app 11.3 transmission unit cost study snc lavalin

8/17/2019 App 11.3 Transmission Unit Cost Study SNC Lavalin

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Unit Cost Estimates for Transmission Lines

and Facilit ies in Northern Ontario and

the Far North

Presented to

Ontario Power Authority

October 18, 2011


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Revision: Final ReportDate: 19 October 2011

North West Ontario Transmission Cost StudyOntario Power Authority

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NOTICE

This document contains the expression of the professional opinion of SNC-Lavalin Inc.

(“SLI”) as to the matters set out herein, using its professional judgment and reasonable

care. It is to be read in the context of the agreement dated June 24,2011(the

“Agreement”) between SLI and * (the “OPA”), the methodology, procedures andtechniques used, SLI’s assumptions, and the circumstances and constrains under which

its mandate was performed. This document is written solely for the purpose stated in

the Agreement, and for the sole and exclusive benefit of the OPA, whose remedies are

limited to those set out in the Agreement. This document is meant to be read as a

whole, and sections or parts thereof should thus not be read or relied upon out of

context.

SLI, in preparing the cost estimates, has exercised due care consistent with the

intended level of accuracy, using its professional judgment and reasonable care, and is

thus of the opinion that there is a high probability that actual costs will fall within thespecified error margin. However, no warranty should be implied as to the accuracy of

estimates. Unless expressly stated otherwise, assumptions, data and information

supplied by or gathered from other sources (including the OPA, other consultants,

testing laboratories and equipment suppliers, etc.) upon which SLI’s opinion as set out

herein is based on has not been verified by SLI; therefore SLI makes no representation

as to its accuracy and disclaims all liability with respect thereto.

SLI disclaims any liability to the OPA and to third parties in respect of the publication,

reference, quoting, or distribution of this report or any of its contents to and reliance

thereon by any third party.

SNC-Lavalin as the selected proponent having entered into this agreement through the

Response For Proposal (RFP) process and in accordance with terms set out within said

proposal, shall not be precluded from participating in bidding on any other requests in relation to

this, or any other work associated with this proposal.


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TABLE OF CONTENTS

1. Overview ............................................................................................................................. 4

2. Study Methodologies and Assumptions .............................................................................. 4

3. Unit Cost Findings, including summarized results as provided in Tables 3, 4, 5 .................. 9

4.

Supporting Evidence and Benchmarks ..............................................................................18

APPENDICES ...........................................................................................................................20


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This report provides unit cost estimates for transmission lines and facilities in NorthernOntario and the Far North.

1. Overview

For the purposes of this study the delineation between “Northern Ontario” and the “Far

North” will be used as defined by the Ontario Ministry of Natural Resources (see Map 1

in Appendix 1). Northern Ontario includes the region north of Sudbury from Manitoba to

Quebec extending to the Far North Boundary. Most of this area is currently connected

to the grid and most communities have all season road access. In the Far North, there

are 26 remote communities (communities not accessible by all-season roads) and theTown of Pickle Lake. The majority of communities in the Far North are not connected to

the grid and are powered by local diesel systems. Of these remote communities there

are 20 which are located north of Pickle Lake, for which the OPA has been directed to

develop a plan for transmission connection.

For the purposes of this study, it is assumed that public lands are owned by the Crown

and access rights must be acquired from the Crown. The project cost information,

therefore will not include considerations of First Nations Impact-Benefit Agreements as

they are difficult to quantify and are assumed to be settled through consultation and

negotiation within the context of any specific project.

This deliverable will identify and summarize each facility type and cost category, the

costs of building transmission lines and facilities in the remote areas of the Far North

separately from the rest of Northern Ontario. Some of the conditions that are expected

to be encountered in remote locations include lack of road access or limited seasonal

road access, reduced work seasons for completing EAs and other development and

construction work and operating in rough undeveloped terrain.

