application to the alberta utilities commission heisler ... · alberta utilities commission heisler...

10035 – 105 Street P.O. BOX 2426 Station Main Edmonton, Alberta T5J 2V6

APPLICATION TO THE ALBERTA UTILITIES COMMISSION

HEISLER TRANSMISSION PROJECT

December 22, 2011

ATCO Electric Heisler Transmission Project Application to the Alberta Utilities Commission Central East Transmission Development Attachment 1 – Application Text December 22, 2011

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INDEX OF ATTACHMENTS 1 THROUGH 12

ATTACHMENT 1 APPLICATION TEXT

ATTACHMENT 2 CONSERVATION AND RECLAMATION DOCUMENT

ATTACHMENT 3 PUBLIC CONSULTATION SUMMARY

ATTACHMENT 4 PROJECT AREA MAPS

Regional Map ................................................................................................Drawing RS-7LA701-A-01

Reference Map Drawing RS-7LA701-A-02

ATTACHMENT 5 ELECTRICAL DIAGRAMS AND SITE LAYOUTS

Proposed System Single Line Diagram .............................................................Drawing RS-7LA701-A-03

Heisler 764S Substation Proposed Site Plan ....................................................Drawing RS-7LA701-A-04

Heisler 764S Substation Proposed Single Line Diagram...................................Drawing RS-7LA701-A-05

ATTACHMENT 6 AIR PHOTO MOSAICS AND SITE PLAN

Proposed Route Mosaic ....................................................................................Drawing RS-7LA701-A-06

ATTACHMENT 7 TRANSMISSION LINE DRAWINGS

Right-of-Way Cross Section Drawings ..............................................................Drawing RS-7LA701-A-07

Typical 144 kV Single-Circuit Davit Arm Structure .............. Drawing RS-7SSP00-Davit-Arm (CE) 144SC

Typical 144 kV Single-Circuit Davit Arm Structure ...........Drawing RS-7SSP00-Davit-Arm-U (CE) 144SC

ATTACHMENT 8 CONSTRAINT MAPS

Soil Capability Map for Agriculture.....................................................................Drawing RS-7LA701-A-08

ATTACHMENT 9 NOISE IMPACT ASSESSMENT REPORT

Heisler Noise Impact Assessment Report

ATTACHMENT 10 PUBLIC NOTIFICATION PACKAGES

Public Information Package, February, 2011

ATTACHMENT 11 AESO DIRECTION AND TECHNICAL INFORMATION

AESO Notice pursuant to the Direction File No. RP-05-811, to ATCO Electric, dated December 5, 2011

AESO Direction Correspondence (Project RP-05-811, July 5, 2010)

AESO Functional Specification (Rev. 2, March 18, 2011)

ATTACHMENT 12 REFERENCE NOTE (CROSS-REFERENCE OF ATTACHMENTS)

NOTE: Confidential site plans and mosaic drawings have been included as part of this application. These drawings include landholder information for use by the Alberta Utilities Commission as part of their review and are designated as Drawings RS-7LA701-AC-04, and RS-7LA701-AC-06.


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INDEX TO INFORMATION REQUIRED PER AUC RULE 007 Information Requirements (Short Description) Found at: TS1 Sections of the HEEA under which application is made. Attach. 1, Sec. 1.2 TS2 Other acts that may affect the project. Attach. 1, Sec. 1.3, 1.4, 2.0,

5.2 TS3 Approvals being applied for. Attach. 1, Sec. 1.2, 1.4 TS4 Existing approvals for facilities being altered. Attach. 1, Sec. 1.2 TS5 Details/outcomes of consultations with local jurisdictions. Attach. 1, Sec. 1.4;

Attach. 3 TS6 Other companies affected, concerns, agreements. Attach. 3, Sec. 4.0. TS7 Description of proposed project. Attach. 1, Sec. 1.1, 1.6, 2.0 TS8 Copy of ISO direction letter. Attach. 11 TS9 Dates when approval and facilities required. Attach. 1, Sec. 2.5 TS10 Route alternatives and relative impacts. Attach. 1, Sec. 3.3, 3.4, 3.5 TS11 Description of participant involvement program. Attach. 1, Sec. 1.4, 1.5, 6.0;

Attach. 3 TS12 List of occupants, residents, landowners, interested parties contacted. Attach. 3 TS13 Mailing addresses and labels. Sent separately TS14 Persons identifying concerns and specifics. Attach. 3 TS15 Summary of discussions with directly/adversely affected persons. Attach. 3 TS16 How concerns are being dealt with. Attach. 3 TS17 Confirmation of resolution of concerns. Attach. 3 TS18 Design and operating voltages. Attach. 1, Sec. 2.1 TS19 Continuous and maximum ratings of transmission line; line losses. Attach. 1, Sec. 2.1 TS20 Conductor choice, size and arrangement. Attach. 1, Sec. 2.1 TS21 Transmission line structure types, height/spacing, locations. Attach. 1, Sec. 2.1

Attach. 7, Drwg. 144SC, TS22 Right-of-way width and the basis for width. Attach. 1, Sec. 2.1 ;

Attach. 7 TS23 Major substation equipment: applied for and final list. Attach. 1, Sec. 2.2 TS24 Switching and protection features. Attach. 5, Drwg. A-03 – A-05 TS25 Electrical interaction with other facilities. Attach. 1, Sec. 5.2 TS26 Changes required to existing facilities. Attach. 1, Sec. 1.2, 2.1 to

2.4 TS27 Map of study area; reasons for area chosen. Attach. 1, Sec. 3.1;

Attach. 4, Drwg. A-02 TS28 Maps/drawings of route and alternative routes, kilometre points (nodes);

right-of-way (R/W) widths and line locations re: R/W and property lines. Attach. 6, Drwg. A-06; Attach. 7, Drwg. A-07

TS29 Maps/air photo mosaics of routes, residences/landowners, and land-use/resource features.

Attach. 6, Drwg. A-06; Attach. 8, Drwg. A-08

TS30 Map of project area suitable for use in public notice. Attach. 4, Drwg. A-01

TS31 Electric single-line diagrams; substation layout. Attach. 1, Sec. 2.2; Attach. 5, Drwg. A-04–A-05

TS32 Construction schedule; construction and R/W maintenance methods. Attach. 1, Sec. 2.5; Attach. 2

TS33 Functional Specification Attach. 11 TS34 Noise Impact Assessment – Rule 012 Noise Control Attach. 1, Sec. 5.3;

Attach. 9 TS35 Conservation and reclamation plan for R/W clearing/maintenance as required by AENV. Attach.2 TS36 Landscape/screening areas and measures. Attach.2 TS37 Aesthetics: viewpoints and measures to minimize impacts. Attach.2 TS38 Tower location flexibility to reduce inconvenience to residents. Attach.2 TS39 Archaeological/historical impacts, consultation with ACCS. Attach.2

Attach 3 TS40 Environmental evaluation of study area and routes, table/discussion of land-use/resource

factors, comparison of environmental factors/costs; compatibility with municipal services if near urban centres.

Attach. 1, Sec. 3.1, 3.4; Attach.2

TS41 Detailed cost breakdown, Rule 007-Appendix B format. Attach. 1, Sec. 2.6


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TABLE OF CONTENTS

1.0 INTRODUCTION............................................................................................................... ..1 1.1 SUMMARY OF PROPOSED FACILITIES………………………………………...1 1.2 DISPOSITIONS REQUESTED.…………………………………………………….1 1.3 PROJECT NEED AND AESO DIRECTION.………………………………………1 1.4 AGENCY APPROVALS……………………………………………………………...2 1.5 LANDHOLDER POSITIONS………………………………………………………...2 1.6 FACILITY LOCATION SUMMARY.………………………………………………...3

2.0 PROJECT DESCRIPTION .................................................................................................3 2.1 PROPOSED 144 kV TRANSMISSION LINE 7LA701……………………………3 2.2 EXISTING HEISLER SUBSTATION 764S………………………………………..6 2.3 ALTERATION OF 144 KV TRANSMISSION LINE 7L701…………………….…8 2.4 ALTERATION OF 72 KV TRANSMISSION LINE 6L05……………………….…8 2.5 SCHEDULE…………………………………………………………………………...8 2.6 PROJECT COST ESTIMATE……………………………………………………….9

3.0 ROUTE SELECTION........................................................................................................11 3.1 STUDY AREA……………… ………………………………………………………11 3.2 GENERAL TRANSMISSION LINE ROUTING CRITERIA……………………..11 3.3 ROUTE OPTIONS …………………………………………………………………11 3.4 COMPARISION OF ROUTE OPTIONS FOR 7LA701…………………………12 3.5 SELECTION OF PROPOSED ROUTE FOR 7LA701………………………….14

4.0 PROPOSED ROUTE DESCRIPTIONS............................................................................14 4.1 PROPOSED ROUTE 7LA701……………………………………………………..14

5.0 ENVIRONMENTAL AND ELECTRICAL EFFECTS .......................................................15 5.1 ENVIRONMENTAL EFFECTS……………………………………………………15 5.2 ELECTRICAL EFFECTS…………………………………………………………..15 5.3 NOISE EFFECTS…………………………………………………………………..16

6.0 PARTICIPANT INVOLVEMENT.......................................................................................16 7.0 CONCLUSION ..................................................................................................................17


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LIST OF TABLES

Page TABLE 1 – Location Coordinates.....................................................................................................3

TABLE 2 – Transmission Line 7LA701 Details ................................................................................4

TABLE 3 – Transmission Line 7LA701 Thermal Ratings ................................................................4

TABLE 4 – Transmission Line 7LA701 Alignment and Right-of-Way..............................................5

TABLE 5 – Proposed Project Schedule ...........................................................................................7

TABLE 6 – Project Cost Estimate for Heisler Transmission Project................................................9

TABLE 7 – Summary of 7LA701 Route Options............................................................................12

TABLE 8 – Proposed Route 7LA701 .............................................................................................14


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1.0 INTRODUCTION

1.1 SUMMARY OF PROPOSED FACILITIES (TS7)

1. ATCO Electric Ltd. ("ATCO Electric") proposes to build new power transmission facilities

approximately five kilometres (km) southeast of the Town of Heisler and 20 km northwest of the Town

of Forestburg in southeast Alberta as part of the Central East Transmission Development project [see

regional map A-01]. The project includes the construction of approximately 1.5 km of new 144 kilovolt

(kV) transmission line, the re-location and alteration of Heisler 764S Substation 141 m to the south of

the original location, the re-termination of the existing 6L05 72 kV transmission line at the new Heisler

764S location, and salvage of a portion of the existing 6L05 72 kV transmission line. The work is

planned to commence by June 2012, or as soon as permits and licences are received, for a targeted

in-service date of November 2012.

1.2 DISPOSITIONS REQUESTED (TS1, TS3, TS4, TS26)

2. ATCO Electric hereby applies to the Alberta Utilities Commission (the “Commission”) pursuant to

Sections 14, 15, 17, 18 and 21 of the Hydro and Electric Energy Act (Chapter H-16 of the Revised

Statutes of Alberta 2000, as amended) for Permits, Licences, Approvals, and Orders to undertake the

following: a. construct a 144 kV transmission line designated as “7LA701,” originating at the existing 144 kV

transmission line 7L701 and terminating at the Heisler 764S Substation;

b. alter the existing Heisler 764S Substation (Permit and Licence No. AP 98-100);

c. alter the existing Battle River to Holden (AltaLink) 144 kV transmission line 7L701 (Permit and Licence AP 88-80);

d. alter the existing Battle River to Heisler 72 kV transmission line 6L05 (Permit and Licence U2000-304); and

e. connect these facilities to ATCO Electric's electrical system, and operate and maintain the aforementioned transmission facilities

1.3 PROJECT NEED AND AESO DIRECTION (TS2)

3. Development of transmission facilities is required to meet the existing and future demand and to

interconnect new wind and gas-fired generation in Central East Alberta. Pursuant to the applicable

processes under the Electric Utilities Act, the need for this project has been addressed by the Alberta

Electric System Operator (AESO) as AESO project RP-05-811, and is the subject of a Needs

Identification Document (NID) filed by AESO to the Commission on May 20, 2010, as Application

No. 1606218. Commission approval was provided through Decision 2011-048 issued as NID

Approval No. U2011-57 on February 10, 2011.

4. In accordance with Section 35 of the Electric Utilities Act, the AESO has directed ATCO Electric to

submit this application. A copy of that correspondence is included in Attachment 11.


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1.4 AGENCY APPROVALS (TS2, TS3, TS5, TS11)

5. The status of approvals from other agencies is described below. All of the below listed agencies have

been provided information as a part of the participant involvement process and have indicated no

objections to the proposed transmission facilities:

Flagstaff County is the municipal authority pursuant to the Municipal Government Act. The

proposed transmission facilities are exempt from the planning and development part of the

Municipal Government Act with respect to subdivision and development approvals.

Alberta Sustainable Resource Development (ASRD) is responsible for the management of

wildlife as a crown resource and for the conservation of species at risk under the Wildlife Act.

The project will be included in the pre-construction environmental survey program planned for

the associated Central East Transmission Development in spring and summer of 2012; the

survey will include survey of plants, animals, soils, and wetlands.

Alberta Environment administers the Environmental Protection and Enhancement Act and the

Water Act. The proposed transmission facilities do not require a Conservation and Reclamation

Approval or an Environmental Impact Assessment under the Environmental Protection and

Enhancement Act. ATCO Electric will comply with the Water Act and apply for all necessary

approvals, if required, prior to the start of construction.

Alberta Culture and Community Spirit (ACCS) have confirmed that an Historic Resources Impact

Assessment is not required under the Historical Resources Act (HRA) and has issued HRA

clearance.

With respect to agreement by TELUS Communications pursuant to Section 39 of the Hydro and

Electric Energy Act, ATCO Electric has referred the project to TELUS. There are no concerns

with this project or requests for mitigation.

With respect to the federal Aeronautics Act, the Applicant will submit the required information

and an application for Aeronautical Obstruction Clearance to the Transport Canada Civil Aviation

safety inspector.

1.5 LANDHOLDER POSITIONS (TS11)

6. ATCO Electric notified all landowners, occupants, agencies, and other potentially interested parties in

the project study area of the transmission facilities. ATCO Electric conducted personal consultation

with 53 agencies, landowners, occupants, and industry stakeholders. ATCO Electric has confirmed

that there are no objections to the proposed route for all parties. The participant involvement

program, compliant with AUC Rule 007, is described in Attachment 3 [Public Consultation Summary].


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1.6 FACILITY LOCATION SUMMARY (TS7)

7. The following table is a summary of facility land locations and latitude/longitude coordinates (upon

completion). TABLE 1: LOCATION COORDINATES

FACILITY LAND (LEGAL) LATITUDE

(N) LONGITUDE

(W)

(1) Heisler Substation 764S LSD 4, 30-42-15 W4M 52.640 112.163

(2) 144 kV Line 7LA701 -Start (Tap Point at 7L701) -End (Heisler Substation)

LSD 1, 30-42-15 W4M LSD 4, 30-42-15 W4M

52.638 52.639

112.140 112.162

2.0 PROJECT DESCRIPTION (TS2, TS7, TS8, TS18)

8. This section describes the location, project details, and engineering specifications of the proposed

transmission facilities. The facilities will be designed in accordance with the AESO's direction and

final functional specification [Attachment 11]. The facilities will be built and operated in accordance

with the authorizations granted pursuant to this application, and in accordance with the requirements

of Section 34 of the Hydro and Electric Energy Act (Highway Authority Approvals), Section 39 of the

Electric Utilities Act (Safe and Reliable Operation), the Safety Codes Act, and applicable regulations

and industry standards. The proposed facilities will be inspected and declared safe prior to being

energized. The proposed system single line diagram is shown in Drawing A-03 in Attachment 5.

