for DG or ERF

Installation.

Hydro Ottawa – NPS0001 -- Identification of Electrical Distribution Equipment & Street

Lighting, Work Procedure

Hydro Ottawa – Oracle Metering Portal http://192.168.30.16:9000/workspace/index.jsp

Hydro One Network Inc. LDC Generation –

http://www.hydroone.com/IndustrialLDCs/Pages/LDCGeneration.aspx

Hydro One Network Inc. Operating Maps

https://www.services.hydroone.com/operating/nodsUI/LoginTe

mplate.htm

Hydro One Network Inc. Station Capacity Calculator

http://www.hydroone.com/Generators/Pages/StationCapacityC

alculator.aspx

Institute of Electrical and Electronics Engineers (IEEE) – Standard 1547 – Standard for

Interconnecting Distributed Resources with Electrical Power

Systems.

National Electrical Manufacturers Association (NEMA) – 250-2003: Enclosures.

Ontario Green Energy Act.

Ontario Electrical Safety Code (OESC).

Ontario Energy Board – Distribution System Code.

Ontario – Regulation 22/04 – Electrical Distribution Safety.

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3.0 Scope

This process guide is to identify all the stages and requirements necessary to successfully

complete a FIT project from start to finish. This document is intended to aid Hydro Ottawa

Limited (HOL) personnel in the FIT project process, by isolating each stage of the project and

outlining all individual documentation required for each step. This document summarizes all

required information that should be provided by the Generator and all necessary steps for HOL

personnel to complete a FIT project. This Process Guide should be used in conjunction with the

FIT Process Flow Chart found on the Intranet, see Appendix A.

4.0 Definitions, Abbreviations, and Acronyms

“Abnormal Grid Conditions” means where the Grid is not operating under normal circumstances

with respect to configuration of supply, voltage levels, or faults

“Alternate Feeder” means there is another feeder, aside from the “normal service feeder”

supplying the Premise, usually used as back-up, but not by a customer auto-transfer schedule

“As-Built” as defined in DFS0002

“Bi-Directional Meter” as defined in GCS0008

“BU” means Business Unit

“Blue Package” means the HOL crew’s information work package defined in GDG0010

“CAE” means Capacity Allocation Exempt as defined in the Distribution System Code

“CIA” means ‘Connection Impact Assessment’ (Also referred to as “DCIA” meaning

‘Distribution Connection Impact Assessment’)

“Conditions of Service” (CoS) means Hydro Ottawa’s Conditions of Service

“Control Authority” as defined in the Conditions of Service

“CYMEDIST” (CYME) is a model and simulation software used across the industry to analyze

power systems

“DCIA” means ‘Distribution Connection Impact Assessment’

“DG Source Disconnect” as defined in GCS0008

“DG System Fused Disconnect” as defined in GCS0008

“Distributed Generator” (DG) as defined in Conditions of Service

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“Distribution System Code” (DSC) as defined in the Conditions of Service

“Electrical Safety Authority” (ESA) as defined in the Conditions of Service

“Embedded Generation Facility” as defined in the Conditions of Service

“Embedded Generation” as defined in the Conditions of Service

“Emergency” as defined in the Conditions of Service

“EOMA” means ‘Electrical Operation and Maintenance Agreement’

“Energy Resource Facility” (ERF) as defined in the Conditions of Service

“Feed-In-Tariff” (FIT) as defined in the Conditions of Service

“GCA” means ‘Generation Connection Agreement’

“Generator” as defined in the Conditions of Service

“GeoOttawa” is an online map, accessible from the City of Ottawa’s website, showing a detailed

map of the City

“GIS” means ‘Geographic Information System,’ an enterprise software for electronically

mapping the Grid normal state.

“Grid” as defined in the Conditions of Service

“Hydro Ottawa Distribution System”, refer to definition of “Distribution System” or “Grid” in

the Conditions of Service

“HOL” means ‘Hydro Ottawa Limited’

“Host” means the landlord or property owner of the building in which the ERF facility is located

“HONI” means ‘Hydro One Networks Inc.’

“HVDS” means ‘High Voltage Distribution Station’

“Independent Electricity System Operator” (IESO) as defined in the Conditions of Service

“Interface Transformer” also known as the distribution or servicing transformer, means the

transformer used to step the local distribution Grid voltage to the Customer Service Entrance

voltage

“Intermediate Transformer” means a Customer owned transformer used to step the generator

voltage to the Customer Service Entrance voltage. The Intermediate Transformer is always

installed on the Generator’s side of the ERF Metering Space

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“ISA” means ‘Installation and Service Agreement’, formally referred to as ‘IMA’ meaning

Installation and Maintenance Agreement

“Isolation” as defined in the Conditions of Service

“Isolating Device” means a circuit breaker or disconnect switch of appropriate rating, which may

be locked in the open position and whose configuration provides a clear visible point of

disconnection between the generating unit and the Hydro Ottawa distribution system.

“Isolation/Reconnection (I/R)” refers to a Customer initiated disconnection, followed by a

reconnection to the HOL Grid to allow the Generator to tie into the HOL distribution system.

“LOE” means Letter of Equivalency

“Lamacoid” as defined in GCS0008

“LOP” means Loss of Phase, referring to a separate Loss of Phase Detection and Isolation

Device

“MEC” means Measurement Error Correction

“Metering Space” means the contiguous area where the DG meter and disconnects are installed.

No Customer owned equipment is to be electrically wired within the restricted area. HOL

requires 24-7 access to the Metering Space

“NEMA” means the ‘National Electrical Manufacturers Association’

“OESC” means ‘Ontario Electrical Safety Code,” latest edition

“OTC” means Offer to Connect

“PCC” means “Point of Common Coupling” see also definitions for “Supply Point’ or “Point of

Supply”, as defined in the Conditions of Service

“PM” means the HOL “Project Manager” assigned to the ERF project

“Premise” as defined in the Conditions of Service

“Regular Business Hours” as defined in the Conditions of Service

“Service Entrance” as defined in GCS0008

“Site Specific Loss Assessment” (SSLA) is a scaling factor applied to revenue meter

measurements to account for unmeasured electricity used by wires and transformers, i.e.,

technical losses of electricity, between an electricity source and the deemed revenue metering

point. The source is either the Grid in the case of SSLA for Load, or the Energy Resource

Facility in the case of SSLA for generation. The deemed revenue metering point in either case is

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the Point of Common Coupling, or the Supply Point. The derivation methodology is detailed in

the calculation standard for Load and ERFs.

“SLD” means Single Line Diagram Drawing

“System Neutral” means the neutral from the Grid emanating from the same station as the

Customer Service Entrance feeder

“TAA” means HONI Threshold Allocation Assessment

“TAT” means HONI Transmission Allocation Tables

“WO” means work order

5.0 Project Process

The following process will provide a basic guideline for the standard FIT project flow. The

Generators are expected to provide the necessary information as required and the PMs are to

guide the Generator to help ensure correspondence with HOL’s timelines. This section

corresponds with the Process Flow Chart in Appendix A.

The province has mandated maximum LDC delivery durations with specific milestones for

connecting generators that will have or has a provincial contract. If there are delays, changes,

omissions, or additions required by the generator or other groups outside of HOL, the specific

HOL milestone timing may be stopped or reset. Where such events occur, please discuss with

Asset Management group on HOL’s appropriate action and response. Some generators wish to

provide edits to HOL’s requirements and template agreements. This customization causes delays

and is considered outside of the mandated provincial timing requirements.