2. Study Methodologies and Assumptions

Remote community connections include development of transmission line corridors to

enable grid connection. In order to select the line options and the location of

transformer stations it will be necessary to map a full range of environmental criteria as

well as the surficial geology so that sensitive features or areas can be avoided. Some

of the general environmental criteria which can be mapped to assist with the route

selection include:


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• Ecological Areas of Concern (Vegetation/Wildlife);

• Land-cover/Land-use;

• Species at Risk Habitat/Breeding Areas;

• Land Ownership;

• Road Networks;

• Existing Transmission Lines;

• Watercourses and Waterbodies;

• Surficial geology;

• Mineral Deposits;

• Archaeological Sites;• National Parks, Provincial Parks and Conservation Reserves;

• Woodland Caribou Herds and Migration Routes; and

• Communities/Populated Places.

3.1.2. Right-of-Way and Site Acquisition Cost

Land will be required to accommodate the ROW for the transmission lines and

associated facilities for the projects. From the review of the preliminary corridors for the

transmission lines, and due to the fact that the study area is located in a remote region

of northern Ontario, we have assumed the lands required for the projects will primarilybe “Public Land”. Public (Crown) lands owned by the province and are under the

jurisdiction of the Ministry of Natural Resources (MNR) with respect to their control and

management. Under this scenario, the MNR policy for Utility Corridors on Public Lands

(Policy 4.10.03, October 2006) is applicable to the projects. This policy provides a

standardized approach to granting of tenure and establishment and collection of rent for

the occupation of public land by utility companies. The annual rental formula is based

on land value per hectare (ha), multiplied by the area occupied, multiplied by impact on

fee simple (75% for transmission lines and facilities) and multiplied by the annual rate of

return (8-10 %). For costing purposes we have assumed the following ROW widths for

the project in the study.

LINE DESCRIPTION ROW, in meters (typical)

2-cct 230 kV, lattice towers 40



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1-cct 230 kV, H-frame wood poles 30


1-cct 115 kV, H-frame wood poles 30

1-cct 115 kV, single wood pole 20

NOTE: ROW width is a function of span length, line voltage, height of the structures.

For example using the 1-circuit 230 kV transmission line option from Ignace to PickleLake with a length of 295 Km and assumed ROW width of 30 m, the following cost

estimate (annual rental) is derived.

Land – $1,062,000 (1,180 ha x market value of $1,200/ha for northwest Ontario) x 75 %

(impact on the fee simple) x 10% (established/assumed rate of return by MNR) =

$79,650 annually or $270 per Km.

The above formula has also been applied to determine annual rental cost for site

facilities (e.g., transformer stations).

Annual rental cost for crown land required for the transmission line project andassociated facilities is presented in Tables 1 thru 4. These costs are not included in the

total cost or the unit costs per kilometer.

3. General Engineering Considerations

• 2011 unit costs for Project Management, Engineering Procurement Management,

Project Controls, Construction Management, Quality, Safety and Environmentalsupport were provided by the SNC-Lavalin procurement group

• All construction activities were estimated per unit cost/activity as per our defined

Work Breakdown Structure (WBS).• The cost of tower steelwork is assumed to be $3.00 per kg. This was developed

from a current 5 year term agreement with an existing supplier and is based upon

today’s market prices (as with all commodities, current pricing is no guarantee of

future trends) with the addition of transportation costs.

• Allowances were included for stand down due to bad weather.


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• Helicopter rates used:

o Foundation work: $5000 per hour

o Assembly and Erection: $7,500 per hour

o Stringing: $5,000 per hour

• Camp accommodation rate is $200 per day per man (food, showers, laundrywashing etc)

• Productivity in winter from November to February has been reduced by 20%. Afurther 20% allowance has been included for exceptional weather during

December and January.