2.1 PROPOSED 144 kV TRANSMISSION LINE 7LA701 (TS19, TS20, TS21, TS22)

9. ATCO Electric proposes to construct approximately 1.5 km of new single-circuit 144 kV transmission

line designated as 7LA701, tapping off from existing transmission line 7L701, extending west to the

Heisler Substation 764S. The proposed and rejected routes are shown on the reference map

[Drawing A-02 in Attachment 4] and the air photo mosaic [Drawing A-06 in Attachment 6].

10. The proposed transmission line will be a standard three-phase design with a single circuit of three

conductor wires strung on single-pole wood or steel structures built to ATCO Electric’s standards for

operation at the nominal voltage of 144 kV. The typical structure for this line will be a ‘Davit Arm’

design or similar. This design has a typical height of about 20 m and a typical span length of

approximately 100–180 m between poles. The line will have an overhead shield wire for lightning

protection. The typical structure is shown on Drawing RS-7SSP00-Davit-Arm (CE) 144SC in

Attachment 7. Design details are summarized in Table 2. The typical structure may vary with final

design.


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11. Approximately 0.96 km of the proposed transmission line will have the existing 25 kV distribution line

understrung on ‘Davit Arm’ design structures. The typical structure for this portion of the route is

shown on Drawing RS-7SSP00-Davit-Arm-U (CE) 144SC In Attachment 7.


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TABLE 2: TRANSMISSION LINE 7LA701 DETAILS

DESIGN TYPE TYPICAL 144 KV ‘DAVIT ARM’

STRUCTURE

Nominal voltage 144 kV

Line length (approx.) 1.5 km

Number of transmission circuits 1

Transmission line conductor 397.5 MCM ACSR, 3 phase

Overhead shield wire 1

Typical structure height 20 m

Typical span between structures 100 – 180 m

Minimum conductor clearance, mid-span 6.2 m – 6.7 m

(varies with location, per safety codes)

12. Non-typical structures with taller or additional poles, and/or anchors or guy wires will be required

where the line turns or terminates, or requires longer spans, greater clearance, or extra stability such

as across wet areas or valleys. In all cases, the line will meet or exceed the requirements of

applicable safety regulations. Final structure specifications will be determined following survey and

line design.

13. Conductors for the line will be single 397.5 MCM ACSR per phase as specified by the AESO. The

average and maximum loading for the line is estimated to be approximately 12 MW and 17 MW,

respectively. Line losses have been calculated to be approximately 0.05% for 7LA701 based on the

conductor type and average line loadings. Thermal ratings for the line are shown in Table 3.

TABLE 3: 7LA701 THERMAL RATINGS

THERMAL RATING: NORMAL

THERMAL RATING: EMERGENCY

Summer Winter Summer Winter CONDUCTOR

397.5 MCM ACSR

147 MVA 187 MVA 167 MVA 203 MVA

Transmission Line Alignment and Right-of-Way

14. The proposed transmission line alignment is based on the location of physical, land use, and

environmental constraints. The proposed route follows an existing county road allowance in order to

minimize impacts on adjacent land uses. The existing single circuit 25 kV distribution line will be

understrung on the 144 kV Davit Arm structures for most of the length of the proposed route.

15. A minimum right-of-way width is required for construction and maintenance access. The width and

structure placements vary with route location. Typical minimum right-of-way widths for the new line

are indicated in Table 4.


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TABLE 4: TRANSMISSION LINE 7LA701 ALIGNMENT AND RIGHT-OF-WAY

TRANSMISSION LINE (T/L)

ROUTE LOCATION

TYPICAL STRUCTURE LOCATION

MINIMUM RIGHT-OF-WAY WIDTH

(R/W)

Parallel to road allowance 1.0 m offset from road

allowance on private property 10 m parallel to road

allowance

Cross-country Centre of new right-of-way 9 m on each side of centre of transmission line (18 m total)

16. Right-of-way requirements for specific route segments are shown on the cross-section diagrams A to

C, drawings A-07 in Attachment 7.

17. Besides the minimum widths indicated, additional area is required as follows: at non-typical structures

such as at corners for anchors, guy wires, additional poles, and wider spacing; and in treed areas, in

order to keep the power line "tree-free" by removing adjacent trees that could fall onto the line now or

in the future.

2.2 EXISTING HEISLER SUBSTATION 764S (TS23)

18. ATCO Electric proposes to rebuild the existing Heisler Substation 764S, upgrading it from 72 kV to

144 kV capability. A 26 m self-supported steel lattice telecommunication tower will be added to the

substation. ATCO Electric is also proposing to terminate the new 144 kV transmission line

7LA701and re-terminate the existing 6L05 72 kV transmission line and existing 25 kV feeders at

Heisler 764S. The proposed Single Line Diagram of the substation is shown in Drawing A-05 in

Attachment 5.

Location and Land Area 19. The existing Heisler Substation 764S is situated in Flagstaff County about 5 kilometres (km)

southeast of the Village of Heisler, 115 km northeast of Red Deer, and 120 km southeast of

Edmonton. The site is located in LSD 4, 30-42-15 W4M (Lat/Long N52.640°, W112.163°). The

existing substation site is confined by the Battle River Railway NGC line to the east and Range Road

160 to the west. In order to accommodate the expansion, ATCO Electric proposes to extend the site

boundary to the south and re-locate the substation approximately 141 m south, where there will be

adequate space for the equipment additions. ATCO Electric owns the 3.25 hectare (ha) expanded

substation site in fee simple. The existing fenced area is approximately 12 m by 28 m. ATCO Electric

is proposing to expand the fenced area to approximately 78 m by 100 m in order to accommodate the

alteration. The substation expansion and re-location will occur within the ATCO-owned site.


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Proposed Addition/Removal of Major Equipment 20. Proposed major equipment to be added to the final design (below) will include the following:

a) one 25/33 MVA 144/72/25 kV transformer;

b) one 6/8/10 MVA 72/25 kV transformer;

c) two 25/33 MVA 25 kV voltage regulators;

d) two 25 kV circuit breakers;

e) one 144 kV circuit breaker;

f) one 72 kV circuit breaker;

g) one self-supporting telecommunication tower; and

h) one control building

21. Proposed major equipment to be removed from the final design (below) and relocated to the Kitscoty

705S substation will include the following:

a) one 10/13.3/16.6 MVA 144/72/25 kV transformer; and

b) one 13 MVA 25 kV voltage regulator

Proposed Major Equipment Final Design Specification

22. Proposed major equipment in the final design will include the following:

a) one 25/33 MVA 144/72/25 kV transformer;

b) one 6/8/10 MVA 72/25 kV transformer;

c) two 25/33 MVA 25 kV voltage regulators;

d) one 144 kV circuit breaker;

e) one 72 kV circuit breaker;

f) two 25 kV circuit breakers;

g) one self-supporting telecommunication tower;

h) one control building; and

i) an enclosure surrounded by a chain link fence and other substation equipment as described in the Application

Note: 25 kV equipment has been added to the listed equipment complement in accordance with the Commission’s current practice of inclusion of this class of equipment in the approved “Major Equipment” list. The above list includes two 25 kV voltage regulators as shown in 7.4.1.5 of the AESO functional specification [Attachment 11], however only one voltage regulator is included by the AESO in 5.4.8.4 of the functional specification.

General Equipment and Engineering Outline 23. The general equipment layout is indicated on the proposed site plan [Drawing A-04 in Attachment 5].

Engineering information, including switching and protection features, is shown on the proposed Single

Line Diagram [Drawing A-05 in Attachment 5]. Additional protection, SCADA, and telecommunication


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requirements are necessary to facilitate the operation of this facility as described in this application

and in the AESO functional specification [Attachment 11].

2.3 ALTERATION OF 144 KV TRANSMISSION LINE 7L701

24. The existing 144 kV line 7L701 operates between the Battle River Substation 757S and AltaLink’s

Holden Substation 395S, as shown on the system Single Line Diagram [Drawing A-03 in Attachment

5]. The ATCO Electric portion of the 99.5 km line is primarily a single-circuit single wood-pole

‘wishbone’ design with 397.5 ACSR conductors. ATCO Electric proposes to tap line 7L701 at LSD 1,

30-42-15 W4M, and connect the proposed line 7LA701 to the new Heisler Substation. The tap point is

indicated on the proposed route mosaic Drawing A-06 [Attachment 6]. Three sets of line switches will

be installed at the tap point to enable isolation of 7L701 north or south of the tap, and 7LA701 from

the main line.

2.4 ALTERATION OF 72 KV TRANSMISSION LINE 6L05

25. The existing 72 kV line 6L05 operates between the Battle River Substation 757S and Heisler

Substation 764S, as shown on the system single line diagram, Drawing A-03 [Attachment 5]. This

22.9 km line is primarily a single-circuit single wood-pole K500 design with 1/0 ACSR Raven

conductors. ATCO Electric proposes to re-terminate line 6L05 at the new substation location. This will

involve the decommissioning and removal of approximately 130 m of line. The proposed line

decommissioning is indicated on the proposed site plan Drawing A-04 [Attachment 5].

2.5 SCHEDULE (TS9, TS32)

26. Construction is scheduled to commence June 2012, if conditions permit and all necessary approvals

are received. The targeted completion date is November 2012.

27. The approximate schedule of key preparatory and construction activities is provided in Table 5. The

dates are approximate and may change in accordance to such factors as timing of approvals,

contractor plans, resource availability, material delivery, ground conditions, and weather.

TABLE 5: PROPOSED PROJECT SCHEDULE

ACTIVITY OR MILESTONE START COMPLETED

AUC approvals June 2012

Transmission line right-of-way clearing and construction

June 2012 November 2012

Substation alterations/construction June 2012 November 2012

In-service date November 2012

2.5.1 Consequences of Delay

28. Reliability of service to customers could be negatively affected. There are existing operational

constraints which do not meet the AESO Transmission Reliability Criteria – Part II System Planning.


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29. With regard to voltage standards, extreme minimum voltages cannot be maintained under the loss of

a single element (i.e. Bonnyville tie transformer) and the post transient voltage stability cannot be

maintained under the loss of a single element during winter peak loads in order to maintain voltage

stability requirements. Likewise, the emergency overload rating of a transmission element (i.e. Battle

River tie transformer) would be exceeded under loss of one transmission element under thermal

loading criteria. The Heisler 144 kV reinforcement would alleviate the voltage and overloading

concerns.

30. Some maintenance activities are restricted on transmission facilities in the area until additional

transmission capacity is installed. At present, maintenance is restricted on the Battle River tie

transformer and its associated breakers, switches and bus work.

2.6 PROJECT COST ESTIMATE (TS41)

31. The cost estimate for the scope of the project work, detailed in ATCO Electric’s proposal to provide

service submitted to the AESO is provided in Table 6.


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TABLE 6: PROJECT COST ESTIMATE FOR HEISLER TRANSMISSION PROJECT

(+20% / -10% Accuracy System Portion Customer

Portion Total

Transmission Line Cost (includes 6L05) Material $ 508,000 $ - $ 508,000 Labour $ 1,740,000 $ - $ 1,740,000

Total-Transmission line $ 2,248,000 $ - $ 2,248,000

Substation Facilities Cost Material $ 2,075,000 $ - $ 2,075,000 Labour $ 3,804,000 $ - $ 3,804,000

Total-Substations $ 5,879,000 $ - $ 5,879,000

Telecommunication Cost Material $ 140,000 $ - $ 140,000 Labour $ 113,000 $ - $ 113,000

Total-Telecommunication $ 253,000 $ - $ 253,000

Owner Costs Proposal to Provide Service $ 24,087 $ - $ 24,087 Permit & Licence $ 290,671 $ - $ 290,671 Land Rights - Easements $ 407,838 $ - $ 407,838 Land - Damage Claims $ 25,311 $ - $ 25,311 Land - Acquisitions $ 10,206 $ - $ 10,206

Total - Owner's Cost $ 758,113 $ - $ 758,113

Distributed Costs Project Indirects $ 238,824 $ - $ 238,824 Project Management $ 625,841 $ - $ 625,841 Construction Management $ 1,020,615 $ - $ 1,020,615 Contingency $ 890,793 $ - $ 890,793

Total - Distributed Costs $ 2,776,072 $ - $ 2,776,072

Total Direct Costs $ 11,914,185 $ - $ 11,914,185

Salvage Transmission Line Labour $ 24,600 $ - $ - Substation Labour $ 200,000 $ - $ - Land Remediation and Reclamation $ - $ - $ -

Total-Salvage $ 224,600 $ - $ -

Other Costs Inflation $ 662,583 $ - $ 662,583 AFUDC $ - $ - $ - E&S $ 878,137 $ - $ 878,137

Total - Other Costs $ 1,540,720 $ - $ 1,540,720

Total Indirect Costs $ 1,765,320 $ - $ 1,765,320

TOTAL PROJECT COST $13,679,505 $ - $13,679,505


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3.0 ROUTE SELECTION

3.1 STUDY AREA (TS27, TS40)

32. The study area for the transmission facilities was selected in order to provide a sufficiently broad area

for routing assessment. The study area, located within Flagstaff County, is primarily cultivated crop

and grazing land. There are a number of industrial oil and gas facilities in the area, including well

sites, pipelines, and associated access roads. The topography is generally flat to undulating. There

are a few water bodies in the study area, which consists mainly of wetlands and seasonal drainages.

There are no major watercourses or designated Environmentally Significant Areas within the study

area. Measures to reduce the environmental impacts of this project are described in the Conservation

and Reclamation Document [Attachment 2].

33. Existing linear disturbances in the study area provided a number of preliminary options for the

proposed transmission lines. These disturbances included existing distribution lines, railway,

pipelines, developed and undeveloped road allowances, and property boundaries. The proposed

route utilizes a combination of these features to minimize impacts to adjacent lands and landholder

concerns.

3.2 GENERAL TRANSMISSION LINE ROUTING CRITERIA

34. General routing criteria and objectives for selection of preliminary route options involve the following:

minimization of impacts with other land uses such as residences, built-up areas, oil and gas

facilities, and airstrips.

utilization of existing linear disturbances in order to minimize new disturbances and clearing, following existing power lines where possible.

the following of existing road allowances where practical and non-exclusive, for access and in order to reduce new clearing and avoid impacts to agriculture.

maintenance of routes as straight as possible in order to reduce line length and avoid costly corner structures.

minimization of length across environmentally sensitive areas such as watercourses, recreation areas, parks, and wildlife habitat.

minimization of length through wet areas and steep slopes for better access and in order to reduce environmental impacts.

3.3 ROUTE OPTIONS (TS10)

35. Preliminary route options were chosen based on the technical, economic, environmental, and land-

use criteria described in 3.1 and 3.2. The study area was analyzed to determine feasible routes

during the initial stages of route development. Route options were presented to landowners and land

occupants, the general public, and agencies. The Proposed Route and Rejected Routes that were


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developed are shown in the mosaic in Attachment 6 and both are further described in Table 7. The

descriptions and maps include ‘node’ identifiers (e.g., "A2") as reference points for the purposes of

clarifying the description.

3.3.1 Proposed Route: South Route with Additional Connection Option 36. The Proposed route starts from node B1 at the 144 kV transmission line 7L701 tap point, at the

southeast corner of 30-42-15 W4M. Paralleling Township Road 424, the proposed route proceeds

west for 0.34 km to node B1A, where the 25 kV distribution line will be understrung for 0.96 km until

crossing the Battle River Railway NGC line at node B1B. The route continues west for an additional

0.11 km to node B1C, turns north and then enters Heisler Substation 764S. The total length is

1.51 km.

3.3.2 Rejected Route: North Route 37. The North route starts from node A1 at the 144 kV transmission line 7L701 tap point, on the eastern

edge of the 30-42-15 W4M quarter line. The route proceeds west for 1.6 km along the quarter line to

the western edge. From there at A2, the line proceeds south for 0.7 km, paralleling Range Road 160,

crossing the Battle River Railway NGC line just before entering the Heisler Substation 764S at node

A3. The total length is 2.38 km.