5.1 Initial Consultation

Asset Management will be responsible for the Initial Consultation portion of the ERF

projects. During the Initial Consultation period, the Generator may request – at no additional

cost – ERF information from HOL via email or by phone. The Generator can send an email

to [email protected] ([email protected]). In some cases, a

site meeting may be required to confirm existing conditions for example: when information

on file is not adequate or is inconsistent and must be verified. The Generator must complete

sections two (2) through nine (9) of the CIA Application (Form B) prior to Initial

Consultation with Hydro Ottawa to receive the full benefit from the Initial Consultation

process. The CIA Application (Form B) can be found on the HOL external website. Once

the designated point of contact for HOL receives completed sections of the Form B from the

Generator, they will review all required information to ensure the installation is feasible.

Asset Management shall complete the Initial Consultation Template Table found on the

Intranet under the Technical Standard Forms link.

The HOL designated point of contact is to use GIS and other HOL records to identify;

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o Servicing Feeder and if applicable, Alternative Feeder

o Servicing Voltage(s)

o Number of Phases (one or three)

o Ownership of existing electrical equipment (HOL, Customer, HONI)

o Distribution Station (HVDS and HVDS feeder and Ownership will auto

populate)

o Supply point(s) (to the property)

o Cable supply length, type and size

o Interface Transformer details (may need to check Vault Database in some

cases to verify all detail, especially the configuration), including secondary

voltage(s)

o Property PIN(s)

The Interface Transformer should be reviewed in detail to ensure it meets current standards

and is of adequate capacity for the proposed generation. The kVA capacity should be

verified to ensure it is equal to or more than the requested kW of the proposed project. This

transformer must meet primary service requirements as per the Conditions of Service. All

applicable fields should be completed on the Initial Consultation Template.

Appendix F of the Conditions of Service must be reviewed to assure the requested kW can be

generated at the voltage and number of phases that are feeding the property and the cable

capacity should also be verified.

GeoOttawa can be used to determine the Property Identification Number (PIN) that defines

ownership and assessed value of the parcel. Only one FIT project can be located at each

individual PIN, or premise on a series of PINs.

The current IeSO/HONI Transmission Availability Tables (TAT) shall be reviewed for

capacity constraints. These capacity constraints can be verified by using the HONI Station

Capacity Calculator on their website. Asset Management can also use the HONI List of

Applications and the HONI List of Station Capacity. All three documents can be found in

the Initial Consultation folder on the ENG:\ERF and DG\Initial Consultation. However,

always ensure you have the most recently published HONI tables by visiting the HONI LDC

Generation web page. The Capacity section on the Initial Consultation Table can be

completed with the researched information.

It is also important to find out if HOL has a HONI Threshold Allocation Assessment (TAA)

for the HONI HVDS of interest. The TAA provides HOL with HONI’s bulk allocation of

capacity on a specific HONI HVDS to be rationed / allocated by HOL for CAE FIT projects.

The TAAs are tracked by Assets in a “Threshold Tracker” spreadsheet located in the Initial

Consultation folder on the ENG:\ERF and DG\Initial Consultation. If HOL does not have a

HONI TAA for the HVDS of interest, then the Assets Management Group needs to apply to

HONI for such. To do so, HOL needs to have a real project submission. HONI will take 60-

days to complete a TAA once they receive a complete and accurate submission with

payment.

Indicate if a separate LOP and/or a Monitoring and Control box will be required for the FIT

installation on the Initial Consultation Template; see Sections 7.2 and 7.3 when they are

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required. Should the existing Premise’s Supply Point need to be brought up to current

standards, Asset Management will outline this in the Initial Consultation.

The meter summary report for the proposed Premise should be checked to verify that the

existing Host load meter(s) meets HOL standards. This can be done by reviewing the

existing load revenue meter in the HOL Oracle metering portal.

Any system work that may affect the proposed In Service Date or commissioning schedule of

the FIT project should be reviewed and identified, if applicable. This will entail reviewing

the Sustainment/Demand Projects that may affect the circuit or station(s) the ERF is

proposing to connect to.

It should be confirmed that all energy account information is up to date and accurate in the

Customer Care and Billing (CC&B) enterprise software, if applicable. Appendix D of the

Conditions of Service is to be completed by the Generator and returned to the HOL PM.

Once all fields of the Initial Consultation Template have been completed, the template should

be put into PDF format and sent to the Generator. Attach any other relevant information,

such as if system expansion or enhancement is required with Level A estimate. The

Generator should also be made aware of where to find the latest construction standards (on

the external website), and notify them of all standard HOL scheduling notification

requirements throughout the course of an ERF project. When the Generator submits the

official CIA Application (Form B), the Initial Consultation document is to be included as

Appendix A.

5.2 Formally Submitting CIA Applications (Form B)

After the Initial Consultation, the Generator will have all the necessary information to

formally submit their Form B application to HOL’s Asset Management Department,

preferably by email to [email protected]

([email protected]). Once the Form B has been formally submitted, Asset

Management is to verify that all the required fields have been completed and that all pages

are sealed, signed and dated by a Professional Engineer registered in the province of Ontario.

The point of contact is to ensure that all the required documentation is attached with the

Form B submission;

Single Line Diagram (SLD)

Equipment Layout (plan and elevation view)

Site Plan

Protection Schema with Tripping Matrix

Inverter(s)/Generator Specifications

Intermediate Transformer and/or Loss of Phase Information (if Applicable)

Payments (in the acceptable format)

The SLD, Equipment Layout, Site Plan and Protection Schema should be sealed, signed and

dated by a Professional Engineer registered in the province of Ontario, as outlined in

Section 5. The Form B is to be submitted along with acceptable payment option, (verify

amount in Appendix G of the Conditions of Service).

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If the application is complete and accurate, then HOL may proceed with the DCIA. If the

application is incomplete, then Asset Management may seek from the applicant either

approval to proceed with the DCIA knowing there would be several pre-conditions, or a re-

application. Once the Form B has been formally accepted within HOL’s expressed timeline,

Asset Management will pass the project along to Distribution Design for assignment of the

project. The HOL PM, assigned to the project will let the Generator know that the Form B

has been accepted and that the DCIA will be issued within the DSC regulated timeline, (60-

days for CAE FIT projects not requiring system expansion). The HOL PM will issue the first

FIT Tracking Sheet to the Generator at this time and will review and confirm all applicable

timelines with the Generator.

The PM will receive the DCIA payment with the Form B submission. The cheque should be

scanned and saved to the electronic project file under subfolder ‘Finance’ and submitted to

the finance department for processing.

5.3 Project Setup

The HOL PM should review the Form B and all associated documentation after the project is

assigned to them. Once they’ve got a good understanding of the details, the project is to be

set up in JDE. The PM is to first create for each FIT project a Business Unit (BU) number,

under Capital Program 92099956 – Stations Embedded Generation, and Parent Program

92001318 – Embedded Generation. The project should be set up as a Capital project and the

title should match what is indicated by the Generator on the CIA Application. Then a work

order (WO) should be opened under that BU for the DCIA portion of the project. The DCIA

WO should be a ‘work for others’, ‘lump sum’ work order and component 0701 used.

5.3.1 Electronic Folder Layout

An Electronic Folder should be created for each FIT Project. The electronic folder

should be opened under the BU number in the Eng-drive;

Eng:\\Projects

The individual project folder should be labeled: ‘Project BU # – Address of Project’.