Assumptions of the cost estimates to supply Northern Ontario

• To develop the unit rates the route lengths considered are:

o 230kV 300 km

o 115kV 200 km

o 44kV 50 km

o 25kV 50 km

• Excluding tower steelwork, a 3% allowance is included on top of standard

Delivered Duty Paid (DDP) prices for transportation of materials.• Adequate road infrastructure exists the length of the line routes

• There is no adequate road infrastructure intersecting the line routes

• Terrain is considered level or gently rolling

• Soil condition is considered rock

• Geo-tech boreholes every fourth structure

• Heavy brushing for 50% line routes

• Three marshaling yards each 2.5 acre located along the 230kV and 115kV line

routes

• No marshalling yard for 44kV and 25kV

• Installation of 5 meter wide temporary access road for 50% of the line routes

• Helicopters assist in construction activities of the 230kV and 115kV

• Helicopters will not support the construction activities of the 44kV and 25kV


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Assumptions of the cost estimates to supply the Far North

• To develop the unit rates the route lengths considered are:

o 230kV 200 km

o 115kV 200 km

o 44kV 50 km

o 25kV 50 km

• A 25% allowance is included on top of standard DDP prices for transportation ofmaterials.

•

There is no adequate road infrastructure existing the length of the line routes andno adequate road infrastructure intersecting the line routes

• Terrain is considered level or gently rolling

• Soil condition is considered rock and muskeg

• Geo-tech boreholes every fourth structure

• Heavy brushing for 75% line routes

• Three marshaling yards each 2.5 acre located along the 230kV and 115kV lineroutes

• No marshalling yard for 44kV and 25kV

• 5 meter wide temporary access road for 100% length of line is assumed

• Helicopters will fully support all construction activities

Fibre Optic Communications Options:

• All substation schemes in these estimates are considered to have protection,

telecom and SCADA. As the most economic solution the telecom considered is

fiber optic. As such the fiber optic infrastructure cost is included in all substation

schemes, in the “Total Cost”. The cost is not presented separately.

•

The telecom identified in the substation schemes must be supported by atransmission infrastructure. This fibre optic infrastructure on the transmission

and distribution lines is separate from the commercial communications

equipment discussed below.

• Commercial fibre optic equipment in the substation schemes has not been

considered.


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• For transmission line estimates, the base cost has been presented with the cost

of overhead steel earth wire only and the cost of Power Line Carrier (PLC)

facilities. Cost for the fibre optic infrastructure required for substation telecom

requirements is shown separately in the column labeled “Cost of Fibre Optic

Comms”. This cost includes one 48 fibre OPGW, accessories and repeater

stations, which is sufficient for substation requirements only. Some spare fibres

may be available for commercial use, but accessories and repeater stations

would have to be modified or added to allow for commercial fibre optic

applications.

Exclusions:

For the purposes of this study, the following factors were not included in the estimates:

• Disbursements to land owners/occupiers

• Type testing and third party quality testing and inspection

• Environmental mitigation

4. Unit Cost Findings, including summarized results as provided in Tables 3, 4, 5

Development work estimates shown in the applicable cost tables were based on theidentified routes and assumed transformer stations locations for the purpose ofcompleting environmental assessments, securing all environmental permits/approvalsand obtain land tenure for the transmission lines and facilities identified in NorthernOntario and the Far North.

Single Line Diagrams (SLD) were developed in order to prepare detailed technical datarequired for the estimates. These SLDs were the basis of cost tables 4 and 5, and areincluded in Appendix 3.

3.1 Unit Cost Findings for Northern Ontario

The study findings for lines and facilities in Northern Ontario are summarized in the costtables shown below.

Assumptions used in the development of the estimates are outlined in section 2.Technical details used in the estimates are included in Appendix 2.


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Cost estimates in Northern Ontario are generally higher than in the Southern part of theprovince due to the lesser availability of infrastructure and higher transportation costsfor labour, equipment and material. Whereas construction in Southern Ontario is notusually affected much by winter weather, more severe winter weather in NorthernOntario will reduce productivity. Foundation installations in Southern Ontario aregenerally less costly to work with due to the soil conditions than in Northern Ontariowhere bedrock are frequently found in many parts.


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Table 3A – Unit Costs per kilometer for new lines in Northern Ontario.