3.3.3 Rejected Route: South Route 38. The original South route starts from node B1 at the 144 kV transmission line 7L701 tap point, at the

southeast corner of 30-42-15 W4M. The route proceeds west for 1.6 km along the southern boundary

of 30-42-15 W4M, crossing the Battle River Railway NGC line, and turns north at the southwest

corner of the section. From this point at B2, the line continues for 0.1 km, paralleling Range Road

160, and enters the Heisler Substation 764S at node A3. The total length is 1.75 km.

3.4 COMPARISION OF ROUTE OPTIONS FOR 7LA701 (TS 10)

39. In evaluating the route options and selecting the proposed routes, ATCO Electric considered the

information summarized in Table 7, the factors as shown on the route constraint map [Drawing A-08

in Attachment 8], and information obtained through consultation with affected landowners, occupants,

agencies, and interested parties as further described in Attachment 3.

40. ATCO Electric selected the proposed route as the route option that best meets the selection criteria

and incorporates response from landowner consultation. The proposed option follows an existing

linear facility (25 kV distribution line or railway) for its entire length. Table 7 summarizes the

comparison of 7LA701 preliminary route options.


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TABLE 7: SUMMARY OF 7LA701 ROUTE OPTIONS

Proposed Route = B1B1CHeisler Substation. Rejected North Route = A1A2A3, Heisler Substation. Rejected South Route = B1B2A3,Heisler Substation.

Routing Factor Proposed

Route Rejected North Route Option

Rejected South Route Option

Line Length 1.51 km 2.37 km 1.72 km

Number of Major Turns 2 2 2

Adjacent Linear Feature (within 50 m)

Existing Tranmission Line ROW 0 km 0 km 0 km

Quarter/Section Line 0 km 1.61 km 0 km

Cross Country (km) 0.16 km 0.05 km 0.05 km

Adjacent Access (including road crossings) (km)

1.35 km 0.72 km 1.68 km

Nearest Residence (m) 87.19 m 571.83 m 87.19 m

Residences within < 150 m of RoW 3 0 3

Residences within < 800 m of RoW 3 1 3

Area of Tree Removal 0 ha 0.87 ha 0 ha

Total Area of RoW (ha) 2.72 4.26 3.1

Percentage of RoW by Ownership Private: 100 Private: 100 Private: 100

Total Number of Landowner Objections within 800 m

0 0 0

Landowners and occupants on RoW with objections

0 0 0

Cultivated (ha) 0.86 1.79 1.08Pasture (ha) 1.28 0.33 1.25

Area of wetlands within RoW (ha) 0.08 0.45 0.08

Project Cost Estimate 2.04 M 2.27 M 2.04 M


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3.5 SELECTION OF PROPOSED ROUTE FOR 7LA701 (TS10)

41. The Proposed Route is the route option preferred by ATCO, based on routing criteria and landowner

and agency consultation.

3.5.1 Proposed Route 42. ATCO Electric has selected the Proposed Route as the option that best meets the selection criteria.

The Proposed Route has the following advantages:

minimal conflicts with existing developments and agricultural practices in the area;

shortest line length;

lowest cost to other options;

minimal impacts on adjacent land use;

largest proportion of line length following existing linear facilities and sharing distribution right-of-way; and

preference by landholders within 800 m and no concerns / objections

43. The Proposed Route has no significant environmental impacts that would trigger the need for a

review under the Environmental Protection and Enhancement Act.

3.5.2 Alternative Routes 44. The Alternative Routes were rejected largely because they followed existing linear disturbances for

a lower proportion of route length, and were longer than the proposed route. Although no landowners

objected to any of the route options, several landowners stated that they preferred the proposed

route.

4.0 PROPOSED ROUTE DESCRIPTIONS

4.1 PROPOSED ROUTE 7LA701

45. The proposed 144 kV transmission line 7LA701 tapping off of the existing transmission line 7L701 to

the existing Heisler Substation 764S is described in detail in the segment-by-segment descriptions

that follow. Detailed route information is shown on the proposed route mosaic, Drawing A-06

[Attachment 6] and on the cross-sections drawings A, B, and C in Attachment 7.


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TABLE 8: PROPOSED ROUTE 7LA701

REFERENCE POINT

LINE SEGMENT DESCRIPTION CROSS-SECTION

DRAWINGS

B1–B1A

(0.34 km)

Proposed route will start at the tap point from 7L701 and run west along the north side of Township Road 424

The adjacent land use is agricultural

A

B1A–B1B (0.96 km)

Proposed route runs west along the north side of Township Road 424 with under strung distribution

The adjacent land use is agricultural B

B1B–B1C (0.11 km)

Proposed route runs west along the north side of Township Road 424

The adjacent land use is agricultural/ATCO Electric substation property

C

B1C–Heisler Substation (0.10 km)

Proposed route runs north within ATCO Electric substation property

The adjacent land use is agricultural N/A

5.0 ENVIRONMENTAL AND ELECTRICAL EFFECTS

5.1 ENVIRONMENTAL EFFECTS

46. ATCO Electric will construct and maintain the proposed transmission facilities, and decommission

existing facilities adhering to Alberta Environment’s R&R/11-03, Environmental Protection Guidelines

for Transmission Lines, and in accordance with the terms and conditions of the right-of-way

agreements and easements. Measures to reduce the environmental impacts of this project are

described in the Conservation and Reclamation Document [Attachment 2], along with general

reclamation and long term right-of-way management practices.

5.2 ELECTRICAL EFFECTS (TS2, TS25)

47. High voltage electrical transmission facilities may induce a voltage in metal objects that are located

nearby. The most common objects are metal fences and buildings, telephone lines, and pipelines.

Appropriate mitigation measures are outlined as follows.

Radio and Television Interference 48. The transmission facilities will be constructed and maintained in such a manner as to keep radio and

television interference levels within limits acceptable to Industry Canada, the federal government

department that regulates communications.


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Telephone Facilities 49. Under certain conditions, power transmission facilities can induce both electrical noise and hazardous

voltages on telephone lines. ATCO Electric will work with TELUS before and after construction in

order to identify and mitigate adverse impacts.

Metal Fences, Buildings and Structures 50. Where necessary, metal fences, buildings, and structures will be grounded by ATCO Electric in order

to minimize induced voltages. Minimum clearance required between all transmission facilities and

buildings will be in accordance with the Safety Codes Act and regulations.

Oil and Natural Gas Well Heads 51. Regulations under the Safety Codes Act require that transmission facilities must not be located any

closer than 40 m from any natural gas or oil well head. This requirement will be adhered to with the

use of the most up-to-date information available. Well sites established subsequent to the date of our

information and prior to Commission approval will be appropriately accommodated in the design of

the project.

Pipelines 52. The Safety Codes Act and the Pipeline Act both have regulations to which the Applicant and the

pipeline operators must adhere. ATCO Electric, in conjunction with pipeline operators, will continue to

meet the regulated standards so that both facilities can be operated safely.

Electric and Magnetic Fields (EMF) 53. Landowners and occupants occasionally raise questions regarding the potential health effects from

EMF. ATCO Electric has reviewed the available literature on biomedical and epidemiological effects

of EMF; this research has indicated that EMF associated with high-voltage transmission facilities has

not been demonstrated to cause harmful biological effects.

5.3 NOISE EFFECTS (TS34)

54. A Noise Impact Assessment was conducted in accordance with the current AUC Rule 012 Noise

Control, for the proposed alterations to Heisler Substation. The report is included as Attachment 9.

The results show that the proposed facilities meet permissible sound levels.

6.0 PARTICIPANT INVOLVEMENT (TS11)

55. ATCO Electric undertook a comprehensive consultation program with landowners, occupants,

agencies and other interested parties, as described in Attachment 3, Public Consultation Summary.

ATCO Electric notified more than 70 landowners, occupants, agencies, and other potentially

interested parties within at least 800 m of the preliminary route options and substation site.

56. ATCO Electric has conducted personal consultation with all of the landowners, occupants, agencies

and interested parties directly adjacent to, or directly affected by, the preliminary routes and

substation. ATCO Electric has confirmed no objections to the proposed route and substation


Page 17

alterations for all parties. Those on the proposed route will be mailed a project update containing a

detailed site plan and advised of the construction schedule and details prior to construction.

7.0 CONCLUSION

57. Consultation with affected parties played an important role in the planning of these facilities. The

proposed route was selected based on general routing criteria as well as input from landowners,

occupants, agencies, and other interested parties potentially affected by the project. The Applicant

believes that the proposed transmission facilities are the most acceptable and respectfully requests

the Commission’s timely and favourable approval.

58. Correspondence or questions concerning this project can be directed to the project planners Nathan

Jones (phone 780-420-4184, fax 780-420-5030) and Scott Merrifield (phone 780-508-4562, fax 780-

420-5030), or the project manager Jing Shan (phone 780-420-3612).

Sincerely, ATCO Electric Ltd.

< Original signed by > Paul van den Camp, P.Eng. Vice President, Projects Capital Projects Division

ATCO Electric Heisler Transmission Project Application to the Alberta Utilities Commission Central East Transmission Development Attachment 2 – Conservation and Reclamation December 22, 2011

Page 1

ATTACHMENT 2 - CONSERVATION AND RECLAMATION

1.0 INTRODUCTION

1. ATCO Electric Ltd. (“ATCO Electric”) proposes to rebuild the existing Heisler Substation 764S and construct approximately 1.5 kilometres (km) of new 144 kilovolt (kV) transmission line (7LA701) from the existing 144 kV transmission line 7L701 to Heisler Substation 764S. ATCO Electric also proposes to re-terminate existing 72 kV transmission line 6L05 at the new substation location. These facilities are shown on the Proposed Route mosaic [see Drawing A-06 in Attachment 6], and are described in the application text (Attachment 1 of this application to the Alberta Utilities Commission). This document describes Conservation and Reclamation measures for the project.

2.0 PROJECT SETTING

2. The project area is situated in Flagstaff County. The proposed transmission line 7LA701 will extend for a distance of approximately 1.5 km from a tap point on existing transmission line 7L701 (located in LSD 1, 30-42-15 W4M) to the Heisler Substation (located in LSD 4, 30-42-15 W4M). The surrounding area is private agricultural land with some industrial (oil and gas) use.

3. The proposed new 144 kV line 7LA701 requires a minimum right-of-way nine metres (m) in

width along road allowance, plus additional area at corners and at termination points for special structures and anchoring [see right-of-way cross-section drawings A-07a-c in Attachment 7]. The proposed facility alignment will mainly parallel Township Road 424. The re-location and expansion of Heisler Substation will occur entirely on the ATCO Electric-owned site. Overall, there will be minimal impacts to the environment or to adjacent landholders.

4. The construction of these facilities is not an activity requiring Conservation and Reclamation

Approval or an Environmental Impact Assessment Report under the Environmental Protection and Enhancement Act (EPEA).

3.0 GENERAL CONSERVATION AND RECLAMATION MEASURES

5. ATCO Electric will undertake the construction and alterations adhering to the following:

Alberta Environment’s R&R/11-03, Environmental Protection Guidelines for Transmission Lines;

ATCO Electric's general construction and maintenance environmental protection standards; and

terms and conditions of the applicable right-of-way agreements and easements


Page 2

6. All activity will be confined to the existing or acquired right-of-ways and road allowances. ATCO Electric will follow standard good practices in order to minimize potential soil erosion and compaction, spills and prairie fires, and in order to implement post-construction clean-up and reclamation. The area is accessible year-round; soil and ground conditions for the new construction do not require seasonal timing constraints.

7. Construction activities are planned for Spring 2012 through Fall 2012, but it is possible that

additional work will be required beyond that time frame. Activities may be delayed if necessitated by changing weather or soil conditions.

8. As this project involves the addition of one 25/33 MVA 144/72/25 kV transformer and one

6/8/10/MVA 72/25 kV transformer and the removal of one 10/13.3/16.6 MVA 144/72/25 kV transformer, ATCO Electric is cognizant of the potential environmental hazard associated with transformer oil handling. Consequently, ATCO Electric will take all reasonable measures to address any contamination. ATCO Electric will employ appropriate spill prevention procedures during the transformer installation and removal. A spill or release will immediately be reported to Alberta Environment. ATCO Electric follows a number of best practices for spill mitigation and response including the following:

a) documented responsibilities and accountabilities for all ATCO Electric staff

b) on and off site availability of release response kits

c) regional listings and contact information for suppliers of containment materials (e.g., clay and sand) and equipment (backhoes, etc.)

d) standing contracts with specialized emergency response contractors for spill containment, clean-up, and remediation

e) locally available and project-specific Health Safety and Environment Coordinators

f) standard lists of required internal and external notifications, including government agencies such as Alberta Environment and Alberta Transportation (if spill occurs in transit)

g) emergency response plans identifying sources for immediate supply of berm, boom, and dyke materials for containment, and on-site storage locations for such materials

h) standards for classifying contaminated materials and appropriately disposal of it

i) specific emergency response plans for MSDS listed substances

j) standards and operational processes for completing emergency clean-up operations 9. Following the decommissioning and removal of the transformer and voltage regulator from

the existing substation, ATCO Electric will then remove the fence and all other substation infrastructure from the original substation site. ATCO Electric will undertake a Phase I & II environmental site assessment to verify the environmental conditions of the site. Should the


Page 3

assessment indicate adverse effects to the environment, ATCO Electric will undertake all reasonable measures to remediate the site.

3.1 EQUIPMENT

10. All construction equipment will be sent to the right-of-way in clean condition in order to minimize the risk of weed or disease introduction. Logging equipment and crawler tractors may be required for clearing the right-of-way, although vegetation removal is expected to be very minimal. The following types of equipment may be used to construct the transmission line:

pickup trucks for hauling crews

one ton trucks with generators

three- and four–ton drill trucks for digging holes

pole trucks with crane (similar to logging trucks)

radial-boom derricks for pulling out poles

wire-winder trucks

skidder or D6 Crawlers for pulling wire

cement truck for pouring foundation

three-ton picker trucks for framing

Nodwells or LGP crawlers that may be used to pull wire or drag poles, depending on ground conditions

3.2 WASTE DISPOSAL

11. Salvaged poles will be stored on the right-of way until they can be transported to Ryley Facility, a secure landfill that is equipped to deal with hazardous wastes, and therefore capable of disposing of the poles without risk to the environment. Storage of wood poles for reuse will be at ATCO’s material yards which are designed to prevent chemical leaching by having ground surfaces characterized by clay materials that control water infiltration.

12. ATCO Electric will ensure that during the course of the project no fuel, lubricating fluids,

hydraulic fluids, antifreeze, herbicides, biocides, or other chemicals are released on the ground or into any watercourse. Construction sites will have spill kits on-site. In the event of a spill, the spilled contents will be cleaned up to the satisfaction of the landowner, municipality, or appropriate regulator.

13. Construction waste will be continuously collected and disposed of at an approved facility to

avoid the attraction of wildlife. Waste containers will accompany each working unit. All garbage will be stored in wildlife-proof containers. Personnel will be made aware of proper disposal methods for cigarette butts and other hot or burning materials. Each working unit will have fire-fighting equipment on hand as regulated by the Forest and Prairie Protection Regulations.


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3.3 OPERATION AND MAINTENANCE

14. Continued operation and maintenance of the line will require access to the structures and conductors. Access for work on the line will be from the acquired right-of-way, using existing access where available.

15. Minimal clearing of trees will be required along the proposed route. Vegetation management

and removal, where required to control the growth of vegetation along the line will be done in accordance with the standards of practice of the Industrial Vegetation Management Association of Alberta. Brushing activities will be kept to a minimum and will only be carried out during appropriate time periods.

16. Minimum right-of-way widths are described in Section 2.1 of the application text

(Attachment 1). Additional right-of-way width for tree clearing will also be required based on tree height. Standard right-of-way widths have been devised for areas having tree growth of varying heights to ensure that the vegetation does not pose a problem. The clearing standards for tree free zones are based on tree heights in relation to the location of the nearest conductor at maximum sag. Typical tree-free requirements are shown in Table 1.