The project folder should be set up as per GAP0006.

5.4 Distribution Connection Impact Assessment (DCIA)

Once the project has been set up in JDE and the PM has reviewed the CIA Application (Form

B) and associated documentation, the PM is to provide the Form B to the appropriate Area

Planning Engineer (Planner) to complete the DCIA. The PM is to provide the Planner with

the associated BU number.

The HOL Planner is responsible for the completion of the DCIA. The Planner should use the

most up to date DCIA template found on the FIT Process Flow Chart on the Intranet, and

input all required documentation from simulation findings and review of Form B submission.

The Planner should refer to sections 6.2 for detailed instructions on completing the DCIA.

The Planner has a maximum of sixty (60) calendar days to complete the DCIA for a CAE

FIT (refer to the DSC for other ERF types), once the DCIA has been formally accepted by

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HOL’s designated point of contact. Once completed, the Planner is to provide the PM with

the final DCIA. The PM should read over the DCIA to make sure they are aware of any pre-

conditions to i.e., capacity reservation, construction, commissioning, or settlement/payment,

and to ensure they have an overall general understanding of all the project requirements prior

to issuing the DCIA to the Generator.

The PM will issue the final DCIA to the Generator for review at this time and identify any

existing pre-conditions. The PM is to provide the Generator with a Generator Payment Form

for completion of the highlighted sections (indicated ‘Completed by: Generator’) at this time

as well. The PM is to request an HST Registration Notice from the Generator along with the

completed Payment Form. It’s important to note that the name on the Payment Form and

HST Registration Notice must match that of the name issued on the IESO contract.

A final DCIA will have to be completed should any pre-conditions exist. A “revision” to the

DCIA will be required should any technical information change, meaning a simulation needs

to be re-run. Should only minor details require alteration(s); a DCIA “amendment” can be

completed instead of a full “revision”. This might be the case, should the Generator

re-submit a SLD or protection schema. Associated costs for the revision and amendment can

be found in Appendix G of the Conditions of Service, and can be billed out through a

Work-for-Others (WFO) work order. These costs should be communicated to the Generator

and received prior to the completion of the revision or amendment. All required revisions

and amendments are to be completed and no pre-conditions should exist before

commissioning has been completed.

5.5 Kick-Off Meeting

Once the finalized DCIA has been submitted to the Generator, the HOL PM is to schedule a

kick-off meeting. Ideally the kick-off meeting should be held on site to review the existing

site conditions and go over the exact location of the Metering Space equipment. Depending

on the specific project, the HOL PM should determine who is required to attend the kick-off

meeting. The following individuals should always attend the kick off meeting; the single

point of contact on the Generators side, the Generator’s site supervisor and/or electrician who

will be performing the work and the HOL PM. Additional individuals who may be required

to attend the kick-off meeting include; an Asset Planner, a Meter Tech, the Host, etc.

A meter tech may be required during the kick-off meeting to verify the existing state of the

load revenue meter on the Premise and to ensure it is up to current standards and no upgrade

or consolidation is required. A meter tech may also be requested to attend the kick-off

meeting, should the Generator be proposing to move the existing Host load revenue meter or

deviate from the DG metering standards.

Any design work required to upgrade the current configuration should be outlined to the

Generator during the Initial Consultation or during the DCIA process. Should this be the

case, a Distribution Designer should attend the kick-off meeting on site and review with the

Generator the extent of the work that is required.

During the kick-off meeting, the PM is to provide the Generator with all the applicable

standards. The PM should also provide the Generator with the Lamacoid Labelling template,

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found on the FIT Process Flow Chart on the Intranet, and review it with the Generator on site

to ensure the labeling is clear for all pieces of equipment. The Generator is to be reminded of

all HOL timeline requirements for each individual portion of the project. A brief run through

of the project flow chart, refer to Appendix A, will help the Generator stay on track and

ensure they have all the necessary information up front. A preliminary schedule with

estimated timelines should be discussed so that an anticipated in service date can be

determined, and to ensure the timelines are feasible and expectations can be met on both

ends.

At the kick-off meeting, the PM is to verify what type of isolation the Generator will be

requesting to connect to the Service Entrance point of the Premise. Any potential estimated

timelines that the Generator may have at this time should be provided to the HOL PM for

review and included in the Tracking Sheet.

5.6 Offer-to-Connect

The Offer-to-Connect (OTC) contains a proposed agreement between the Generator and

HOL. Included in the OTC is an Installation and Maintenance Agreement (will become the

Installation and Service Agreement (ISA)) that is to be executed by the Generator. The ISA

outlines the scope of work; who is responsible for the installation; cost; operating control and

maintenance of all electrical equipment and civil infrastructure relating to the generation

system. The OTC outlines all relevant costs for each of Hydro Ottawa’s services required to

connect the FIT project to the Grid, and the cost confidence level per HOL’s Project Charter

process. The cost for isolation and the installation of the meter will always appear in the

OTC, any additional design requirements or load meter upgrades will be outlined as

applicable. The OTC should reference the most up to date SLD, which the costs will be

based upon.

If HOL is required to complete a system expansion for a generator with a provincial contract,

the generator will receive a fixed $90,000 / MW credit and pay for the remainder of the

system expansion.

The I/R and ERF meter costs indicated in the OTC should be the lump sum fees as outlined

in the Appendix G fee schedule of the Conditions of Service.

Once the OTC has been completed with all necessary information and costs associated with

the project, the PM should issue the OTC to the Generator for review and execution. The

Generator is encouraged to hold off on construction until the OTC has been fully executed.

This is to ensure that all parties are aware of all cost implications and responsibilities for the

project. Once the Generator has signed off on the OTC and the associated deposit has been

submitted, the PM should set up additional work orders in JDE for the I/R, the DG metering

installation and any additional design work, or load meter upgrades that may be required.

The PM should scan and save the duly executed OTC agreement into the electronic project

folder.

The cheque corresponding to the OTC should be submitted to HOL at the same time as the

executed agreement. The PM should scan the cheque and save it to the electronic project

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file. The PM should submit the cheque with the BU and associated WO timely to Finance

Accounts Receivable.

5.7 Letter of Equivalency

Once the Generator has provided the PM with an expected commissioning date, the PM can

complete a Preliminary Letter of Equivalency (LOE), if applicable, and send it to HONI.

The LOE provides HONI with all applicable information concerning the new generation that

is to be put onto the Grid. A LOE is only required when the Generator is connecting to a

HONI HVDS. The PM will have to include the name and address of the ERF, ERF

nameplate capacity and fuel type, the contract number along with all the feeder connection

information. The feeder, bus and connection point can be found using GIS maps and

functions plus the HONI Operating maps found on the HONI Operating Maps Website. The

HONI maps will provide the HOL demarcation point on the TS side, when applicable. The

LOE should be sent to HONI’s Business Customer Centre and the appropriate Control

Authority Outage Planner identified in the Connection Agreement Operating Schedule A and

D, and the current HONI (and if applicable HOL) key account executive, plus to HOL’s

System Planning Desk and Green Settlements.

Once the project has been energized, a finalized LOE with the exact date of commissioning

and ERF identification number should be issued to HONI (if applicable).

In cases where the ERF is connected to a Hydro Ottawa owned High Voltage Distribution

Station (HVDS), no LOE is required.