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Table 4A – Unit Costs for new Transmission Facilities i n Northern Ontario


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Table 5A – Detailed Description of New Transmission Facilities in Northern Ontario


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3.2 Unit Cost Findings for the Far North

The study findings for lines and facilities in the Far North are summarized in the costtables shown below.

Assumptions used in the development of the estimates were outlined in section2. Fortechnical details used in the estimates refer to Appendix 2.

It was expected that cost estimates in the Far North are generally higher than inNorthern Ontario. The Far North generally has limited infrastructure causing significantlyhigher transportation costs for labour, equipment and material. More construction

access will be required in the Far North adding to the higher cost, or, where not possibledue to muskeg for example, winter construction will be required. Winter constructionhowever, affects productivity to a much higher extent than in Northern Ontario; reduceddaylight reduces work hours as well.

Foundation installation in the Far North is also expected to be costlier due to permafrostand muskeg conditions.


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Table 3B – Unit Costs per ki lometer for new lines in the Far North.


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Table 4B – Unit Costs for new Transmission Facilities in the Far North


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Table 5B – Detailed Description of New Transmission Facilities in the Far North


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5. Supporting Evidence and Benchmarks

Detailed parameters used in the development of the cost estimates are included in

Appendix 2.

Given our extensive exposure to the Transmission and Distribution markets,ongoing work within the province and complimentary relationships within thegeographical study area, we are confident of the basis of the estimates producedwithin the constraints of this submission.

The cost estimates for Northern Ontario and The Far North are comparable (withinthe constraints of this submission and without breaching commercialconfidentialities) with the following studies by SNC Lavalin:

• The Northland Study ( 2011)

• The Nishnawabe Aski Development Fund (NADF) Study in Northern Ontario(2009, basis of estimate 2007)

• Goldcorp’s Red Lake Project (2011)

All of the above projects utilized a single circuit 115kV transmission line H-framedesign, although each project, as with almost any transmission project contained

unique characteristics, such as timing, specifications, access, constructionmethodologies and location.


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Level of construction difficulty and cost impact comparisons throughout the threeregions of the province.

Activ ity /Cond iti ons Southern Ontario CostImpact

Northern Ontario CostImpact

The Far North CostImpact

Access Direct access to Right of Way 1 In areas terrain restricts access.Muskeg. Lack of roads.

1.2 Terrain greatly restricts access.Significant muskeg. Nosupporting infrastructure.

1.5

Soil conditions Till type. Possibly augerfoundations.

1 Mixture: Till, broken rock, muskegand permafrost.

1.2 Mixture: Broken rock, muskegand permafrost.

1.5

Average Difficult Very difficultWeather Yearlong installation.

Unaffected by winter1 Yearlong installation but in areas

terrain restricts installation towinter. Some severe winterconditions. Inefficiencies duringwinter.

1.2 Terrain greatly restrictsinstallation to winter. Longerfreezing periods and moresevere winter conditions.

1.5

Average Difficult Very difficult

Transportation ofresources

Project locations within reachof central developed areas.

1 Terrain and remoteness providessome restrictions. Somespecialized transport required.Inefficiencies.

1.2 Difficult terrain and remote.Inefficiencies. Costly specialtransportation required.

1.5


Transportation ofequipment andmaterial

Project locations within reachof central developed areasand logistic resources.

1 Terrain and remoteness providessome restrictions. Logisticresources not readily availableand some specialized transportrequired.

1.2 Difficult terrain and remote.Costly logistics. Specializedtransport required.

1.5


Local logistics Local accommodations readilyavailable.

1 Requires fully equippedconstruction camps.

1.2 Requires fully equippedconstruction camps. Costly dueto remoteness.

1.5


Staging areas andConstruction yards

Minimal preparation and effort.In direct reach of developedareas.

1 Staging areas required. Terrainrestricts direct delivery.

1.2 Staging areas required. Terrainand remoteness restricts directdelivery.

1.5


OVERALL Least difficult to construct. Average.