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TABLE 1: TYPICAL TREE CLEARING CHART FOR 144 kV TRANSMISSION LINE

Width of Clearing from Centre Line

TREE HEIGHT

(m)

CLEARING WIDTH (m)

1 8.5 2 9.5 3 11.5 4 12.5 5 13.5

6 14.0 7 15.0 8 16.0 9 17.0

10 17.5

11 18.5 12 19.5 13 20.0 14 21.0 15 22.0

16 22.5 17 23.5 18 24.5 19 25.5 20 26.5

21 27.5 22 28.0 23 29.0 24 30.0 25 31.0

26 32.0 27 32.5 28 33.5 29 34.5 30 35.5

Chart includes both conifers and hardwoods, and is designed for a 10 year tree-free cycle.


Page 6

4.0 LANDSCAPE

17. The project study area is located within the Parkland Natural Region of Alberta. Much of the Region, including the area of the proposed route, has been converted to agriculture and extensive cultivation has disturbed significant portions of the native vegetation; however, some sensitive habitat still remains, including wetlands and scrublands.

4.1 ENVIRONMENTALLY SIGNIFICANT AREAS

18. Environmentally Significant Areas (ESA) are natural areas that have been identified as significant and worthy of protection. They are defined by their important and/or unique environmental values that are vital to the long-term maintenance of bio-diversity and ecological processes and services within a region. The province of Alberta has identified and mapped all of its established ESA; ATCO Electric has confirmed that the project area does not overlap any of these areas.

4.2 WETLANDS

19. Wetlands are important on both local and regional scales, where they act as water purifiers, in-stream flow regulators, and habitat. Many species of plants and animals rely on wetlands directly for habitat and refuge; wetlands also issue indirect benefits to ecosystems further downstream. The Alberta Government, in recognition of the importance and delicate nature of wetlands, has required that clearance be granted under the Water Act for any activity that may potentially impact wetlands or other water bodies.

20. Field observations and a desktop study suggest that low-lying areas of the proposed route

have a high probability of containing water bodies, wetlands, or sensitive ecosystems that are of importance to the ecological integrity of the surrounding region. Preconstruction field surveys along the proposed right-of-way will confirm the location of any sensitive wetland-type of habitat, including areas with open water, wetlands, and other sensitive ecosystems. Information from the survey and from consultation with the landowner and the relevant regulators (i.e., ASRD and AENV) will be used to develop appropriate mitigation plans for construction in and around sensitive areas.

21. Avoidance of wetlands and waterbodies will be the primary mitigation employed during

construction and operation of the transmission projects. Structures will be located so as to avoid wetlands and waterbodies wherever possible. If construction activities are required in the vicinity of wetlands, measures will be taken to limit the potential for spills or sedimentation to reach the wetlands. Where required, an approval will be obtained from the appropriate regulators before construction activity begins. Approval will be sought from AENV under the Water Act prior to construction for any impacts to wetlands or water bodies impacted by this transmission project.


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4.3 WATER BODIES

22. There are no permanent water bodies, creeks, rivers, or riparian areas to be crossed by the proposed routes; however, the proposed route does cross a seasonal drainage ditch and is in proximity to a permanent wetland. ATCO Electric will ensure that the planned timing of construction will minimize the potential impact on any unmapped or seasonal drainages that may be present at the time of construction.

5.0 WILDLIFE

5.1 POTENTIAL IMPACTS

23. The Heisler Transmission Project has the potential to impact wildlife in three possible ways:

increased mortality (through direct collision with facilities, destruction of nests, etc.)

increased avoidance behaviour (through wildlife deterring from increased human presence during construction)

alteration or destruction of habitat (e.g., the brushing of treed areas that removes nesting and perching sites)

24. The project does not overlap any ASRD-designated areas of concern for wildlife; however,

several species at risk have been listed within the regional area and have the potential to be impacted by this project. Wildlife species with management requirements are identified in such provincial and federal legislation as Alberta’s Wildlife Act, the Species at Risk Act (SARA), and the Committee on the Status of Endangered Wildlife in Canada (COSEWIC). A list of species with special conservation status that have the potential to occur in the Parkland Natural Region of Alberta was generated and is included in Table 2.

25. A more specific information search was conducted through the ASRD Fish and Wildlife

Management System (FWMIS) for a 9 km buffer around the centre of the project study area; this search identified five species that may be present close to the project area [see Table 3]. However, when the search was conducted using a 6 km buffer, no species were identified.

26. Preconstruction surveys for wildlife and rare plants are planned for this project and will

confirm whether sensitive species are present along the proposed route. While many of the species are migratory, several of the more common species are residents (e.g., Pronghorn Antelope) and may be present during the proposed construction period.

5.2 MITIGATION

27. To eliminate or minimize the impacts of the project, ATCO Electric will implement several strategies:

construction personnel will be not be permitted to have firearms or dogs on the right-of-way


Page 8

construction personnel will not be permitted recreational ATV / snowmobile use on the right-of-way

only the minimum right-of-way width necessary for safe access and operation will be brushed

construction personnel will be instructed not to harass nor feed any wildlife 28. Upon the discovery of any species with special conservation status, further strategies will be

developed in coordination with ASRD to ensure that they are not adversely affected. Work carried out in close proximity to any discovered species with special conservation status will be suspended until permission to continue is granted by the appropriate authorities.

TABLE 2: SPECIES AT RISK IN THE PARKLAND NATURAL REGION

CATEGORY OF SPECIES

ENDANGERED SPECIES THREATENED SPECIES SPECIAL CONCERN

SPECIES

BIRDS BURROWING OWL

(Athene cunicularia)

BOBOLINK

(Dolichonyx oryzivorus)

SHORT-EARED OWL (Asio flammeus)

PIPING PLOVER

(Charadrius melodus circumcinctus)

COMMON NIGHTHAWK

(Chordeiles minor)

LONG-BILLED CURLEW

(Numenius americanus)

WHOOPING CRANE

(Grus Americana)

OLIVE-SIDED FLYCATCHER

(Contopus cooperi)

HORNED GREBE

(Podiceps auritus)

SPRAGUE’S PIPIT

(Anthus spragueii)

PEREGRINE FALCON

(Falco peregrinus anatum)

RUSTY BLACKBIRD

(Charadrius melodus circumcinctus)

YELLOW RAIL

(Coturnicops noveboracensis)

MAMMALS None None None

REPTILES None None

NORTHERN LEOPARD FROG

(Rana pipiens)

WESTERN TOAD

(Bufo boreas)


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TABLE 3: WILDLIFE SPECIES OF CONCERN POSSIBLY PRESENT WITHIN 9 KM OF THE

HEISLER PROJECT STUDY AREA CENTRE (FWMIS RESULTS)

SPECIES MIGRATORY

STATUS OF ALBERTA WILD

SPECIES (2010)

SENSITIVE LOCATION

WITHIN PARKLAND

SETBACK FOR HIGH DISTURBANCE /

SPECIAL CONSIDERATIONS

REQUIRED

NORTHERN HARRIER

(Circus cyaneus) Yes Sensitive Not specified

Preservation of wetlands is important for survival

PRONGHORN (Antilocapra Americana)

No Sensitive Winter range 2 km exclusion zone, dependent on winter

severity

LONG-TAILED WEASEL

(Mustela frenata) No May be at risk Dens Not specified

March 15th– June 15th

500 m

SHARP-TAILED GROUSE

(Tympanuchus phasianellus)

No Sensitive Lek June 16th–March

14th 100 m

NORTHERN PINTAIL

(Anas Acuta) Yes Sensitive Wetlands

Preservation of wetlands is important for survival

Source: Recommended Land Use Guidelines for Protection of Selected Wildlife Species and Habitat within Grassland and Parkland Natural Regions of Alberta, ASRD, Fish and Wildlife Division, 2010;

Status of Alberta Wild Species, ASRD, 2010

6.0 VEGETATION

6.1 POTENTIAL IMPACTS

29. This transmission project has the potential to damage vegetation in the following ways:

destruction of individual plants through crushing by vehicles or by clearing brush within the right-of-way (for safety)

compacting of the soil and consequent impediment to plant recovery, root development, and water absorption

introduction of weeds

introduction of toxic materials through spills 30. The Alberta Conservation Information Management System (ACIMS) has identified that

there were no Elements of Occurrence for rare or endangered plants within 850 metres of the project area. The majority of the native parkland ecosystem in the Heisler area has been altered or removed by agricultural development over the last 100 years.


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31. Preconstruction surveys for rare or endangered plants are planned for this project and will confirm whether sensitive species are present along the proposed route. During this survey any occurrences of rare or endangered plants will be recorded and reported to the ACIMS.

6.2 MITIGATION

32. To mitigate the risk of damage to local vegetation, ATCO Electric proposes to undertake the following:

ensure that all machinery is sent to the work site in clean (weed-free) condition

ensure that all machinery is kept in good repair in order to minimize leaks or spills of toxic or hazardous substances

report and clean-up any toxic or hazardous spills to the satisfaction of the landowner and the relevant agencies

33. A protection plan will be designed in collaboration with environmental regulators to ensure

that plants or native prairie assemblages that are identified in the pre-construction survey are protected from any undue or adverse impacts.

34. With the proposed preconstruction survey and mitigation measures, the Heisler

Transmission Project poses a low risk to vegetation along the right-of-way.

7.0 SOILS, AGRICULTURE AND OTHER IMPACTS

7.1 SOILS AND AGRICULTURE

35. The Canadian Land Inventory (CLI) Capability classification of soils indicates that the soil impacted by the proposed lines is predominately Class 3, along with some Class 2. Class 2 soils have moderate limitations to agriculture (Class 3 is moderately severe); only a restricted range of crops may be grown with moderate conservation practices required.

36. The current land use along the proposed route is primarily cereal cropping along with some

pasture. 37. Construction is scheduled to occur during the crop growing or harvest season. Efforts will be

made to avoid damage to crops and pasture where possible, and construction will be limited to within the acquired right-of-ways and existing road allowances. All construction equipment will be sent to the right-of-way in clean condition in order to minimize the introduction of crop diseases or noxious weeds. Site access plans will be developed to ensure that no vehicles traverse soils where rutting could occur, and that low-ground pressure vehicles are used where appropriate.

38. Mitigative measures to prevent the spread of agricultural disease are managed by ATCO

Electric’s Best Management Practice – Crop Disease Protection (based on Alberta’s


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Clubroot Management Plan). ATCO Electric will incorporate municipal district guidelines for the control of agricultural disease where required.

39. Where necessary, ATCO Electric will properly brace fences prior to cutting. Fences will be

returned to pre-construction condition or as agreed upon by the landowners; gates will be closed after use. Compensation for crop damage associated with construction activities will be provided.

7.2 LANDSCAPE, AESTHETICS AND RESIDENTIAL CONSIDERATIONS

40. The topography in the local project area is generally flat-to-gently-rolling with cultivated land use. No landowners have identified visual concerns; however, if requested, ATCO Electric is committed to work with affected landowners during the line design and construction stages. Much of the proposed line would follow an existing county road and distribution line, which will be understrung onto the transmission structures in order to minimize aesthetic impacts in the area. The proposed facilities will not impact local scenic viewpoints; there are no areas identified that would require tree planting or landscaping. The nearest residence is located approximately 82 m from the proposed facilities (across Township Road 424).

7.3 HISTORICAL RESOURCES AND SENSITIVE AREAS

41. ATCO Electric has sought direction from Alberta Culture and Community Spirit (ACCS) on the need for a Historic Resource Impact Assessment (HRIA) for this project. ACCS has advised that an HRIA is not required and has issued Historical Resource Act clearance. In the event that ATCO Electric identifies any potential historic resources, prior to or during construction, ATCO Electric will halt construction activities until clearance has been granted by ACCS.

7.4 NOISE AND TRAFFIC

42. Any significant noise or traffic is generally limited to the initial construction period, when larger trucks and equipment are required for clearing, hauling, and construction. Longer-term traffic is generally limited to less frequent traffic and lighter equipment. During continuous operation, transmission facilities are not expected to be audible at a distance exceeding 200 m from the right-of-way or substation site. There will be no appreciable noise increase from the proposed 144 kV facilities relative to the local agricultural and oil field activities.

43. ATCO Electric commissioned a Noise Impact Assessment (NIA) for the alterations to the

Heisler Substation 764S site [see Attachment 9]. The predicted results indicate the final substation will comply with requirements of AUC Rule 012.

7.5 ELECTRICAL EFFECTS

44. Where necessary, metal fences, buildings, and structures will be grounded by ATCO Electric in order to minimize induced voltages. Minimum clearance required between all transmission facilities and buildings will be in accordance with the Safety Codes Act and regulations.


Page 12

45. ATCO Electric will work with the pipeline operators to ensure compliance with the Safety

Codes Act, Pipeline Act, and other applicable regulations for all pipeline crossings. ATCO Electric will ensure that applicable regulations for setbacks are followed.

46. The transmission facilities will be constructed and maintained in such a manner as to keep

radio and television interference levels within limits acceptable to Industry Canada, the federal government department that regulates communications.

7.6 SOCIO-ECONOMIC CONSIDERATIONS

47. The proposed alterations will not have a significant socio-economic impact relative to the various oil- and gas–related activities in the area. As an established centre, Forestburg has services and amenities that are equipped to deal with construction activities of this magnitude.

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² Heisler TransmissionProject

REGIONAL MAPATTACHMENT 4

-A-01RS-7LA7011:200,000Cartography By: TV Approved By: Nathan Jones November 2011ATCO Planner: Nathan Jones EBA Project Manager: Brent McMillin

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Cartography By: BA Approved By: Nathan Jones November 2011ATCO Planner: Nathan Jones EBA Project Manager: Brent McMillin

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NOTES: REFERENCE MAPATTACHMENT 4

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Cartography By: BA Approved By: Nathan Jones November 2011ATCO Planner: Nathan Jones EBA Project Manager: Brent McMillin


PROPOSED ROUTE MOSAICATTACHMENT 6

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Cartography By: BA Approved By: Nathan Jones November 2011ATCO Planner: Nathan Jones EBA Project Manager: Brent McMillin1:15,000

² Heisler TransmissionProject

SOIL CAPABILITY MAP FOR AGRICULTUREATTACHMENT 8

-A-08RS-7LA701

SOIL CAPABILITY FOR AGRICULTURE (CLI DATA)1. Soils in this class have no significant limitations for crops.2. Soils in this class have moderate limitations that restrict the range of crops or require moderate conservation practices.3. Soils in this class have moderately severe limitations that restrict the range of crops or require special conservation practices.4. Soils in this class have severe limitations that restrict the range of crops or require special conservation practices.5. Soils in this class have very severe limitations that restrict their capability in producing perennial forage crops, and improvement practices are feasible.6. Soils in this class are capable of only producing perennial forage crops, and improvement practices are not feasible.7. Soils in this class have no capacity for arable culture or permanent pasture.O. Organic Soils (not placed in capability classes).W. Water


NOTES:

August 31, 2011 Project

767600 Rev. 0

LSD 4-30-42-15 W4M ATCO Electric

Heisler 764S Substation

Noise Impact Assessment

ATCO Electric Project 767600 Heisler 764S, Rev. 0 August 31, 2011

Page i

TABLE OF CONTENTS

1. NOISE IMPACT ASSESSMENT SUMMARY ................................................................................ 1

2. SITE DESCRIPTION & RESIDENCE LOCATION...........................................................................2

3. SOUND POWER LEVELS.............................................................................................................3

4. NOISE PROPAGATION MODELING........................................................................................... 4

5. RESULTS .....................................................................................................................................5

6. CONCLUSIONS .......................................................................................................................... 8

7. DISCLAIMER .............................................................................................................................. 9

Appendix A GLOSSARY ............................................................................................................. 10

Appendix B FIGURES..................................................................................................................11

Appendix C AUC RULE 012 KEY POINTS .................................................................................. 12

Appendix D PERMISSIBLE SOUND LEVEL DETERMINATION ................................................. 13

Appendix E ACOUSTICAL PRACTIONER’S INFORMATION..................................................... 14


Page ii

TABLES AND FIGURES

Table 1: Calculated Sound Pressure Levels from Proposed ATCO Facility................................... 1

Table 2: Low‐Frequency Noise, Calculated Facility dBC – dBA Levels.......................................... 1

Table 3: Noise Source Sound Power Levels...................................................................................3

Table 4: Modeling Parameters ...................................................................................................... 4

Table 5: Calculated Sound Pressure Levels from Proposed ATCO Facility ..................................5

Table 6: Low‐Frequency Noise, Calculated Facility dBC – dBA Levels .........................................5

Table 7: Ranking of Noise Sources at R1 ....................................................................................... 6

Table 8: Ranking of Noise Sources at R2 ...................................................................................... 6

Figure 1: Aerial Image of Study Area..............................................................................................2

Figure 2: Noise Contours ................................................................................................................7

Figure 3: Aerial Image of Study Area ............................................................................................11


Page 1

1. NOISE IMPACT ASSESSMENT SUMMARY

ATCO Structures and Logistics (ASL) has completed a Noise Impact Assessment (NIA) as requested by ATCO Electric for the proposed Heisler 764S substation located at LSD 4‐30‐42‐15 W4M.