The LOE template can be found on the Intranet under Technical Standards Forms link. Both

the preliminary and final LOE are required to be signed by a Professional Engineer,

registered in the province of Ontario (stamp not needed). Copies of the LOE should be saved

to the electronic project folder, on the ENG-drive.

5.8 Isolation/Reconnection

The Isolation/Reconnection (I/R) is to allow for the ERF to connect to the existing service.

The ERF will either; connect directly to the Interface Transformer secondary spades, or

ahead of the main building disconnect, depending on the site and space availability (refer to

ECG0015 for the FIT connection options).

HOL’s crews will complete I/R work. The Generator can request what type of crew they

desire for the I/R, as per Appendix G-3.1 of the Conditions of Service.

The Generator is to provide the PM with a proposed date and time to complete the work.

The Generator must give a minimum of ten (10) business days’ notice to schedule an I/R.

The PM is to then schedule this work with the Service Desk. The PM must provide the

Service Desk, the address of the FIT project, the WO and BU number associated with the

work, and the site contact information for the Generator’s electrician or supervisor who will

be on site at the time of the I/R. The PM is to let the Service Desk know whether a dedicated

crew or a regular crew has been requested by the Generator.

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While on site, the Generator’s electrician or site supervisor is responsible for getting ESA

Authorization. The Generator should be notified that if an ESA Connection Authorization is

not received, HOL’s crew will not reconnect the service and the load Customer will be left

isolated until ESA authorization has been received. Once the HOL crews have completed

their work, they will lock the DG System Fused Disconnect switch in the open position to

ensure the ERF equipment is isolated from the Grid until successful commissioning has

occurred.

5.9 Metering Installation

Once the Generator has completed the I/R portion of the project and has installed the DG

System Fused Disconnect, DG Source Disconnect, Meter Base and IT Cabinet (if required)

they can then request a meter installation. Once the request has been formally submitted,

HOL will complete the meter installation within ten (10) business days. In order to formally

request a meter installation, the Generator must submit the following documentation:

‘For Construction’ (or As-Built) SLD (sealed, signed and dated by a P. Eng.)

Site Plan and Equipment Layout (sealed, signed and dated by a P. Eng.)

Site Contact Information for Site Supervisor (or Electrician) on site

ESA Connection Authorization for secondary services <225A, where no complex

metering is required

Once the Generator has submitted all required documentation and formally requested a meter

installation, the PM will complete a Blue Light package for the Metering Department. Refer

to GDG0010 (Project Coach) on the Intranet for further Blue Light Package requirements.

The Blue Light package should be submitted to the Supervisor of the Metering Field Techs.

The supervisor will then schedule the meter installation and notify the PM once the work has

been completed. The metering technician(s) on site will lock out both the DG System Fused

Disconnect and the DG Source Disconnect to continue to isolate the solar generation from

the Grid until commissioning.

5.9.1 Information for GIS

After the meter has been installed, the metering department will send the PM an email to

confirm the installation and include all necessary metering information. This information

shall be saved in the electronic project folder as it will need to be sent to the Generator

upon issuing Confirmation of Settlement. An email should be sent to the Records

Administrator so that an update can be completed in GIS. An example can be found on

the FIT Process Flow Chart on the Intranet. The following information should be

outlined: [typical examples in brackets]

Address of Project

System Voltage [600Y/347V]

Source Circuit

Orientation [Underground, Overhead]

Phase [3 phase, 1 phase]

System Device Nomenclature (ERF ID – GE#)

Size

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Power Type [Direct Current]

Fuel Type [Solar]

Generator [Inverter]

Load Export Type [Exports to Grid]

Number of Generators [1]

Metering Type [Parallel]

Contact Name

Building Number

Street Name

Street Type

City

Comments: [MC Approval Number AE-1168 Rev.18, Meter ID Badge # OTT]

Installation Date

Asset Owner [Customer Owned]

Ownership Authority [Customer]

Control Authority [Hydro Ottawa]

Maintenance Authority [Others, Customer]

State [In Service]

Billing Rate Class [SCOMM]

5.10 Electrical Operating and Maintenance Agreement

Once the Generator has completed construction, and an As-Built SLD has been submitted to

the PM, the Electrical Operating and Maintenance Agreement (EOMA) template can be

completed. The EOMA is a tri-party document between the Generator, the Host (aka. the

Landlord) and HOL, (assuming the Host and the Generator are two different parties). Should

the Host and the Generator be the same party; a bi-party EOMA is to be executed. The

EOMA outlines which party has ownership of individual electrical equipment and/or civil

infrastructure, who is the Controlling Authority for the equipment and who is responsible for

the operation and maintenance of all assets. The table in Schedule B of the EOMA,

(Operations Contacts) is to be completed by all parties. HOL’s contact information will

already be completed in the EOMA template; however, both the Generator and the Host will

have to complete their portion of the table for each individual project. This contact

information will be used in the case of emergencies to allow HOL to contact the controlling

authority for both the Generator and/or the Host.

Prior to issuing the final EOMA to the Generator for signature, it should be reviewed by a

peer internally. Once finalized, a PDF version of the EOMA is to be issued to the single

point of contact for execution by both Generator and Host. One original copy of the fully

executed EOMA is to be distributed to all parties. The most up to date EOMA template can

be found on the Intranet under the Technical Standards Form link.

The generator’s final connection shall not be completed until the EOMA is executed.

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5.11 Requesting Commissioning

The Generator is to provide the PM with a minimum of four (4) weeks’ notice prior to the

proposed date for commissioning. At this time the Generator should submit an initial

Commissioning Plan to the HOL PM for review and acceptance. The commissioning plan

should include:

Time and Date of proposed commissioning;

Type and Size of Generation System;

Contact Information of parties completing commissioning tests; and

Lists of all applicable tests to be completed during commissioning, and the expected

outcome.

As a minimum, the Generator must complete four mandatory tests which HOL will witness

during the commissioning:

Visual means of disconnect;

Loss of Grid/anti-islanding;

Loss of phase (if applicable); and

Inverter(s) re-synch time (≥5 mins, or as agreed to in the CIA)

The Generator is not limited to these tests, and can complete additional tests should they

wish. The Generator should ensure their inverter(s) are compliant with IEEE 1547). It is

recommended that the Generator test the DC polarity before requesting PM on site for

commissioning. This will aid in avoiding additional commissioning delays and revisit costs.

The Generator is to provide the PM five (5) business days’ notice prior to the finalized

commissioning date. The following documentation must be submitted to the PM prior to

commissioning:

As-Built SLD (sealed, signed and dated by P. Eng.)

Finalized Site Plan and Equipment Layout (sealed, signed and dated by a P. Eng.)

ESA Connection Authorization

Finalized Protection Schema (sealed, signed and dated by a P. Eng.)

Finalized Form B (sealed, signed and dated by a P. Eng.)

Commissioning Plan

5.12 Commissioning

On the date of commissioning, the HOL PM is to notify HOL System Office Planning Desk,

the metering field tech supervisor, and the Meter Data Service personnel of which sit the FIT

installation will be energized. The PM is to be present on site during the commissioning of

the FIT system. The PM is only a witness, and should not assume any responsibility or

liability while present on site.