1 Average to difficult constructability. 1.2 Most difficult to construct. 1.5

Average costmultiplier

1 1.2 1.5


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APPENDICES

Appendix 1 – Northern Ontario and The Far North Delineation map.

Appendix 2 – Single Line Diagrams

Appendix 3 – Design Considerations

Appendix 4 – Environmental Assessment

Appendix 5 – Maps


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APPENDIX 1

Northern Ontario and the Far North


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APPENDIX 2

The Single Line Diagrams (SLD) shown in this appendix were developed in order toprepare detailed technical data required for the estimates. These SLDs were the basisof cost tables 4 and 5.

SLD 1: 230/115Kv 250MVA, 230/115Kv 125MVA Substation


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SLD 2: 114/44Kv 20MW, 115/25Kv 10MW, 44/25Kv 5MW SubstationNote: Same SLD is used for Table 2 and Table 4

SLD 3: 115Kv Single Tap-3 Terminations


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SLD 4: 115Kv Single Tap-1 TerminationNote: Same SLD is used for 230Kv and 115Kv Single Tap- 1 Termination


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APPENDIX 3

Design considerations included in the estimate scope:

Table 3: Unit Cost Per Kilometer for New Lines in Northern Ontario and the Far

North

230Kv S/C & D/C (Lattice) transmission lines

• The tower weight is estimated based on preliminary design of the Hydro 1“X” tower family

•

220 meter ruling span; within the “X” tower family parameters• 1 x 795 ACSR conductor

• Concrete drilled pile foundations; four per tower, 2.1meter diameter,

8meter depth

115Kv S/C (Wood pole) transmission lines

• Standard wood pole; Western Red Cedar Pole (WRC)

• 120 meter ruling span; within the WRC parameters for a single

• 120 meter ruling span; within the WRC parameters for a twin pole

structure

• 1 x 477 ACSR conductor per phase

• Wood pole are direct buried, supported with anchor included for 50% oftangents and 100% of angles/dead ends

• 10% screw pile foundations are included to support structures in abnormalconditions



• 120 meter ruling span; within the WRC parameters 1 x 336 ACSR

conductor

• Wood pole are direct buried, supported with anchor included for 50% of

tangents and 100% of angles/dead ends• 10% screw pile foundations are included to support structures in abnormal

conditions




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• 120 meter ruling span; within the WRC parameters 3/0 Pigeon ACSRconductor

• Wood pole are direct buried, supported with anchor included for 50% oftangents and 100% of angles/dead ends

• 10% screw pile foundations are included to support structures in abnormalconditions.

Table 4: Unit Cost for New Transmission Facilities in Northern Ontario and theFar North

• For the estimate the substation scopes considered are:230/115Kv 250MVA Auto Transformer TS Substation

• Site development is approximately 100 x 70 meters

• 100 meter access road

• 110% Oil Containment

• Screw pile foundations for muskeg

• Spread footing foundations for rock

• 1 x 250MVA 230/115Kv LTC Transformer

• 1 x 245Kv, 1200A, Live Tank Circuit Breaker

• 3 x 230Kv CVT• 1 x 230Kv Motor Operated Air Switch c/w Grounding Switch

• 3 x 240Kv Surge Arrestors

• 4 x 115Kv, 2000A, Dead Tank Circuit Breaker

• 8 x 115Kv Manually Operated Air Switch

• 9 x 115Kv CVT

• Control building

• Install SCADA, Telecom, P&C system

• Install 2 x Station Service Transformers for substation loads

• Install DC Charger and Battery System for P&C

230/115Kv 125MVA Auto Transformer TS Substation







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• 3 x 230Kv CVT

• 1 x 230Kv Motor Operated Air Switch c/w Grounding Switch




• 9 x 115Kv CVT


•

Install SCADA, Telecom, P&C system• Install 2 x Station Service Transformers for substation loads