The major noise sources associated with the proposed substation will be one 25/33 MVA 144‐72/25 kV POD transformer, one 6/8/10 MVA 72/25 kV POD transformer and one 25/33 MVA 25 kV voltage regulator. Sound power levels for the proposed equipment were input into a computer model to provide the overall facility sound level, and to generate a noise contour map that indicates overall sound levels from the facility to the receptors.

The area surrounding the proposed site is generally flat and largely agricultural. The nearest and most‐impacted residential receptor is located 450 m east‐southeast of the proposed substation fenceline. ASL has calculated the sound levels from the substation at this receptor as shown below in Table 1 and Table 2.

Table 1: Calculated Sound Pressure Levels from Proposed ATCO Facility

Receptor Location

Calculated Facility Sound

Level (Leq, dBA)

Ambient Sound Level* (dBA)

Total Calculated Sound Level at

Receptor (Leq, dBA)

Determined AUC PSL**

(Leq, dBA)

R1 450 m East‐Southeast of

Substation 35 35 38 40

*In Rule 012 (2011), the average rural ambient sound level in Alberta is deemed 5 dB less than the BSL. ** The determination of the PSL is presented in Appendix D.

Table 2: Low‐Frequency Noise, Calculated Facility dBC – dBA Levels

Receptor Location Calculated Facility

Sound Level (Leq, dBC) Calculated Facility

Sound Level (Leq, dBA) Facility

dBC – dBA Level (dB)


Substation 44 35 9

The calculated results indicate that the ATCO Electric Heisler 764S substation will comply with the PSL at all receptors. The “dBC ‐ dBA” value is less than 20 dB at the critical receptor indicating a low frequency noise issue is not likely to occur.


Page 2

2. SITE DESCRIPTION & RESIDENCE LOCATION

The proposed ATCO Electric Heisler substation is located at LSD 4‐30‐42‐15 W4M which is roughly 4 km southeast of the town of Heisler, Alberta.

All equipment on the existing ATCO Electric Heisler substation is being removed and the substation is being relocated approximately 60 m south of the existing substation fenceline. The proposed equipment that will be installed in the new substation location is:

• One (1) 25/33 MVA 144‐72/25 kV POD transformer (701T);

• One (1) 6/8/10 MVA 72/25 kV POD transformer (602T);

• One 25/33 MVA 25 kV voltage regulator (501VR);

• Associated circuit breakers, transmission equipment and communication equipment.

The area surrounding the Heisler substation is generally flat and primarily used for agriculture. There are two residential receptors (dwellings) within 1.5 km of the facility fence line. ASL has evaluated the noise levels at these receptors as shown below in the aerial image. An expansive aerial view of the study area is presented in Figure 3 of Appendix B, indicating the location of the ATCO Electric facility, the neighboring receptors and the surrounding area. There are no identified energy‐related facilities in the study area.

Figure 1: Aerial Image of Study Area

R1 R2


Page 3

3. SOUND POWER LEVELS

Sound power levels for the proposed noise producing equipment were calculated using data within the ASL noise database. ASL has built up its database from extensive in‐situ sound level measurements of transformers and other applicable substation equipment throughout North America.

Calculations were performed for each identified source in full octave bands between 31.5 Hz and 8000 Hz. Applicable international standards used for the calculation of sound power levels include but are not limited to the following:

• IEEE Std. C57.12.90‐2006 Standard Test Code for Liquid‐Immersed Distribution, Power, and Regulating Transformers

• ANSI S12.12‐1992 Engineering Method for the Determination of Sound Power Levels of Noise Sources

• ANSI S12.36‐1990 Survey Methods for the Determination of Sound Power Levels of Noise Sources

• ISO 3744:1994 Determination of Sound Power Levels of Noise Sources using Sound Pressure ‐ Engineering Method in an Essentially Free Field over a Reflecting Plane

Measured sound levels typically provide more accurate results than those obtained from manufacturers’ specifications as they represent operation in an actual installation. Calculated sound power levels of the equipment for the proposed ATCO Electric substation are presented in Table 3. The stated levels for the equipment represent operation at full load with all cooling fans in operation.

Table 3: Noise Source Sound Power Levels

Octave Band Center Frequency, Hz No. Noise Source

31.5 63 125 250 500 1000 2000 4000 8000 dBA

1 Transformer 701T 91 93 99 97 99 96 90 88 78 100

2 Transformer 602T 79 86 109 92 91 85 79 74 65 95

3 Voltage Regulator 501VR 83 79 100 87 89 89 83 76 66 93


Page 4

4. NOISE PROPAGATION MODELING

The acoustical modeling for this project was conducted using the Cadna/A computer software program from DataKustik GmbH. The meteorological conditions used were downwind conditions which favor the transmission of sound from the facilities to the receptors. The inputs for the model are presented in Table 4.

Table 4: Modeling Parameters

Item Modeling Input and Description

Terrain of Site Area Flat

Temperature 10°C

Relative Humidity 70%

Wind 3.6 to 18 km/h, from facility to receptor*

Ground Attenuation 0.5

Number of Sound Reflections 2

Receptor Height 1.5 m above ground

Operation Condition Full load with cooling fans turned on

*Propagation calculations under the ISO 9613 standard incorporate the effects of downwind propagation (from facility to receptor) with wind speeds of 1 to 5 m/s (3.6 to 18 km/hr) measured at a height of 3 to 11 m above the ground. This encompasses the acceptable summertime modeling conditions of AUC Rule 012 which require modeling a wind speed of 5.0 to 7.5 km/hr from the facility to the receptor.


Page 5

5. RESULTS

Table 5 and Table 6 below present the calculated facility noise levels from the Heisler substation at each receptor. A colour noise contour map is presented in Figure 2 below, illustrating the overall calculated sound levels at varying distances from the ATCO Electric substation.

Table 5: Calculated Sound Pressure Levels from Proposed ATCO Facility

Receptor Location

Calculated Facility Sound

Level (Leq, dBA)

Ambient Sound Level* (dBA)

Total Calculated Sound Level at

Receptor (Leq, dBA)

Determined AUC PSL**

(Leq, dBA)





*In Rule 012 (2011), the average rural ambient sound level in Alberta is deemed 5 dB less than the BSL. ** The determination of the PSL is presented in Appendix D.

Table 6: Low‐Frequency Noise, Calculated Facility dBC – dBA Levels

Receptor Location Calculated Facility

Sound Level (Leq, dBC) Calculated Facility

Sound Level (Leq, dBA) Facility

dBC – dBA Level (dB)


Substation 44 35 9


Substation 37 27 10


Page 6

Table 7 and Table 8 below present the noise source rankings for R1 and R2, order ranked for each major noise source.

Table 7: Ranking of Noise Sources at R1

Rank Noise Source Calculated Sound Level,

dBA

1 Transformer 701T 34


3 Voltage Regulator 501VR 26

Overall 35

Table 8: Ranking of Noise Sources at R2

Rank Noise Source Calculated Sound Level,

dBA



3 Voltage Regulator 501VR 17

Overall 27


Page 7

Figure 2: Noise Contours


Page 8

6. CONCLUSIONS

The calculated results indicate that the proposed ATCO Electric Heisler 764S substation will comply with the PSL at all receptors. The “dBC ‐ dBA” values are less than 20 dB at each receptor indicating a low frequency noise issue is not likely to occur.


Page 9

7. DISCLAIMER

This “Noise Impact Assessment (NIA)”, which is reported in the preceding pages, has been prepared in response to a specific request for service from the Client to whom it is addressed. The information contained in this “NIA” is not intended for the use of, nor is it intended to be relied upon, by any person, firm, or corporation other than the Client to whom it is addressed, with the exception of the applicable regulating authority to whom this document may be submitted for planning permission purposes. We deny any liability whatsoever to other parties who may obtain access to the information contained in this “NIA” for any damages or injury suffered by such third parties arising from the use of this “NIA” by them without the express prior written permission from ASL and its Client who has commissioned this “NIA”.

ATCO STRUCTURES AND LOGISTICS

Report Prepared by:

Tze Yuin Tay, B.Sc. Acoustician

Reviewed by:

Arthur Küpper, P.Eng., INCE Acoustical Engineer


Page 10

Appendix A GLOSSARY

Ambient Sound Level (ASL) – The sound level that is a composite of different airborne sounds from many sources far away from and near the point of measurement. The ASL does not include any energy‐related industrial component and must be measured without it.

A‐weighted Sound Level, dBA – the sound level as measured on a sound level meter using a setting that emphasizes the middle frequency components, similar to the frequency response of the human ear.

Background Noise ‐ The total noise from all sources that currently exist in an area.. Background noise includes sounds from the energy industry, as well as other industrial noise not subject to this rule, transportation sources, animals, and nature.

Basic Sound Level (BSL) – The nighttime A‐weighted Leq sound level commonly observed to occur in the designated land‐use categories with industrial presence. The BSL is assumed to be 5 dBA above the ASL.

Frequency – the number of cycles per unit interval of time. Units Hz (Hertz).

C‐weighted Sound Level, dBC – the C‐weighting approximates the sensitivity of human hearing at industrial noise levels (above about 85 dBA). The C‐weighted sound level is more sensitive to sounds at low frequencies than the A‐weighted sound level, and is sometimes used to assess the low‐frequency content of complex sound environments.

dB (Decibel) – the standard unit of measure, in acoustics, for level or level difference. The decibel scale is based on the ratio 101/10; multiplying a power‐like quantity (such as sound power or mean square) by this factor increases its level by 1 decibel. If a power‐like quantity is increased by a factor 10n/10, its level goes up by n decibels. Unit symbol for dB.

Equivalent Sound Level (Leq) – the prime descriptor used in assessing most types of sounds heard in a community. The Leq is an average of sounds measured over time. It is strongly influenced by occasional loud, intrusive noises.

Permissible Sound Level (PSL) ‐ The maximum daytime/nighttime sound level that a facility must not exceed at a point 15 m from the nearest or most impacted dwelling unit. The PSL is the sum of the BSL, daytime adjustment, Class A adjustment, and Class B adjustment.

Sound Power Level (PWL, LW) – the level of sound power expressed in decibels relative to a stated reference value. The quantity Lw is defined by Lw = 10 Log10(W/Wref). Here Wref is the reference sound power. Units dB re 1pW.

Sound Pressure Level (SPL, Lp) – or sound pressure‐squared level, at a given point the quantity Lp defined by Lp = 10 Log10(Prms/Pref)2 = 20 Log10(Prms/Pref). Here Prms is the root mean square sound pressure, and Pref is the reference rms sound pressure, 20µPa. Units dB re 20µPa.


Page 11

Appendix B FIGURES

Figure 3: Aerial Image of Study Area


Page 12

Appendix C AUC RULE 012 KEY POINTS

Environmental noise from energy industry facilities in Alberta is regulated by the AUC, as described in Rule 012. Rule 012 has adopted the A‐weighted energy equivalent sound levels (Leq) as the sound pressure level criterion for a receptor location. Rule 012 requires a Noise Impact Assessment (NIA) be completed for any new permanent facility or for modifications to existing permanent facilities where there is a reasonable expectation of a continuous noise source.

Rule 012 considers noise from a receptor viewpoint, whereby noise emitted by energy industry facilities is specified at defined receptor locations, including residences. It applies to all facilities under the AUC jurisdiction or where the AUC will issue or has issued a permit to operate. New facilities planned for remote areas, where there are no impacted dwellings, must be designed to meet a target sound level of 40 dBA Leq at a distance of 1500 m from the facility.

The PSLs are derived from information regarding the area population density, proximity to heavily traveled transportation routes including motor vehicle routes, rail lines and aircraft flyways and other specified adjustments. While actual compliance to the PSLs can only be determined by performing a valid comprehensive sound survey, the AUC expects the sound level for new facilities to meet the PSLs at the design phase through the preparation of a NIA.

Rule 012 includes a discussion on low frequency noise, which states that “Low frequency noise (LFN) may be a problem in some situations where the dBA value is satisfactory but the concern is a dominant or resonant low frequency that creates a great deal of annoyance. Provided that data are available, weighted dBC minus dBA determinations should be made in the noise modeling of new plants or plant expansions to minimize the potential for LFN concerns.” A low frequency noise complaint condition may exist when:

• “the isolated (i.e., nonfacility noise, such as wind noise, has been removed) time‐weighted average dBC – dBA value for the measured day or night time period is equal to or greater than 20 dB, and

• a clear tonal component exists at a frequency below 250 Hz.”

Due to noise data and prediction method limitations the following restrictions apply to the calculated “dBC minus dBA” value:

• The dBC and dBA values can only be assessed in the full octave bands from 31.5 Hz to 8 kHz inclusive (based on ISO 9613).

• Due to the application of ISO 9613, noise prediction methods (including Cadna/A), only consider full octave band analysis – prediction in 1/3 octave band levels is not available. Therefore, the analysis of tonal components can only be assessed at the post‐construction stage through measurement.


Page 13

Appendix D PERMISSIBLE SOUND LEVEL DETERMINATION

Receptor R1 & R2 ATCO Electric Heisler 764S LSD 4‐30‐42‐15 W4M

AUC Rule 012

Dwelling Unit Density per ¼ Section of Land Proximity to

Transportation* 1 – 8 Dwellings

9 – 160 Dwellings

>160 Dwellings

Nighttime (22:00‐07:00)

Daytime (07:00‐22:00)

Category 1 40 43 46 40 50**** Category 2 45 48 51

Basic Nighttime Sound Level

Category 3 50 53 56

Class Reason for Adjustment Value

(dBA Leq)

A1 Seasonal Adjustment (1 Nov – 31 Mar)

+5

Class A Adjustments**

A2

Ambient Monitoring Adjustment

‐10 to +10

Total Class A Adjustments 0 0

Class Duration of Activity Value

(dBA Leq)

B1 1 day +15 B2 1 week +10 B3 < or = to 2 months +5

Class B Adjustments***

B4 > 2 months 0

Class B Adjustment 0 0

Permissible Sound Level (dBA) 40 50

*Proximity to Transportation Category Definitions: Category 1 ‐ Dwelling units more than 500m from heavily traveled roads and/or rail lines and not subject to frequent aircraft flyovers; Category 2 ‐ Dwelling units more than 30m but less than 500m from heavily traveled roads and/or rail lines and not subject to frequent aircraft flyovers; and Category 3 ‐ Dwelling units less than 30m from heavily traveled roads and/or rail lines and subject to frequent aircraft flyovers.

**Class A Adjustment = Sum of A1 and A2 (as applicable), but not to exceed a maximum of 10 dBA Leq. ***Class B Adjustment = One only of B1, B2, B3 or B4. ****Daytime Adjustment = 10 dB.