The PM, the Generator’s Site Supervisor (or electrician), and all other parties on site are to

review, on site, the planned job steps for commissioning and identify all hazards present or

anticipated. An onsite Job Plan (Tailboard) is to be created and signed off on site by all

parties. It should clearly identify that the Generator’s Site Supervisor is responsible. The

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Generator’s representative (site supervisor or electrician) is responsible for all Health and

Safety on site. Once Safety has been discussed, the PM will remove the locks from the DG

System Fused Disconnect and DG Source Disconnect to allow the onsite electrician(s) to

perform switching to energize the system. The PM will then confirm the fuse size inside the

DG disconnect(s) and inspect the Lamacoids.

The Generator’s Site Supervisor onsite should have prepped prior to HOL’s arrival and

should be ready to commission the system as soon as the PM gets to site. Any last minute

construction or site preparation, such as snow removal, should be completed prior to the

PM’s arrival. The Generator is encouraged to bring a DC power source to site to test their

equipment prior to commissioning. HOL will be on site to witness all required tests. Should

the Generator wish to complete additional tests, (after HOL is satisfied with witnessing the

essential tests or satisfied that the ERF will not affect Grid Integrity), HOL is not required to

stay on site. Commissioning should take no more than two (2) hours on site. Should the

Generator be unprepared or have problems with the commissioning tests, the PM at their

discretion can leave site after the two hours is up and the Generator will be charged for an

additional visit to re-attempt commissioning.

Should commissioning be unsuccessful, or the PM has decided that enough time has elapsed

a re-scheduled appointment will have to be made. The PM is to lock out the DG System

Fused Disconnect and DG Source Disconnect with HOL padlocks, leaving the FIT

generation off line. Another commissioning date is to be scheduled with the single point of

contact on the Generator side and the HOL PM. An additional fee, outlined in Appendix G

of the Conditions of Service, will be charged to the Generator for each additional

commissioning attempt.

In the case of successful commissioning, the HOL PM is to tag out (install red metering tags

on equipment) the DG System Fused Disconnect and DG Source Disconnect; the meter

should already be tagged.

The PM should complete the HOL Generation Commissioning Checklist, found on the

Intranet under Technical Standards Forms link. Once commissioning is completed the

Generator’s “competent electrician”, on site, is to sign off on the commissioning check list.

The PM is to take a meter reading and send the initial reading to the metering department for

analysis.

5.13 Confirmation of Settlement

After successful commissioning of the FIT system and all required documentation has been

submitted, confirmation of settlement can be issued to the Generator. The following

documentation is required prior to issuing confirmation of settlement:

Fully executed EOMA;

As-Built SLD;

Finalized Site Plan and Equipment Layout;

Finalized Protection Schema;

Finalized Form B;

Finalized DCIA;

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Confirmation of settlement will be issued in two separate emails. The first email is a one line

email accepting the official date. This email is required from the IESO without any

additional information present in the email. An example email can be found on the FIT

Process Flow chart on the Intranet. The second email will repeat the accepted confirmation

of settlement date and include all the additional metering information the Generator requires.

The MEC and SSLA will be included in this email. The MEC should always be a value of

0.00%, if the installation was as per HOL standards. The PM should verify that the SSLA

originally calculated by the Planning Engineer is accurate. Should cable sizes, lengths of the

SLD have changed the SSLA Calculation Spreadsheet should be updated to reflect the

correct SSLA. This value will also be identified in the Generation Connection Agreement.

Both confirmation of settlement emails are to be sent to the Generator’s appointed single

point of contact. HOL’s Green Settlements department should be cc’d to give them a heads-

up that the project is coming their way.

After confirmation of settlement has been issued, the PM is to confirm the Payment Form is

completed and up to date and that the Generator has provided an HST Registration Notice

(this is especially required if payments are anticipated to reach or exceed $30,000 CND/year,

as per Canada Revenue Agency – see finance for further details). These documents should

be saved in the Payment subfolder of the FIT Project file. This will allow HOL’s Green

Settlements department to easily access these documents. It should be confirmed that the

Generator’s name on the Payment form and on the HST Registration Notice matches the

name on the IESO contract.

5.14 Project Close Out

To finally close out the project, the PM is to issue a final LOE to HONI when applicable.

The final LOE should include the date of commissioning and the generator nomenclature ID

number. The LOE is to be signed by a P. Eng. The PM is also to prepare and have executed

the final contract, the Generation Connection Agreement (GCA).

5.14.1 Generation Connection Agreement (GCA)

The GCA template can be found on the Intranet under the Technical Standards Forms

link. This contract is between the Generator and HOL. This contract is mandated by the

Distribution System Code and the template can only be changed by the OEB. The GCA

has some repeat information from the EOMA; however, there are additional terms and

conditions for the Generator to abide by. The GCA incorporates:

Final From B;

IMA (ISA) OTC;

As-Built SLD;

Metering Diagram (if separate from SLD); and

EOMA

Protection Schema

Any assignment contracts (if applicable)

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Schedule D of the GCA summarizes technical and operating requirements that will apply

to the ERF. The SSLA will be outlined in this Schedule and information on the Loss of

Phase and/or Monitoring Control Box when applicable. Schedule F outlines the ‘contacts

for notice’, this section is to be completed by the Generator and the information in the

right hand column should match that outlined in the EOMA tables.

A draft version of the GCA should be sent to the Generator for review and completion of

Schedule F. Once the Generator has approved the draft GCA, the PM is to have the GCA

reviewed by a peer prior to issuing the final copy to the Generator. Both the Generator

and HOL are required to sign original copies of the GCA. The duly executed GCA

should be saved in the electronic project folder.

It should be noted that the Generator’s name on the GCA should match that of the name

on the IESO contract, the Payment Form and the HST Registration Notice.

Once final LOE and GCA have been completed, the PM should ensure that all

documentation is properly organized in the electronic project folder and that the following

hard copies of documents are placed in a green project folder to be kept for record purposes:

Final Form B

Final DCIA

Final Protection Study

IMA (ISA) (duly executed)

ESA Connection Authorization

As-Built SLD (

Site Plan

Equipment Layout

Technical Deviation(s), if applicable

Amendments to contracts, if applicable

Commissioning Plan

Commissioning Test Report

COVER testing report, if applicable

LOE (preliminary and final)

EOMA (fully executed, original copy)

GCA (duly executed, original copy)

Project Green Folders, refer to GAP0006, are to be filed and stored in the Hydro Records

Vault in the Commercial project area (Indexed by Civic Address).

The PM is to confirm all documentation has been submitted, filed accordingly and confirm

all charges on WOs are accurate and GIS is As-Built accurately. Once all aspects of the

project have been wrapped up and documented, the WOs can be advanced to status 92 so that

payments can be processed, and the project officially closed out.

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6.0 Planning and Legislative Considerations

6.1 Conditions of Service – Premise Upgrade

As per Hydro Ottawa’s Conditions of Service, whenever work requiring an ESA electrical

permit is completed for the Premise Service Entrance, the electrical service including Hydro

Ottawa operated electrical equipment shall be upgraded to meet current standards. This

could result in the upgrade of the existing load revenue meter(s), consolidation of Supply

Points, consolidation of transformation (to consolidate primary or secondary voltages), etc.

When upgrades to the existing services are required, the PM will be responsible for

communication to the Generator to ensure that all upgrades are completed prior to the FIT

installation. Alternatively, the Generator can provide, in writing, that these upgrades will be

completed prior to commissioning of the FIT project.