114/44Kv 10MVA Step Down TS Substation






• 1 x 10 MVA 115/44Kv LTC Transformer• 1 x 115Kv, 600A, Dead Tank Circuit Breaker

• 3 x 115Kv CVT

• 3 x 44kv PT



• 3 x 44Kv, 600A Circuit Breaker


• 1 x 44Kv Bypass Fuse Switch


• Install SCADA, Telecom, and P&C system

• Install Station Service Transformer for substation loads


114/44Kv 5 MVA Step Down TS Substation




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• 1 x 5 MVA 115/44Kv LTC Transformer


• 3 x 115Kv CVT

• 3 x 44kv PT



•

3 x 44Kv, 600A Circuit Breaker• 6 x 44Kv Manually Operated Air Switch

• 1 x 44Kv Bypass Fuse Switch





115/25Kv 5 MVA Substation


• 100 meter access road• 110% Oil Containment





• 3 x 115Kv CVT



• 3 x indoor GIS 25Kv, 600A Circuit Breakers








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• 3 x 115Kv CVT



•

3 x indoor GIS 25Kv, 600A Circuit Breakers• Control building


o Install Station Service Transformer for substation loads

o Install DC Charger and Battery System for P&C





• Screw pile foundations for muskeg• Spread footing foundations for rock


• 1 x 44Kv, 600A Circuit Breaker

• 3 x 44Kv CVT





•

Install SCADA, Telecom, and P&C system• Install Station Service Transformer for substation loads


230Kv Single Tap – 3 Termination Substation





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• 12 x 230Kv CVT

• 12 x 230Kv CT





•

Install SCADA, Telecom, P&C system• Install 2 x Station Service Transformers for substation loads








• 1 x 245Kv, 1200A, Live Tank Circuit Breaker• 3 x 230Kv CVT

• 3 x 230Kv CT







115Kv Single Tap – 3 Termination Substation• Site development is approximately 70 x 70 meters







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• 12 x 115Kv CVT






• Install 2 x Station Service Transformers for substation loads









• 3 x 115Kv CVT

• 2 x 115kkV Motor Operated Air Switch c/w Grounding Switch


• Control building• Install SCADA, Telecom, P&C system

• Install Station Service Transformers for substation loads


Table 5: Detailed Description of New Transmission Facilities in Northern Ontarioand the Far North

For the estimate the substation scopes considered are:

One Incremental 230/115Kv 250MVA Line Termination



• Modify the existing bus and install 1 x dead end structure

• Update and modify the SCADA, Telecom, and P&C system

Spare Onsite 230/115Kv 250MVA Transformer (not connected)


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• 1 x 230/115Kv 250MVA LTC Auto Transformer

• 110% oil containment transformer foundation





• Update and modify the SCADA, Telecom, and P&C system


• 1 x 230/115Kv 125MVA LTC Auto Transformer• 110% oil containment transformer foundation



• 1 x 44Kv bypass switch with fuse


• Update and modify the SCADA and P&C system


• 1 x 115/44Kv 5MVA LTC Transformer• 110% oil containment transformer foundation




• Modify the existing bus



•

1 x 115/44Kv 3MVA LTC Transformer• 110% oil containment transformer foundation






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• 1 x 115/25Kv 5MVA LTC Transformer
















One Incremental 230Kv Single Tap


• 6 x 245Kv CT

• 6 x 245kv CVT

• 4 x 245Kv, Manually Operated Air Switch

• Modify existing bus and install dead end structures.

• Modify and upgrade SCADA, Telecom, and P&C system

One Incremental 115Kv Single Tap• 2 x 115Kv, 600A, Dead Tank Circuit Breaker

• 6 x 115Kv CVT

• 4 x 115Kv, Manually Operated Air Switch

• Modify existing bus and install dead end structures

• Modify and upgrade SCADA, Telecom, and P&C system


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APPENDIX 4

ENVIRONMENTAL ASSESSMENT

The Ontario Ministry of the Environment (MOE) has developed environmental

assessment (EA) requirements for electricity projects. These requirements are set out in

Regulation 116/01 (referred to as the “Electricity Projects Regulation”), made under the

Environmental Assessment Act (EAA). In the MOE “Guide to Environmental

Assessment Requirements for the Electricity Projects” (MOE Guidelines), the subject

230 kV transmission line options are considered a Category C type project. Category C

projects are major projects with known significant environmental effects. These projectsrequire an Individual EA and must be approved by the Minister in accordance with

subsection 5(1) and 5 (2) of the EAA.