Page 14

Appendix E ACOUSTICAL PRACTIONER’S INFORMATION

Tze Yuin Tay is an Acoustician with the Noise Management division of ATCO Structures and Logistics and is based in Calgary, AB. Tze has been with the Noise Management division for 3 years and her responsibilities include noise prediction modeling, noise surveys, noise control design and technical report writing. To date, Tze has completed noise impact assessments for oil and gas and energy‐related facilities in Alberta, British Columbia, Saskatchewan and various states in the US. Tze received her bachelor’s degree in Audio, Video and Broadcast Technology from the University of Salford in Salford, England.

February 2011

Heisler Transmission Project

Why are you receiving this project information package?

New transmission facilities are needed in Central East Alberta (Heisler area). ATCO Electric has direction from the Alberta Electric System Operator to assess site and route options for these upgrades. We have prepared this summary for landowners, occupants, agencies and interested parties located near the proposed power transmission facilities. This package will provide you with important project information and will outline our public consultation process. We invite any comments, questions or concerns you may have. Please refer to page six for our contact information and details.

Included in This Package:

• Project Information brochure

• Reply Form

• Open House invitation

• Alberta Electric System Operator document Transmission Reinforcement in the Central East (Cold Lake, Vegreville and Provost) Area

• ATCO Electric Information Sheets

• Alberta Utilities Commission brochure Public Involvement in Needs or Facilities Applications

• Maps and drawings

Project Overview The Heisler Transmission Project is needed to meet growing demand for electricity from oil sands development and pipelines and to interconnect proposed gas-fired electricity generation as well as wind farms. Please see the Alberta Electric System Operator (AESO) document entitled Transmission Reinforcement in the Central East (Cold Lake, Vegreville and Provost) Area. If approved, the project will involve upgrades to the existing Heisler substation and constructing about three kilometres of new transmission line from the Heisler substation to an existing transmission line.

Heisler Transmission Project 1

Project Need and Details When upgrades to Alberta’s electrical system are needed, they are identified by a not-for-profit organization with a public interest mandate called the Alberta Electric System Operator (AESO). The AESO has received applications to interconnect over 500 megawatts of wind power and proposed gas-fired electricity generation in Central East Alberta. Demand for electricity in the Cold Lake and Wainwright areas is expected to increase. The existing transmission system in this region is operating at capacity and parts of the system are subject to low voltages under certain conditions. The Heisler Transmission Project is part of the system reinforcement that is needed to meet increasing demand for electricity and interconnect new generation. The AESO has described the need for these facilities in the enclosed document: Transmission Reinforcement in the Central East (Cold Lake, Vegreville and Provost) Area.

Heisler Substation The Heisler substation (called 764S) is located on SW-30-42-15 W4M, southeast of the town of Heisler, in Flagstaff County. If approved, the substation will be upgraded with the installation of one 144/72/25 kV 25/33 MVA transformer, one 72/25 kV 6/8/10 MVA transformer, one 25 kV voltage regulator, one 144 kV circuit breaker, one 72 kV circuit breaker, one new control building, one 26 metre tall self-supporting steel lattice telecommunication tower and related electrical and communication equipment. To accommodate these changes, an existing 144/72/25 kV transformer and 25 kV voltage regulator will be removed and the fence will be expanded to encompass an additional area of approximately 7,000m²

Typical Substation

2 Heisler Transmission Project

Typical Single-Circuit 144 kV “Davit Arm” Structure

Approximate Dimensions

Height………20m Max. Width……6m Distance between structures….100-180m

144 kV Transmission Line If approved, approximately three kilometres of new 144 kV single-circuit transmission line (to be called 7LA701) will be built to connect the Heisler substation to the existing transmission line 7L701. The new line will consist of three conductor wires plus one overhead shield wire strung on steel or wood pole structures. The typical structure will be a single-pole “Davit Arm” design, about 20 m tall. The typical distance between poles will be 100 m to 180 m. Non-typical structures with taller or additional poles, anchors and/or guy wires are required where the line ends or bends, at corners, and to maneuver around and over obstacles. In all cases, minimum clearance will meet or exceed the requirements of provincial safety regulations.


Typical Right-of-Way Transmission lines are located in corridors that have been cleared of brush and other obstacles. These are called a ‘right-of-way’. Right-of-ways must have a minimum width to ensure safety and allow for construction and ongoing access for maintenance purposes. The width of the right-of-way, and the position of transmission structures within it, will depend on the type of structure that is used. The typical right-of-way that relates to this project is 18 metres and is shown below. Details may change with final design and location.


Route and Site Selection We have identified preliminary route options for the new single-circuit 144 kV transmission line. Preliminary options are shown on the enclosed map. We have selected route options that:

• Avoid homes and minimize impacts on residences

• Follow property boundaries wherever possible to provide access and to avoid impacts to agriculture

• Minimize impacts on built-up areas, highways, agricultural, oil and gas operations and communication facilities

• Minimize impacts to environmentally sensitive areas such as watercourses, wet or steep areas, wildlife habitat and other sensitive areas such as designated historical sites

Other options for transmission line routes may be considered if identified through our consultation process. The preferred transmission line route will be identified after we have considered feedback and concerns.

Facilities Application Process Once the preferred transmission line route has been identified, ATCO Electric will submit a Facilities Application to the Alberta Utilities Commission (AUC) to obtain approval for the construction and operation of the proposed transmission facilities. For more information about how you can participate in the process, please refer to the enclosed AUC brochure entitled Public Involvement in Needs or Facilities Applications.


Proposed Timeline* February 2011 – October 2011

Consultation with landowners and agencies.

November 2011

Selection of preferred route and submission of the Facilities Application to the Alberta Utilities Commission (AUC).

November 2012

If approval is granted by the AUC, construction will commence.

October 2013

Facilities completed and operating.

*Timing may be adjusted to reflect final plans.

ATCO Electric Albertans count on us for the safe, reliable and cost-effective delivery of electricity to their homes, farms and businesses. We have delivered electricity to Albertans for more than 80 years. Headquartered in Edmonton, ATCO Electric has 38 service offices serving two-thirds of the province in northern and east-central Alberta. We help keep the lights on across the province by building, operating and maintaining more than 69,000 kilometres of transmission and distribution power lines. We also operate an additional 12,000 kilometres of distribution power lines on behalf of Rural Electrification Associations. We are committed to responsible development and environmental practices. We conduct an open and transparent consultation process, carefully considering the impacts to landowners, communities and the environment.

Contact Us Your comments and concerns are important to us. Please contact us toll free 1-866-600-0022 or direct: Shawn Hipkiss, Project Planner Heisler Transmission Project Phone: 780-420-5554 ATCO Electric Fax: 780-420-5554 10035-105 Street Email: [email protected] Edmonton, AB T5J 2V6 Website: www.atcoelectric.com


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Cartography By: BM Approved By: Shawn Hipkiss February 2011ATCO Planner: Shawn Hipkiss EBA Project Manager: Brent McMillin


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NOTES:

-P-01RS-7LA701

Join us at our open house

If you have questions about this project or if you cannot attend the open house and you would like to discuss this project with ATCO Electric, please contact:

Shawn Hipkiss, Environmental/ Right of Way PlannerToll free: 1-866-600-0022 Fax: 780-420-5030Email: [email protected] Website: www.atcoelectric.com

HEISLER TRANSMISSION PROJECTATCO Electric is hosting an open house to share details of the reinforcement transmission project taking place in Flagstaff County. The proposed project looks to answer the growing demand for electricity and to interconnect to new generation in the region. Proposed project activities will include the construction of a new transmission line from the Heisler substation to an existing transmission line in the area. Additional alterations will occur to the related substation electrical and communications equipment. We invite you to attend the open house.

Attendance at an open house will provide you with an opportunity to meet the members of our team, learn more about the different options under consideration and have your questions answered.

We welcome open discussion including any comments or concerns you may have as your feedback plays a critical role in our projects.

We look forward to meeting you.

Tuesday, March 22, 2011 4 - 8 p.m. Heisler Community Centre, 119 Main Street, Heisler, Alberta

10035 - 105 Street, Edmonton, Alberta, T5J 2V6

REPLY FORM

NOTE ABOUT PRIVACY: The information on this form is being collected to help identify potential concerns with proposed power transmission facilities, to facilitate communications about the project, and to comply with our obligations to the Alberta Utilities Commission. This information may be provided to the Alberta Utilities Commission. Information relating to the need for the facilities may be provided to the Alberta Electric System Operator. Enquiries or concerns about ATCO Electric's privacy policies can be directed to Greg McNeill, privacy officer (address above), phone 780-420-4468.

DATE: _____________________

FAX TO: Shawn Hipkiss, ATCO Electric, Fax No. 780-420-5030

PROJECT: Heisler Transmission Project

Do you have any facilities or developments in the area that may be affected by this project?

No. Yes, and they are as follows:

______________________________________________________________________

______________________________________________________________________

Do you have any concerns about the project? No. Yes, and they are as follows:

______________________________________________________________________

______________________________________________________________________

Is there anyone else we should be contacting about this project? No. Yes, and they are as follows:

______________________________________________________________________

______________________________________________________________________

Do you have any other comments or questions? No. Yes, and they are as follows:

______________________________________________________________________

______________________________________________________________________

If we have any errors in your name and address, please provide corrections.

______________________________________________________________________

______________________________________________________________________

Sent By: Name

Agency/Company Name

Address

Phone No.: _________________________ Fax No.:

E-mail/Other:

Who is the AESO?

Alberta’s transmission system, also referred to as the Alberta Interconnected Electric System (AIES), is planned and operated by the Alberta Electric System Operator (AESO). The transmission system is comprised of the high-voltage lines, towers and equipment (generally 69 kV and above) that transmit electricity from generators to lower voltage systems that distribute it to cities, towns, rural areas and large industrial customers. Our job is to maintain safe, reliable and economic operation of the provincial transmission grid. Where is the AESO’s planning study region?

The AESO’s planning study region runs from Cold Lake south through the Battle River, Wainwright and Vegreville areas, and east to the Provost area. The Central East region also covers Lloydminster, at the border with Saskatchewan. Larger communities in this region include Cold Lake, Bonnyville, Vermilion, Kitscoty, Lloydminster, St. Paul, Elk Point, Vegreville, Wainwright, Hardisty, Sedgewick, Strome, Jarrow, Edgerton, Castor, and Killarney Lake. Why is transmission development required in the Central East (Cold Lake, Vegreville and Provost) area? Transmission system reinforcement is needed in the study region to meet growing demand for electricity from oil sands development and pipelines, and to interconnect proposed gas fired electricity generation as well as wind farms in the study region. The AESO has received applications to interconnect over 500 megawatts (MW) of wind power and natural gas generation projects in Central East Alberta. Further, the AESO long term forecast shows demand for electricity in the Cold Lake and Wainwright areas increasing by more than five percent per year and 12 percent per year respectively. Oilsands development and pipelines, required for transporting oilsands products for upgrading, drive this growth in demand. The existing transmission system in this region, however, is at capacity and cannot carry any additional electricity. In addition, parts of the system are subject to low voltages under certain conditions. System reinforcement, therefore, is needed to meet increasing demand for electricity and to interconnect new generation. Where will the new lines be proposed?

The AESO identified a number of alternatives for reinforcing the transmission grid in this region. Consultation with stakeholders will help identify a preferred solution for reinforcing the system. This preferred solution will form part of our Needs Identification Document (NID), which we will submit to the Alberta Utilities Commission (AUC) later this year. We will also submit individual NIDs separately to the AUC to interconnect wind power projects as well as gas fired generation. The transmission facility owners, AltaLink and ATCO Electric, service the communities, industry, and farms in the Cold Lake, Vegreville and Provost region. Should the AUC approve our NID, we will assign the larger system reinforcement and each new interconnection to either AltaLink or ATCO Electric, to build and maintain the required transmission facilities. Additional public consultation will be required as part of this process. Once, completed, siting and routing proposals will be submitted to the AUC in the form of a Facility Application for approval. What’s happening right now?

Since the region is vast, we have developed alternatives to address both broader and local transmission issues. So far, our planning study has produced alternatives for system reinforcements in the area to address the challenges facing the transmission system. After gathering stakeholder insights on our alternatives, our study will identify areas where transmission lines and other related facilities could be added to improve the system. The targeted in-service date for these facilities is 2012. The map below shows broadly where transmission lines may be needed. No individual routes have been identified below; this will be done in a later process also requiring public consultation.

Transmission Reinforcement in the Central East (Cold Lake, Vegreville and Provost) Area

For more information please contact the AESO at 1-888-866-2959,

www.aeso.ca or [email protected]

- 2 -

The AESO is committed to protecting your personal privacy in accordance with Alberta's Personal Information Protection Act. Any personal information collected by the AESO with regard to this project may be used to provide you with further information about the project, may be disclosed to the Alberta Utilities Commission (and as a result, may become public), and may also be disclosed to the eligible Transmission Facility Owner. If you have any questions about how the AESO will use and disclose your personal information collected with regard to this project, please contact us at 888-866-2959 or at [email protected].

INFORMATION SHEETS

TRANSMISSION LINES ON OR NEAR YOUR PROPERTY

We understand that you may have questions or may be interested in additional details about transmission lines. The following information sheets will provide you with detailed explanations and answers to commonly asked questions concerning:

Additional contact information

………………. sheet 1

Route selection & planning ………………. sheet 2

Landowner participation ………………. sheet 3-4

The regulatory process ………………. sheet 4

Transmission line construction ………………. sheet 5

Transmission lines and farming ………………. sheet 6

Environmental considerations ………………. sheet 7

Electrical effects ………………. sheet 7-8

Electric & magnetic fields (EMF) ………………. sheet 9

Compensation ………………. sheet 10

Definition of terms ………………. sheet 11

TLYourPpty-Sep2009.doc TRANSMISSION LINES ON OR NEAR YOUR PROPERTY

INFORMATION SHEETS

TLYourPpty-Sep2009.doc TRANSMISSION LINES ON OR NEAR YOUR PROPERTY Sheet 1

TRANSMISSION LINES ON OR NEAR YOUR PROPERTY

Albertans as a whole use more power every year. Transmission lines are required to transmit bulk power from generating sources to the distribution systems which serve homes, farms, businesses and industry. Transmission lines are designed and built to carry bulk electricity safely, reliably and economically over long distances. They are the lifeline of growth, development and prosperity in Alberta.

The Alberta Interconnected Electric System consists of over 21,000 kilometres of transmission lines and 530 substations, connecting more than 300 generating units across the province.1 Electricity flows over the transmission system from generating stations to supply customers around the province.

If you are a landowner or leaseholder* faced with the possibility of having a transmission line built on or near your property, you probably have some questions or concerns. These information sheets provide facts and answers to the questions most frequently asked about transmission lines. ATCO Electric encourages you to become involved in the process for selecting new transmission line routes.

*Wherever the word "landowner" is used throughout these information sheets, "leaseholders" and others with an interest in land are also implied. The exception to this is in the Compensation section.

FOR MORE INFORMATION

If you need more information, please try our web site (www.atcoelectric.com), or contact one of our planning staff by calling toll-free 1-866-600-0022 or by writing to:

ATCO Electric Right-of-Way Planning Box 2426 Edmonton, Alberta T5J 2V6

Enquiries about the need for transmission facilities can be directed to the Alberta Electric System Operator (AESO):

Phone: 403-539-2588, or 1-888-866-2959 E-mail: [email protected] Web page: www.aeso.ca

If you have questions about the process for applications to the Alberta Utilities Commission (AUC), please contact the Commission at 780-427-4903. Or, you may wish to contact the Commission for a list of relevant publications, such as:

• Public Involvement in Facility Applications to the Alberta Utilities Commission

AUC publications are available from:

Alberta Utilities Commission 4th Floor, 425 – 1 Street SW Calgary, Alberta, T2P 3L8 Phone: 403-592-8845 or 780-427-9362 E-mail: [email protected] Web page: www.auc.ab.ca www.auc.ab.ca

1. Based on information from Alberta Electric System Operator, Powering Albertans, vol. 3(1), May 2009.

INFORMATION SHEETS


R O U T E S E L E C T I O N A N D P L A N N I N G

If your property is situated in the general area between existing or proposed power substation locations, there is the possibility that a transmission line may be routed on or near your property.