6.2 Analysis of CIA Application

HOL Area Asset Planners will complete a Distribution Connection Impact Assessment for

complete CIA Applications from Generators. The HOL Planner will review all submitted

documentation by the Generator for completeness and proceed to; model the system in

CYME, calculate the SSLA loss adjustments and complete the DCIA template. The Planner

is to review the SLD, Equipment Layout and Site Plan, the Protection Schema and all

equipment specifications provided by the Generator to ensure they meet HOL’s current

standards and the requirements outlined in Section 5. Any errors or omissions should be

outlined in the DCIA as pre-conditions to construction and/or commissioning.

6.2.1 Modelling the Generation Facility in CYME

The assigned Planner is to run a simulation in CYME using the latest distribution model

extracted from GIS, to evaluate the effect of the Generator on voltage and short circuit

levels. See Standard ECS0038 for a guide on using CYME. If an upstream station

already exists as a network in the CYME distribution model then the existing one should

be opened and a model of the new generation created on the feeder. Should the station

not exist, or the existing station model, not give expected short circuit results, then the

station or equivalent source should be modelled prior to creating the ERF model on the

appropriate feeder. The Planner is to verify that all equipment specifications

(transformers, circuits, other generations, etc.) are accurate by comparing to GIS, the

Vault Database, or project file when required. The Planner should run a short circuit

fault analysis in CYME to identify any changes to the short circuit levels due to the

Generator’s equipment, and to ensure the service entrance, station equipment, and

distribution equipment fault ratings are not exceeded. All the existing and committed

ERFs associated with the Grid model set should be confirmed.

6.2.1.1 Fault Analysis (ANSI Parameters)

Table 5.1 shows allowable symmetrical short circuit limits permitted on various primary

voltages in the Hydro Ottawa Service Area.

Table 5.1: Symmetrical Short Circuit Limits

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Fault

Location

Fault

Type

Symmetrical Circuit Limit

4.16 KV

Symmetrical Circuit Limit

8.32 KV

Symmetrical Circuit Limit

12.47 KV

Symmetrical Circuit Limit

13.2 KV

Symmetrical Circuit Limit

27.6 KV

Symmetrical Circuit Limit

44 KV

Station Bus

Fault

LLL 10.50 10.50 11.50 21.5 17 20

LG 10.50 10.50 11.50 10 12.5 8

LL 10.50 10.50 11.50 21.5 17 20

LLG 10.50 10.50 11.50 21.5 17 20

PCC Fault

LLL 10.50 10.50 11.50 21.5 17 20

LG 10.50 10.50 11.50 10 12.5 8

LL 10.50 10.50 11.50 21.5 17 20

LLG 10.50 10.50 11.50 21.5 17 20

6.2.1.2 Power Flow Analysis

The allowable voltage tolerance for the system when generating vs. not generating at the

PCC shall be as per HOL ECG0008.

6.2.2 Calculate Site Specific Loss Adjustment (SSLA)

The Planner is to calculate the initial SSLA using the information provided by the

Generator on the submitted SLD and Form B Application. As per HOL’s Conditions of

Service – Section 2.4.5.8, the SSLA is a condition for settlement. The Generator can

provide a calculated SSLA sealed, signed and dated by a Professional Engineer registered

in the Province of Ontario should they wish, or accept the HOL calculated SSLA. Either

party can question or accept the other’s SSLA. The SSLA components are the Interface

Transformer loss and the wire losses.

To assess the Interface Transformer losses;

1) If the Interface Transformer is HOL owned, then; an OEB default of 1.0%

will also be included to the Customer’s energy to account for the Interface

Transformer losses consistent with HOL’s Transformer Loss Credit.

2) Otherwise; calculate the Customer owned Interface Transformer loss

considering the resistive losses accounting for the no-load and ERF nameplate

rating for load loss. Assess the appropriate ratio of time between no-load and

load loss. Update the Customer’s energy account SSLA adjustment factor.

To assess the wires loss, calculate for the HOL cables from the PCC (the deemed revenue

meter point) to the ERF revenue meter. A percentage to factor in for the wires loss

should be based on the cable specifications and distance from equipment. Refer to

ECG0005 and ECG0009 for demarcation supply points currently applicable (see

ECS0012 Appendix I for legacy demarcation points prior to November 1st, 2000). The

Planners should use the SSLA Calculation Spreadsheet, found in Schedule 1 of ECS0039,

to calculate the total SSLA for each individual project. Refer to ECS0039 for detailed

instruction on how to use the spreadsheet.

6.3 Biweekly Project Status Update Spreadsheet

For each project, the Biweekly ERF Update Spreadsheet should be kept up to date with each

milestone.

Biweekly Update Spreadsheet: ENG:\ERF and DG\Bi-weekly update

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The Excel file is to be updated throughout the course of the project with all applicable

information. The spreadsheet is used to keep track of project status, and to complete internal

and external reporting requirements. The information entered into the spreadsheet should be

verified during each project milestone and correspond with all information provided by Asset

Planning, Metering Department, GIS and the Generator. It is important to ensure that all data

entered into this spreadsheet is correct and accurate, since the information is used to ensure

HOL is compliant with the DSC Appendix E Service performance metrics.

Initially, during the Initial Consultation portion of the project, Asset Management will input

the project information into the spreadsheet and complete as many columns as possible.

After completion of the DCIA, the HOL Planner will be responsible for updating the

spreadsheets, and then throughout the remaining course of the project, the HOL PM will be

responsible for completing all required fields and ensure they remain up to date and accurate.

6.4 FIT Milestone Tracking

The FIT Milestone Tracking Sheet is a tool designed to help the HOL PM better

communicate with the Generator’s Single Point of Contact (identified on the Form B). The

FIT Milestone Tracking Sheet template can be found in the FIT Process Flow Chart on the

Intranet and in Schedule 1. The Milestone Tracking Sheet provides a quick and manageable

way to find all the required information for each FIT project. The Milestone Tracking Sheets

should be updated and sent to the Generator, on a bi-weekly or monthly basis depending on

the stage of the project, or at the PM’s discretion. All versions of the tracking sheet are to be

stored in the Project file.

Any estimated timelines provided by the Generator should be included in the Milestone

Tracking Sheet under the ‘Planned Dates’ column. As scheduled timelines approach and

timing becomes clearer, the PM can add the ‘Forecasted Dates’ to the Milestone Tracking

Sheet. As milestones get completed the ‘Actual Dates’ are populated into the spreadsheet.

Any issues and/or risks that are determined throughout the duration of the project should be

recorded on the Milestone Tracking Sheet and marked with the dates these issues (or risks)

were identified. Applicable standards, HOL time restrictions, and commissioning

requirements are outlined at the bottom of the tracking sheet, for quick reference by the

Generator. The Milestone Tracking Sheet template is only a guideline and milestones may

need to be added or removed depending on the nature of the project.

6.5 Timelines

The HOL PM is to ensure the Generator is aware of the timeline requirements for the FIT

process. The timelines are as follows:

Initial Consultation:

o Five (5) business days – three or less projects from the same

company/Proponent/Generator

o Ten (10) business days – more than three projects or project requires field

verification/archive search

Form B Submission:

o Ten (10) calendar days – review and acceptance of application

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o Sixty (60) calendar days – to complete the Distribution Connection Impact

Assessment (DCIA), after formal application acceptance

Single Line Diagram Re-Submission(s):

o Ten (10) business days – for review after each resubmission

Offer-to-Connect (OTC):

o Ten (10) business days – after the HOL PM has granted authorization to

construct (granted no additional Distribution Design work is required).