There is a potential for the 230 kV line options to also "trigger" an environmental

assessment screening under the Canadian Environmental Assessment Act (CEAA),

should a federal authority perform one or more of the following: grant money or any

other form of financial assistance to the project; lease/sell land; or issue a

permit/approval. However, for purposes of the cost estimate at this time we have

excluded any environmental assessment requirements under the CEAA.

The proposed 115 kV line options fall within the types of projects covered by the “ClassEnvironmental Assessment for Minor Transmission Facilities” (Class EA, Ontario Hydro,

1992) document, approved under the Ontario Environmental Assessment Act. As such,

an environmental assessment study is required for the 115 kV transmission lines to be

conducted in accordance with planning and design process described in the Class EAdocument.

The identified OPA transformer and distribution stations, and SVC, Statcom or otherfacilities associated with the 115 or 230 kV options to supply Pickle Lake and remote

northern communities are assumed to be included in the environmental assessment

process.The 44 kV and 25 kV remote distribution lines do not require completion of an EA.

However, the work would be subject to numerous permits/approval and licenses from

regulatory agencies and are assumed to involve the preparation of a natural heritageexisting conditions and impact study to evaluate the routes and to fulfill permitting

requirements. As well, engagement of remote aboriginal communities on specificrouting options is also assumed to be required.


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Individual Environmental Assessment

Key work components for the Individual EA required for the 230 kV transmission line

options, and assumed in the SLI cost estimate, include the following:

All 230kV transmission lines will require an Individual EA, which is an extensive

undertaking involving numerous initiatives and requirements.

Class Environmental Assessment

The MOE Guidelines stipulate that 115 kV transmission lines and associated facilities(e.g., transformer station) are required to complete an environmental assessment inaccordance with the process set out in the Class Environmental Assessment for MinorTransmission Facilities (Class EA) as approved under the EA Act. Projects subject tothe Class EA are consistent with the screening level assessment process outlined underthe Electricity Projects Regulation (O. Reg. 116/01) for Category B type projects.Typically these types of projects have predictable range of effects, can be readilymitigated and are a proponent-driven self assessment process.

The scope of the environmental assessment for the 115 kV line options would involvesimilar work components as an Individual EA, however the assessment is assumed to

be less rigorous and would exclude Step 1 noted above (i.e., preparation of Terms ofReference). In general, the Class EA planning and design process includes thefollowing major steps:

1. Identify need/justification and purpose;

2. Collect relevant environmental, social and technical information;

3. Evaluate and compare site/route alternatives;

4. Identify and provide project description of the preferred design/solution;

5. Identify and assess environmental effects, including mitigation and impactmanagement measures to reduce negative environmental effects; and

6. Preparation of an Environmental Study Report (ESR) to document the EAprocess.

Consultation with external government agencies, public, Aboriginal communities aremandatory throughout the process.

Environmental Approvals, Permits and Authorizations


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The proposed high voltage transmission lines to supply Pickle Lake and 44/25 kVdistribution lines to remote communities will require a number of environmental permits,

approval and authorizations under federal and provincial laws in addition to the

completion of an EA, where applicable.


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APPENDIX 5

The following maps are included in this report:

1. First Nations map

2. Geology map.

3. Land cover map.

4. Permafrost map.


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SNC-Lavalin T&D

195 The West Mall

Toronto, ON

M9C 5K1

Phone: (416) 201 5939

Fax: (416) 231 5356E-mail:

[email protected]

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