ATCO Electric carries out detailed studies

to identify route alternatives that will have the least impact on landowners, but it is impossible to avoid everyone's property. The lines have to be built somewhere, and there are many factors to be considered.

The final decision on the specific location of

a proposed transmission line is made by the Alberta Utilities Commission.

How are potential routes for a transmission line decided?

ATCO Electric's planners carefully gather

and study the best available information about the area between substation locations, to determine possible route alternatives. Engineers, environmental specialists, surveyors, and construction personnel assist with these studies.

They get their information from maps and

aerial photographs, site investigations, cost and technical studies, landowners, local governments and planning bodies, as well as various departments of the provincial and federal governments.

Alternative routes are selected to avoid,

wherever possible, any problems or conflicts identified by the studies.

What factors does ATCO Electric consider when selecting potential routes for a transmission line?

Generally, our planners select routes that

meet cost and technical criteria, while creating the least disruption to people, agriculture, industry and the environment.

Factors to consider could be: • geographical features (lakes, rough

terrain) • cultivated land • residential property and built-up areas • other power lines • pipelines and related facilities • highways • airports • parks and environmentally sensitive areas The nature and significance of route

constraints vary for each project. Planners have to consider all known factors and constraints, then evaluate them to determine the most suitable route alternatives.

Rules established by the Alberta Utilities

Commission help guide the route and site planning and approval processes for transmission facilities.

INFORMATION SHEETS


L A N D O W N E R P A R T I C I P A T I O N

When planning new power facilities, ATCO Electric encourages landowners to participate, as early as possible, in the process of selecting a route for a transmission line. If it looks like a transmission line may be routed on or near your property, we want you to tell us how you think the proposed line will affect you. We will make every reasonable effort to satisfy your concerns.

How will I know if a proposed transmis-sion line route is on or near my property?

Once some possible routes have been

identified, ATCO Electric planners will send information to all landowners who have property within about 0.8 km (one-half mile) of any of these route possibilities. This does not always apply to land within incorporated villages, towns or cities, where we would give notice of the project through advertisements in the local newspaper.

Who can I talk to about my concerns?

The name and phone number of the project

planner along with details about the project are included in an information package which you should receive from ATCO Electric early in the planning process. We encourage you to call the toll-free number during business hours to let us know about your concerns, or to get more information.

In addition, ATCO Electric may schedule a

public open house on the project. If so, the time and place will be announced in your information package and through advertisements in your local newspaper. Open houses are usually held in a local community hall or similar facility.

The open house would be held to get your views on the route alternatives being considered. At this stage, ATCO Electric has not necessarily decided on a final route; all of the alternatives shown would still be considered viable options.

ATCO Electric’s planners, transmission

engineers, land agents and service staff will be available to talk to you about your concerns on a one-to-one basis. This is your chance to spend as much time as you need to discuss the project and your specific concerns with the people responsible for routing and designing the transmission line. We record each participant's comments and concerns, to help us determine exactly where specific features are located that we should avoid.

The open house gives you, the individual

landowner, the chance to voice your specific concerns about how the proposed line would affect your property.

Formal public meeting or informal open house?

A formal public meeting usually does not give

every landowner an opportunity to bring all of his or her individual concerns to the planners' attention. For this reason, we have found a public meeting is usually not as effective as an informal open house.

Can my concerns be important enough to change the route proposed for a transmission line?

Your concerns are very important to us. In the

past, there have been occasions where landowners have brought up a variety of concerns important enough to convince ATCO Electric’s planners and engineers to make changes in the proposed routes.

INFORMATION SHEETS


L A N D O W N E R P A R T I C I P A T I O N ( C o n t i n u e d )

However, it is important for you to make your concerns known to us as soon as possible. If you wait until an Alberta Utilities Commission (AUC) hearing is announced (which may or may not be required) or later, it may be too late for us to make changes that will satisfy your major concerns. Talk it over with us before it's too late.

What happens after the landowner consultation?

After our representatives have met with

potentially affected landowners, our planners evaluate all the factors and select a preferred route (and alternatives, if any). ATCO Electric then applies to the AUC for permission to build and operate the line.

We will notify you after we have submitted our application to the AUC, and we will advise you of the route(s) described in the application.

The list of landowners affected is forwarded

to the AUC as part of the formal application. The AUC may also contact landowners along the route, to determine if there are any objections, or to announce the date and place for a public hearing on the transmission line project. If necessary, a hearing date and location may also be advertised in your local newspaper.

If no landowners or other interested parties oppose the project, a hearing may not be called.

T H E R E G U L A T O R Y P R O C E S S

On direction from the Alberta Electric

System Operator (the province's independent transmission system administrator), ATCO Electric must apply to the Alberta Utilities Commission (AUC) for permission to construct and operate a transmission line, which is any power line carrying 69,000 volts or more. In the application, we will describe the preferred route and alternatives, if any, and the reasons for our selection.

Who has the final say on the location of transmission lines and substation sites?

The AUC must decide whether or not the

transmission line is required, and if so, where it is to be located. Before reaching these decisions, the AUC may conduct a public hearing.

Any directly affected group or individual is entitled to participate in the hearings as an intervener, to support or oppose all or any part of the company's proposal. If a hearing is not required, anyone with an interest in the project can make their views known by contacting the AUC directly.

Once the AUC has considered the

information presented by all parties, it will announce its decision. And once the decision has been made, it is normally too late to make changes to the transmission line route. The simplest and most effective way of having your concerns recognized and considered is to make them known to ATCO Electric’s route planners as early as possible.

The AUC does not make a decision on

matters of land compensation. These issues are dealt with by the Surface Rights Board.

INFORMATION SHEETS


T R A N S M I S S I O N L I N E C O N S T R U C T I O N

Construction activities for a new trans-mission line include: conducting field investigations, surveying, preparing the right-of-way, installing the poles or towers, and stringing the conductor wires. Surveying and field investigations such as geotechnical testing can occur before approvals are granted by the Alberta Utilities Commission (AUC). The other activities occur only after the AUC has issued its approvals.

Before construction begins, ATCO Electric

contacts landowners along the route to inform them of our schedule and negotiate the necessary agreements (see Sheet 10, Compensation).

Preparing the right-of-way may require

selective clearing or removal of trees, according to safe clearance standards. The actual width of the cleared right-of-way will depend on the type of transmission structure and the height of trees nearby. Our liaison representative can explain the right-of-way width required on your property.

In some cases, we may have to temporarily

remove a fence or gate, or relocate granaries or other structures. Temporary fences will be installed, where necessary, to make sure your livestock is contained. We may have to construct temporary or permanent roads for access to the right-of-way, sometimes on property not crossed by transmission lines, especially in steep terrain.

Before we put up the transmission poles or

towers, foundation holes are drilled and, in the case of towers, the footings may be embedded in reinforced concrete. The structures are assembled, then raised and set into place. In the final stage of construction, trailers carrying large reels of wire are brought in, and the wire is pulled from the reels and strung onto the towers or poles.

How will the right-of-way look after construction is completed?

All construction debris is removed from the

right-of-way, either before our contractors leave the area or, in the case of winter construction, as soon as ground conditions permit. All fences removed or relocated will be restored to the condition they were in before construction began. Brushing debris is normally burned on site.

When clearing treed areas, we do not grub

roots or break up new ground. You may wish to do this work yourself if you want to cultivate the newly cleared area. We will, however, seed the right-of-way to compatible grasses if you request this. We will make every effort to restore, as near as practicable, the work site to its original condition.

After construction, will ATCO Electric need access to the right-of-way?

Access rights are granted in the power line

easement or agreement. By law ATCO Electric must inspect the line, either on the ground or from the air, at regular intervals, usually yearly. Our crews may need access to inspect or repair the line, or to control hazardous vegetation. You will be paid fair compensation for damage to crops, land or fences.

Vegetation must be managed to provide for

the safe operation of the line. ATCO Electric tries to keep the right-of-way covered with grass or other low-growing plants, to allow access and to protect the soil. Vegetation is controlled chemically by spraying herbicides (such as Garlon 4 or Tordon 101), or mechanically by trimming, slashing or mowing.

INFORMATION SHEETS


T R A N S M I S S I O N L I N E S A N D F A R M I N G

When planning new power facilities, ATCO Electric tries to avoid placing transmission lines diagonally across cropland. We make every effort to position transmission structures where they will have the least possible impact on farming operations.

Single poles can usually be located on road

allowances, thereby avoiding private land. However, if there are too many homes or other restrictions, we may have to place the poles along quarter lines or section lines - usually offset 1 metre from the property boundary - or across cultivated land. Transmission lines built on the larger two-pole or steel lattice-type structures are usually located along quarter lines or section lines. For all transmission lines on private property, we pay compensation for the inconvenience of farming around structures, as explained in the information on Compensation.

In some cases, such as line deflections, we

may have to approach the landowner for an easement for a supporting guy wire and anchor, or even for additional poles.

Double-pole "H-frame" structures and steel

towers cannot be safely located on opened road allowances. As a result, we have to position these structures on adjacent properties. ATCO Electric will try to place them where the least amount of cropland will be affected, such as on pastureland.

Will transmission line construction interfere with my farming operations?

Depending on the time of year construction

takes place, there may be some temporary interference with some farm activity. We will make every reasonable effort to co-ordinate our construction activities with your farming operations to minimize any inconvenience to you.

Will I still be able to farm around and under the line, once it is completed?

You will still be able to farm around and

under it, subject to certain restriction due to the exact location of the poles or towers.

Normally, you should be able to operate

your farm equipment under the wires without any concern. For your own safety, equipment should be no higher than 4.3 metres (14 feet), as specified by provincial safety regulations. Most farm equipment meets this height restriction, but if you have any doubts about your equipment or loads, please contact us.

Do transmission lines affect production by honey bees?

Honey production may be affected if hives

are located too close to a transmission line. Bees are sensitive to both the low-level electric fields around the hives and the very low-level induced charge that may develop on a hive's supers.

Shielding hives with a grounded wire plate

or moving them further away from the transmission lines will eliminate these effects, and the bees will carry on their normal level of honey production.

INFORMATION SHEETS


E N V I R O N M E N T A L C O N S I D E R A T I O N S

Clearing, construction, reclamation, and subsequent activities are all carried out in accordance with Alberta Environment's Environmental Protection Guidelines for Electric Transmission Lines (C&R/IL/95-2). Activities must also follow the terms and conditions of right-of-way agreements and Crown easements, and comply with all applicable laws, regulations and good utility practices. Transmission facilities normally do not require an environmental impact assessment report or Alberta Environment approval. Measures to be taken to address environmental concerns are identified through environmental protection planning and in consultation with landowners and agencies.

Do transmission facilities create noise?

Transmission lines are very quiet in good

weather. You will hardly notice any sound they make during normal operation. During rain or heavy fog, you may hear a low level

crackling or buzzing sound at the edge of the right-of-way. Even so, the noise is less than the sound of a light breeze.

Certain equipment in substations (e.g.,

transformers, fans) can be audible up to a few hundred metres away from the site. ATCO Electric must ensure that the facilities meet Alberta Utilities Commission rules for noise control.

Any significant noise or traffic is

generally limited to the initial construction period. Construction traffic would include a variety of trucks and heavy equipment. During long-term operation, facilities require occasional light traffic and activity (typically weekly at substations and annually for lines) for inspection and maintenance, and rare access (every few years) for larger repairs.

E L E C T R I C A L E F F E C T S

Occasionally landowners express concern about the electrical effects of transmission lines. Unfortunately, misconceptions can cause unnecessary concerns for many people. The following questions cover the most common concerns people have about electrical effects.

Should I worry about getting an electrical shock from a transmission line?

You will not get a harmful shock from a

transmission line unless you or your equipment comes into contact with or is very close to the actual conductor wires.

Occasionally you might experience a

slightly annoying but harmless electrical

sensation if you touch an ungrounded metal object near a high voltage transmission line. This sensation is similar to what you may have experienced in your own home, after walking across a carpet and touching a door knob. Typical ungrounded objects include wire fences with dry wood posts, large vehicles with old rubber tires, and metal buildings. To eliminate these mild shocks, make sure metal objects and fences are properly grounded. During construction of a new line, ATCO Electric will do this. You can always contact us about proper grounding methods.

Long lengths of ungrounded pipe parallel

to and near a power line can build up an induced hazardous electrical charge.

INFORMATION SHEETS


E L E C T R I C A L E F F E C T S ( C o n t i n u e d )

Is it safe to drive or park a car or truck near a transmission line?

Most vehicles today are naturally

grounded, because their tires are made of semiconducting carbon black. A mild electric charge can build up on a vehicle with old rubber tires because they generally do not conduct electric currents. Such induced charges are annoying, but harmless. If your vehicle tends to develop a mild electric charge, it can be grounded by attaching a chain that is long enough to touch the ground.

There have been no reported cases of

fires caused by static sparks induced by transmission lines. However, the refueling of vehicles under lines could pose a problem in the unlikely event that certain conditions (including hot, still weather and a completely insulated vehicle) existed all at the same time. As a precaution, never refuel your vehicles directly under a transmission line. If you have no choice in the matter, use a plastic gasoline container.

Will a transmission line endanger my property in a lightning storm?

Transmission lines do not attract distant

lightning. When a storm is directly overhead, they may actually draw lightning away from nearby trees, buildings, animals and people. Since lightning is attracted to the highest available object, in a rural area the power transmission lines are often struck. However, because these structures are well grounded, the potential danger is far less than if it were to strike a tree or building.

Will transmission lines affect my radio and TV reception?

Transmission lines in Alberta are alternating

current (AC) lines, which normally do not affect radio or TV reception. However, under certain circumstances, there may be some static interference which may affect the reception of weak signals from far away radio and TV stations, particularly if poor quality receiving equipment is used.

ATCO Electric will make every reasonable

effort to correct any interference caused by its facilities. Sometimes it may be a matter as simple as tightening a nut or bolt.

However, if you have poor reception now

without the presence of a transmission line, the company cannot improve your reception after a transmission line is built. ATCO Electric, in consultation with the federal department for communications (Industry Canada), will work to address radio and TV reception complaints. Industry Canada stipulates that within six months of the line being energized, radio noise levels are to be measured, and that they must fall within set limits.

A WORD ABOUT SAFETY.

You should always be careful and follow common sense rules of safety when near any type of power line.

Some of the hazards you should avoid in the home, around the farm and on the job are illustrated in a variety of safety booklets and materials, available at no charge by contacting your local electricity provider.

Look for safety tips on our web site: www.atcoelectric.com

INFORMATION SHEETS


E L E C T R I C A N D M A G N E T I C F I E L D S

What is EMF? EMF stands for "electric and magnetic

fields" which are fields of force caused by electric voltage and current.

Since the 1970s, scientists having been

researching the potential health effects of EMF, particularly the 60-hertz, alternating current type that surrounds all electrical equipment, from high voltage power lines and lower voltage distribution lines to household wiring and appliances. In fact, EMF surrounds all things electrical.

Should I be concerned?

Concerns are mainly about chronic, long-

term exposure rather than occasional exposure such as harvesting crops under a power line.

Research has been focusing on magnetic

fields, where some studies have suggested a slightly increased risk of certain illnesses associated with people who may be exposed to higher EMF levels. However, the associations are weak, and other studies indicate no association at all. And none of the research has found a cause-and-effect relationship.

What do we know about EMF?

We do know that field strengths decrease

quickly with distance. Magnetic fields are commonly measured in units of milligauss (mG). Magnetic field strengths might be up to 60 mG directly beneath a typical ATCO Electric 240 kV transmission line, but would drop to about 0.5 mG at a distance of 70 metres (230 feet) to 100 metres (330 feet) away.