Isolation/Reconnection:

o Ten (10) business days’ notice

Metering:

o Work completed within ten (10) business days

Commissioning:

o Four (4) weeks’ notice prior to anticipated date

o Five (5) business days’ notice prior to confirmed date

If the Generator, at any time, provides new information, changes their criteria or a change is

recommended by a third party, then the timelines may reset, as required to ensure project

feasibility.

7.0 Design Criteria

The following criteria, provides a basic guideline for the standard FIT project installation.

Generators are required to conform to these standards and all applicable corresponding standards

outlined in the Reference section of this document and available on Hydro Ottawa’s external

website. Planners should have a good understanding of the design criteria so as to ensure all

requirements are captured in the DCIA.

7.1 ERF Metering

Metering for FIT installations shall be in accordance with the current edition of Hydro

Ottawa’s Metering Specification GSC0008. The bi-directional meter, related meter base, and

applicable Instrumentation Transformer (IT) Cabinet, in a FIT installation should be

immediately preceded by a DG System Fused Disconnect and immediately succeeded by a

DG Source Disconnect, refer to MCS0058. The two fused disconnects are required to enable

isolating the HOL meter. These three pieces of metering equipment are to be installed in the

same contiguous space, designated as the ‘Metering Space’. Under no circumstances can any

Customer owned equipment be installed between the two disconnects and the metering unit,

or in other words inside the ‘Metering Space’. The Metering Space can be installed inside

the Premises’ electrical room or at an outdoor location if the Metering Space enclosure meets

the requirements of GCS0008.

The ‘metering space’ shall comply with GCS0008 including, but not limited to:

Space requirements;

Height and mounting locations restrictions;

Properly matched meter base to the main disconnect rating;

Properly sized IT cabinet (when applicable);

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Meter base requires a neutral conductor, preferably the System Neutral, to be

terminated no shorter then at the DG Source Disconnect switch, if not required by the

generation equipment; and

Metering space is to be located inside the electrical room, or outside in line-of-sight

to the interface transformer.

The DG disconnects and the meter must be labelled according to MCS0058. Lamacoids

should be installed directly on the front of the electrical equipment and follow the

specifications noted in MSC0102.

The metering for Stand-Alone ERFs, follow the same requirements as for FIT projects.

Refer to Section 5.3 for Net-Metering and Load Displacement ERF projects.

7.2 Monitoring and Control Box

A Monitoring and Control Box is required when one or more of the following apply:

The ERF name plate is ≥ 251kW (limit subject to be reduced as the need may arise

with ERF intensification, fuel type, or generation profile type);

The servicing feeder has reclosing protection;

An Alternate Feeder1 to the property exists;

The Monitoring and Control Box is to protect the Integrity of the Grid, restrict generation to

the normally designated feeder and provide HOL control of the ERF for emergency operating

purposes. The Monitoring and Control Box also allows HOL to access the ERF operating

information for Grid management and regulatory reporting.

HOL is responsible for the design and commissioning of the Monitoring and Control Box.

The Generator is to install the enclosure and HOL crews are to wire the system. The

Monitoring and Control Box sensors should be the first piece of equipment installed after

(Generator side) the DG Source Disconnect.

7.3 Loss-of-Phase Protection

An independent Loss-of-Phase device, to the inherent feature of the inverter, is required if

one or more of the following apply:

The LDC side of the Interface Transformer is of delta or tee configuration;

There is more than one inverter in the DG configuration;

It is deemed required by OESC or ESA;

There is an Intermediate Transformer present between the Interface Transformer and

the inverter(s).

1Due to some areas within the HOL Grid having various switching positions, an Alternate Feeder will not be

assigned simply because a feeder other than the normal supply feeder could receive electricity. If an Alternate

Feeder exists at the Service Entrance associated with the ERF, Generation is permitted on the normal feeder;

however, for the potential to be granted operational permission for generating on the Alternate Feeder then a

Monitoring and Control box is required. However, only Hydro Ottawa’s System Control Authority can permit

generating on the Alternate Feeder through a HOL SCADA command to the Monitoring and Control box.

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The LOP should be installed on the ERF side of the DG Source Disconnect immediately after

the Monitoring and Control Box sensors (when applicable). In the case where no Monitoring

and Control Box is present, the LOP is to be installed directly after the DG Source

Disconnect. All Customer owned equipment is to be installed on the ERF side of the LOP.

When present, the same sensors and contactors for the Monitoring and Control Box can be

used for this LOP device.

7.4 Single Line Diagram

An electrical Single Line Diagram of the ERF and connection to the Host Service Entrance is

to be submitted with the Form B application for a CIA. Refer to the Hydro Ottawa standard

ECG0015 for FIT or Stand-Alone permitted connections; otherwise refer to the respective

Net-Metering or Load Displacement standard. All submitted SLDs shall be sealed, signed

and dated by a Professional Engineer registered in the province of Ontario.

The Host load and FIT ERF should be connected in parallel, typically after the Host Interface

Transformer. The SLD should clearly indicate the overcurrent rating/fuse sizes for all such

devices. Wiring lengths, types and sizes plus all NEMA ratings are to be stated. The SLD

should be reviewed in conjunction with the Form B, Site Plan, Equipment Layout and

Protection Schema to verify that all documentation corresponds to each other.

Any time the Generator makes an update or change to the SLD, a new version is to be

submitted to HOL for review and acceptance. HOL has up to ten (10) business days to

review the SLD and provide comments after each re-submission or accept. Prior to the

installation of the ERF metering equipment, a formal ‘For-Construction’ SLD is to be

submitted to the HOL Project Manager (PM) for review and acceptance. The ‘For-

Construction’ SLD is to be included in the Blue Package submitted to the metering

department for the DG meter installation. Prior to commissioning of the system, the

Generator is to submit a final ‘As-Built’ SLD for acceptance by the PM. The final ‘As-Built’

SLD, like all previously submitted SLDs, is to be sealed, signed and dated by a Professional

Engineer registered in the province of Ontario.

7.5 Site Plan and Equipment Layout Diagrams

A Site Plan and Equipment Layout diagram (of the Metering Space) are to be submitted

along with the SLD and the Form B. The Site Plan should be an aerial view and clearly

indicate the location of all new and existing electrical equipment. All electrical equipment

on the Site Plan and Equipment Layout should be labeled with the appropriate nomenclature,

as per MCS0058, and NPS0001. The Equipment Layout should show a plan and elevation

view of the Meter Space, indicating all heights, clearances and relevant NEMA ratings

associated with the equipment. Both documents are to be sealed, signed and dated by a

Professional Engineer registered in the province of Ontario.

Throughout the duration of the project, should the location of any equipment change, the

Generator shall provide a new Site Plan and/or Equipment Layout to the HOL PM for review

and acceptance. The latest copy of the Site Plan and Equipment Layout should be included

in the Blue Package provided to the metering department for the DG meter installation work.

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Prior to commissioning, a final Site Plan and Equipment Layout are to be submitted to the

PM, along with the As-Built SLD.

7.6 Protection Schema Document

A Protection Schema Document is to be submitted with the Form B application. The

Protection Schema Document is to be sealed, signed and dated by a Professional Engineer

registered in the province of Ontario, on each individual page. It will be the responsibility of

the Planner to review and accept the Protection Schema Document. The Protection Schema

should indicate overcurrent rating for the DG system disconnect(s), and any other protected

Customer owned equipment. The Protection Schema should also demonstrate that the

inverter(s) have anti-islanding capabilities and provide the inverter settings that will be used,

not the settable range or assumption of default. A copy of the inverter(s) specifications,

protection scheme, and tripping matrix should also be included in the submission.

If the inverter is derated, the method and effect on operations should be included. How the

inverter is derated is to be detailed and signed, stamped and sealed by a P. Eng. Should the

inverter(s) be derated, then the nameplate shall be updated accordingly. When a property has

more than one feeder supply available, the Protection Schema should indicate the use of the

Monitoring and Control Box to ensure the Generator is not able to supply on the Alternate

Feeder(s) without Hydro Ottawa System Control Authority’s written approval.

Individual settings, for all applicable equipment, should be outlined in the Protection

Schema. It should be indicated if the settings are fixed, or if they vary (a range should be

indicated in this situation). This includes ratings of over-current protection devices.

The devices and methods for ERF isolation from the PCC should be clearly identified on

SLD and Protection Schema Document. Power quality properties should be specified in the

Protection Schema such as: expected voltage dip at the PCC when the inverter starts, the total

harmonic distortion and possible range, the operating frequency range and the power factor

range and guaranteed set-point. If power quality issues are outside HOL limits the Generator

shall install corrective measures to ensure operation within defined limits, see ECG0008.

The Generator may wish to include the inverter manufacturer’s tripping matrix, in a table

format with the Protection Schema, should they wish. The tripping matrix should list all

protection devices, their type, rating and time of operation. The tripping matrix does not

need to be signed off by a Professional Engineer unless there are deviations or optional

setting changes that differ from the devices standard operation. Ultimately, it is the

Protection Schema documentation that will be accepted or rejected by the Planner.

The Protection Schema should provide details on how the inverter will behave under

Abnormal Grid Conditions and abnormal conditions of the inverter’s input. The Protection

Schema should clearly indicate whether the inverter ceases to operate or another device

isolates the generating system from the Grid. The reaction time and the duration of the

protection response should be indicated, along with what trigger (if any) that will initiate the

change of state, and the number of cycles allowed before a fail-safe, or non-automated,

intervention is needed.

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If a LOP device is required, the Protection Schema shall specify the type of device that will

be used and the behavior of that device during abnormal Grid conditions.

It should be noted, that stand by charges will apply should a higher level of back up than

normal for Customer’s connection be requested for reliability or loading purposes.

Currently, Automatic Transfer Schemes (ATS) are not permitted for Generator’s. Should one

be installed at a premise the Generator will be locked outed, unless otherwise agreed upon by

HOL’s Asset Management group and System Office. HOL is seeking approval from the OEB

for a custom standby rate, and once approved, the Asset Management group shall provide

further clarification for these type requests. The technical requirements for such connections

will require a SCADA interface with the generator’s output control devices.

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Appendix A: PROCESS FLOW CHART

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Appendix B: Net-Metering and Load Displacement

Net-Metering and Load Displacement ERF projects can also follow this process guideline with

slight similarities and differences to FIT ERF projects as follows;

A CIA is still required for Net-Metering and Load Displacement when the

existing and proposed total generation will be of >10kW on the property.

Contract requirements are the same as for FIT when total generation exceeds

10kW.

Standby charges, for Net-Metering and Load Displacements ERFs, are applied to

the energy account per the present standby terms and conditions.

Other charges may apply for account administration, or set up. Consult the rate

approved feeds and charges.

Metering

Regulatory Affairs confirms OEB requirements for a meter specifically for profiling the

generation unit(s) to provide the Net-System Load Shape with and without generation.

Net Metering

For Net-Metering, the existing load meter at a premise is changed to a bi-directional meter.

There is no separate meter for the generator at the parallel grid connection like there would be

for a FIT or Stand-Alone generation project.

Load Displacement

For Load Displacement, unless there is a concern for potential receipt of electricity from the

ERF, there existing load meter may remain unidirectional.

.1 Load Displacement Exemptions Connection Impact Assessment of Load Displacement ERFs can have no special

electrical protection, if they meet all the following criteria;

When three years of revenue metering data is available, the ERF nameplate

capacity is <25% of the Customer’s lowest demand (not average) over the past

three years, and the Customer has no plans of any major load reduction; OR

When less than three years of revenue metering data is available the ERF name

plate capacity is <10% of the load’s average annual peak

For new premises without an established revenue metering data history, a Load

Displacement ERF may be fast tracked if all Load Displacement fast track

conditions are met and the Customer installs Reverse Flow Protection triggered at

1kW of electricity delivered from the Grid

The ERF maximum nameplate capacity is less than 500kW, whether inverter or

rotating machine interface to the Grid;

There is no Customer controlled Automatic Transfer Switch (ATS) between

supplying circuits;

The Customer is not within a revenue horizon period for a system expansion that

it triggered;

The Load Displacement ERF meets any requirements of the upstream transmitter;

The Customer’s Service Entrance meets HOL’s Conditions of Service; and

The ERF, when operating, does not generate electricity that then gets received by

the Grid.

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There is currently no provincial incentive program for Net-Metering or Load

Displacement with IESO funding contracts. Therefore, all requests and correspondence

is strictly with Hydro Ottawa.

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Schedule 1: FIT MILESTONE TRACKING SHEET

F.I.T. Update Sheet Project: XXXXXX

HOL PM Name: Cons. PM Name:

HOL Estimates: Estimate Type Total:

Estimate Values

Milestones Planned Dates Forecast Dates Actual Dates Comments

Initial consultation (MM/DD/YYYY) (MM/DD/YYYY) (MM/DD/YYYY)

Submit form B (MM/DD/YYYY) (MM/DD/YYYY) (MM/DD/YYYY)

DCIA (MM/DD/YYYY) (MM/DD/YYYY) (MM/DD/YYYY)

Construction Authorization (MM/DD/YYYY) (MM/DD/YYYY) (MM/DD/YYYY)

Request isolation (MM/DD/YYYY) (MM/DD/YYYY) (MM/DD/YYYY)

Request meter (MM/DD/YYYY) (MM/DD/YYYY) (MM/DD/YYYY)

Commissioning (MM/DD/YYYY) (MM/DD/YYYY) (MM/DD/YYYY)

Close out (MM/DD/YYYY) (MM/DD/YYYY) (MM/DD/YYYY)

Issues / Risks Identified Date

Example issues: Service transformer is undersized for the generation requested. (MM/DD/YYYY)

Relevant Information Applicable standards are posted on the Internet The standards as a minimum: -ECG0015, MCS0058, MCS0063 (ie. add outdoor metering standards if required) Isolation/Shutdown: -Fee incorporated in estimate & deposit. -10 business days’ notice. -ESA Connection Authorization -Building Service required for HOL reconnection. -Coordinate for ESA C/A -Generation to also be done at this time. Generation Meter: -Upon notice to HOL, process timeline within 10 business days -Work package created for Metering Department, includes: -Approved SLD, ‘for construction’ version -ESA Connection Authorization –Generation -Greater or equal to 400A (IT cabinet), ESA C/A. Commissioning: -Provide 4 weeks’ notice for HOL to comply with HONI OGCC requirements and to notify HOL System Office -Submit Commissioning Plan for review at this time Commissioning Plan Must Include: -Location, Date, Time, and Attendees. -What will be demonstrated to comply with HOL requirements -HOL is only a witness.