For a typical 144 kV transmission line, magnetic field strengths might be up to 25 mG directly beneath the line, dropping to about 0.5 mG at a distance of about 60 metres (200 feet) away. The average magnetic field in most homes (due to home electronics, appliances and household wiring) is 1 mG or less.

Are there EMF limits or guidelines?

Health Canada does not consider guidelines

necessary because scientific evidence is not strong enough to conclude that typical exposures cause health problems.

What is ATCO Electric doing about EMF?

ATCO Electric is taking steps to act

responsibly. We continue to build and operate our transmission facilities within accepted engineering and safety standards. We try to route new facilities away from built-up areas.

We are also committed to monitoring what

is happening in the research, and sharing information with customers, employees, government officials or any other interested people or organizations on matters concerning EMF.

Further information and links can be found

on the Canadian Electricity Association web site: www.canelect.ca.

INFORMATION SHEETS


C O M P E N S A T I O N

For new transmission lines ATCO Electric negotiates compensation settlements that are fair and reasonable to landowners and in accordance with surface rights legislation.

Compensation negotiations usually take

place after the Alberta Utilities Commission (AUC) issues the company a permit to construct the transmission line along a designated route.

Our land agent will negotiate compensation

settlements with each landowner or lease-holder from whom rights must be obtained. ATCO Electric does not purchase the land outright for a right-of-way, but simply acquires rights to use it for a specific purpose.

How much compensation will I be offered?

The amount of compensation depends on

how, and to what extent, the transmission line will affect you and your property. A number of factors are considered, and not all may apply to your case. Compensation is paid for each of the following, if required:

1. an entry fee payment (required under

surface rights legislation) based on $500 per acre of land required. For each parcel of land, the minimum payment is $250 and the maximum is $5000;

2. an easement or agreement for the trans-mission line right-of-way, based on the amount of land within the right-of-way and the fair market value of the land (or a portion of the value if the rights are only temporary);

3. an agreement allowing for the removal of trees and brush adjacent to the right-of-way;

4. a temporary working-space agreement allowing for additional area outside the right-of-way of the transmission line during the construction period.

In addition, you may receive payment for general disturbance such as costs for time, and other inconveniences related to the installation of the power line.

When do I get my compensation?

Whenever possible, ATCO Electric will pay

the initial lump-sum compensation before construction begins.

Where the transmission structures are to be

located on agricultural land, the negotiated settlements will also include annual compensation payments for inconvenience and crop loss. You may review these annual payments with the company at five-year intervals, at which time they may be adjusted to reflect changes in farming costs and crop prices. Our land agent will explain these procedures to you in more detail.

Does the compensation payment include reimbursement for construction damage?

Claims for damage arising from construction

activities are settled separately from the main compensation agreement after construction is completed.

What can I do if I am not satisfied with the company's final offer?

If you are not happy with the company's

offer or settlement of damage claims, you are entitled to ask that the amount of compensation be determined by the Surface Rights Board.

Definition of Terms for 144-kV and 240-kV Transmission Line Projects Sept. 2009

Definition of Terms Transmission System: The transmission system or "grid" is made up of transmission lines and substations that have the ability to efficiently transmit power over long distances, between generators and "load" (customer) centres, or between regions. Transmission lines (69 kilovolts or more) are higher voltage, and transmit power to local substations whereas the distribution lines (25 kilovolts and lower) deliver power to homes, farms and businesses. The transmission system is like a major highway network for longer distance travel, while distribution lines are comparable to secondary roads and local streets. 144 kilovolt (144 kV): A 144 kilovolt line is a mid to higher capacity type of line, usually transmitting power within regions, to larger industrial loads, and from larger generating sites. 240 kilovolt (240 kV): A 240 kilovolt line is a higher capacity transmission line, usually transmitting bulk power between regions, to very large industrial loads, and from very large generating sites. Substation: A fenced enclosure containing equipment such as step-down transformers that connect the transmission lines to the distribution system, and other equipment to manage the flow and quality of power. Substations are also designed to operate and protect the electric system similar to in-home breaker units but are a much more sophisticated, larger scale version. Study Area: The area in which we are examining both the opportunities for routing such as existing power lines, roads, high ground, etc., and the key constraints such as residences, sensitive environmental or cultural features, conflicting developments, etc. Route or Route Option: A possible location for the proposed transmission line and right of way, selected to try to meet the technical, economic, environmental and land use criteria. The route selection process also involves obtaining essential feedback from agencies and landholders toward ensuring we minimize environmental or land use impacts. Preliminary routes require further refinement and may be rejected, or may shift by several hundred metres depending on information gathered through further examination, surveys and the feedback from landholders and interested parties. In the final analysis, only one new line is needed along an acceptable route. Right of Way: An area that is cleared of trees, brush, debris or other obstacles to allow access for construction and ongoing maintenance and operation of the transmission line. Right of way also means the legal rights to use the land, normally obtained by a power line agreement or easement. Alberta Utilities Commission (AUC): The AUC is an independent, quasi-judicial agency of the Government of Alberta. Its mission is to ensure that the delivery of Alberta's utility services takes place in a manner that is fair, responsible, and in the public interest. The AUC ensures that electric facilities are built, operated, and decommissioned in an efficient and environmentally responsible way. All new transmission facilities require the approval of the AUC. The AUC replaced the Alberta Energy and Utilities Board (EUB) on January 1, 2008. If you have any questions regarding the process for applications to the AUC, please see the enclosed AUC brochure "Public Involvement in Facility Applications to the Alberta Utilities Commission", or contact the Commission at 780-427-4903. Alberta Electric System Operator (AESO): A corporation established under provincial law, the AESO acts as the independent system operator, directing the reliable and economic operation of Alberta's interconnected electric system. AESO plans the transmission development in Alberta by identifying present and future needs, and contracts with transmission facility owners such as ATCO Electric to provide the needed transmission services and facilities. AESO is independent of any industry affiliations and owns no transmission assets. Enquiries about the need for transmission facilities can be directed to AESO at 1-888-866-2959, [email protected]. ATCO Electric: ATCO Electric owns and operates the power transmission and distribution systems in northern and east-central Alberta. With a service area covering almost two-thirds of the province, ATCO Electric provides safe, reliable delivery of electricity to Alberta homes, farms, and businesses. ATCO Electric also reads the electricity meters and provides consumption information to the retailer, which passes these charges on to their customers. ATCO Electric costs are regulated by the Alberta Utilities Commission. For power emergencies call ATCO Electric at 1-800-668-5506. For general enquiries about power lines or meters call us at 1-800-668-2248. For questions about hook-ups or your bill, please contact your energy retailer (see the phone number on your bill).

Central East Region Transmission Development

File No. RP-05-811(ATCO) R2 AESO Functional Specification Page 2 of 66

REVISION HISTORY

Rev. # Description Author Date

V1B1 Initial Issue Henry Ng June 25, 2010

V1B2 Second Issue Henry Ng August 12, 2010

R1 Final Issue Henry Ng October 5, 2010

R2 Added critical development in section

4.1

Henry Ng March 18, 2011



TABLE OF CONTENTS

1. INTRODUCTION ....................................................................................... 6

2. DATA DISCLAIMER .................................................................................. 6

3. TFO SERVICE PROPOSAL AND ESTIMATE........................................... 6

4. PROJECT OVERVIEW.............................................................................. 6

4.1 Proposed Facility Additions........................................................................ 6

4.1.1 Stage I development: ................................................................................. 6

4.1.2 Stage II development: ................................................................................ 9

4.2 Future / Ultimate Development .................................................................. 9

5. SCOPE OF WORK .................................................................................. 10

5.1 General .................................................................................................... 10

5.2 Standards ................................................................................................ 10

5.3 Substation Equipment Specifications....................................................... 11

5.4 ATCO Scope of Work (Stage I)................................................................ 12

5.4.1 General Requirements............................................................................. 12

5.4.2 Conversion of St. Paul 707S and Willingdon 711S .................................. 12

5.4.2.1 Transmission Lines......................................................................... 12

5.4.2.2 St. Paul 707S Substation (Appendix 7.3.3)..................................... 13

5.4.2.3 Watt Lake 956S (Appendix 7.3.10) ................................................. 14

5.4.2.4 Willingdon 711S Substation (Appendix 7.3.5)................................. 15

5.4.2.5 Bonnyville 700S Substation (Appendix 7.3.1) ................................. 15

5.4.2.6 Whitby Lake 819S Substation (Appendix 7.3.7).............................. 16

5.4.3 Cold Lake Area Reinforcements – Part I.................................................. 17


5.4.3.2 Bourque 970S Substation (Appendix 7.3.11).................................. 17

5.4.3.3 Mahihkan 837S Substation (Appendix 7.3.9).................................. 18

5.4.4 Cold Lake Area Reinforcements – Part II................................................. 19


5.4.4.2 Bonnyville 700S Substation (Appendix 7.3.1) ................................. 19

5.4.5 Cold Lake Area Reinforcements – Part III................................................ 20


5.4.5.2 Leming Lake 715S Substation ........................................................ 20



5.4.5.3 Wolf Lake 822S Substation............................................................. 21

5.4.5.4 Marguerite Lake 826S Substation (Appendix 7.3.8) ....................... 22

5.4.6 Provost and Lloydminster Areas Line Re-builds ...................................... 23


5.4.6.2 Lloydminster 716S Substation ........................................................ 23

5.4.7 Line Clearance Mitigations....................................................................... 24


5.4.8 Battle River and Lloydminster Areas Reinforcements.............................. 24


5.4.8.2 Kitscoty 705S Substation (Appendix 7.3.2)..................................... 24

5.4.8.3 Hill 751S Substation ....................................................................... 25

5.4.8.4 Heisler 764S Substation (Appendix 7.3.6) ...................................... 26

5.4.8.5 Vermilion 710S Substation (Appendix 7.3.4) .................................. 27

5.4.9 Vermilion Area Voltage Support............................................................... 27

5.4.9.1 Vermilion 710S Substation (Appendix 7.3.4) .................................. 27

5.5 ATCO Scope of Work (Stage II)............................................................... 28

5.5.1 General Requirements............................................................................. 28

5.5.2 7L50 Re-build .......................................................................................... 28


5.5.2.2 Battle River 757S Substation .......................................................... 29

5.5.3 Cold Lake Area Additions (Year 2017) .................................................... 29


5.5.3.2 Marguerite Lake 826S Substation (Appendix 7.3.8) ....................... 29

5.5.3.3 Bourque 970S Substation (Appendix 7.3.12).................................. 30

6. TRANSMISSION SYSTEM OPERATING CHARACTERISTICS ............. 32

6.1 Short Circuit Current Levels..................................................................... 32

6.2 Insulation Levels ...................................................................................... 35

6.3 Operational Constraints ........................................................................... 35

7. APPENDICES.......................................................................................... 36

7.1 Central East Region Transmission System - Existing.............................. 36

7.2 Central East Region Transmission System - Proposed Developments .. 37

7.3 Substation Single Line Diagrams............................................................. 38

7.3.1 Bonnyville 700S Substation – Proposed Development ............................ 38



7.3.2 Kitscoty 705SSubstation – Proposed Development................................. 39

7.3.3 St. Paul 707S Substation – Proposed Development................................ 40

7.3.4 Vermilion 710S Substation – Proposed Development ............................. 41

7.3.5 Willingdon 711S Substation – Proposed Development............................ 42

7.3.6 Heisler 764S Substation – Proposed Development ................................. 43

7.3.7 Whitby Lake 819S Substation – Proposed Development ........................ 44

7.3.8 Marguerite Lake 826S Substation – Proposed Development .................. 45

7.3.9 Mahihkan 837S Substation – Proposed Development............................. 46

7.3.10 Watt Lake 956S Substation – Proposed Development ............................ 47

7.3.11 Bourque 970S Substation – Proposed Development............................... 48

7.3.12 Bourque 970S Substation – Proposed 2017 Development...................... 49

7.4 Energy Data Requirements...................................................................... 50

7.4.1 SCADA Point Requirements .................................................................... 50

7.4.1.1 Bonnyville 700S Substation ............................................................ 50

7.4.1.2 Kitscoty 705S Substation ................................................................ 51

7.4.1.3 St. Paul 707S Substation ................................................................ 52

7.4.1.4 Vermilion 710S Substation.............................................................. 53

7.4.1.5 Heisler 764S Substation ................................................................. 54

7.4.1.6 Whitby Lake 819S Substation......................................................... 55

7.4.1.7 Marguerite Lake 826S Substation................................................... 56

7.4.1.8 Mahihkan 837S Substation ............................................................. 57

7.4.1.9 Watt Lake 956S Substation ............................................................ 58

7.4.1.10 Bourque 970S Substation ............................................................... 59

7.4.1.11 Bourque 970S Substation - 2017 Development............................. 60

7.4.2 SCADA Data Requirements..................................................................... 61



1. INTRODUCTION

This Alberta Electric System Operator (“AESO”) Functional Specification (“the Specification”) is intended to provide functional direction to the Transmission Facilities Owners (“TFOs”), as well as a party who has made an application to the AESO for system access (“Customer”) pursuant to the AESO’s tariff (“ISO Tariff”), for the development of new or modified transmission facilities for interconnection with the Alberta Transmission System (“ATS”). The Specification also serves to delineate the work to be completed by various parties involved in the development of such facilities, provide reference to applicable standards and guidelines to be applied in the design of such facilities, outline the electrical environment in which such facilities will operate, and provide reference to the applicable rules and templates for the format required for proposals and estimates to be submitted by the TFO’s.

2. DATA DISCLAIMER

This Specification should not be used, nor relied upon, by any Customer, TFO, or other party for any purpose other than that stated in section 1. The information presented in this Specification is based on data provided by third parties to the AESO. These third parties have made no guarantees, expressed or implied, with respect to the completeness or accuracy of the provided data. AESO has taken reasonable steps to verify this data where possible and believes it to be accurate.

3. TFO SERVICE PROPOSAL AND ESTIMATE

The TFO’s Service Proposal and Estimate must be submitted and prepared in accordance with the terms of ISO Rule 9.1, section “9.1.2.4 Obligation to Provide Service Proposal and Service Proposal Estimate”

The final scope of work and any TFO requested exceptions from the scope of work must be approved by the AESO and no work is to be commenced until a “Direction” has been provided in accordance with ISO Rule 9.1, Section 9.1.2.3 b).

4. PROJECT OVERVIEW

4.1 PROPOSED FACILITY ADDITIONS

The project outlined in this document includes the transmission developments required to be carried out by ATCO within the Central East Region, the proposed developments as outlined in the Need Application are as follows:

4.1.1 Stage I development:

1. Bonnyville and St. Paul Areas:

a. Re-build and relocate existing 72 kV Willingdon 711S substation, convert to 144 kV and connect it via tapping nearby 144 kV line 7L92 line. The new



substation shall be designated as Watt Lake 956S. 72kV supply and transformer will be retained for backup supply to town load.

b. Convert existing 72 kV St. Paul 707S substation to 144 kV and connect it to 144 kV line 7L70 using an in and out configuration. Demobilize all 72 kV equipment at St. Paul 707S and install two 144/25 kV low noise transformers at this site.

c. Demobilize (i.e. this equipment will be removed from this site for potential future use at other sites) all 72 kV equipment at Bonnyville 700S including the 144/72kV tie transformer and the two 72/25 kV load transformers. Install a new 144/25 kV load transformer at Bonnyville.

d. Restore the capacity of 144 kV line 7L53 (from Bonnyville 700S to Irish Creek 706S) and 7L117 (from Irish Creek 706S to Vermilion 710S) to its full thermal conductor rating by mitigating line clearance issues.

2. Cold Lake Planning Area:

a. Build a new 144 kV switching station (named as Bourque 970S), with associated set of breakers, near the existing Mahihkan 837S.

b. Build a new double circuit 240 kV, one side strung, from Bourque 970S to Bonnyville 700S using 2x795 MCM ACSR conductors per phase. This line will be initially operated at 144 kV, and be designated as 7L146.

c. Build a new 144 kV double circuit line from Bourque 970S to Mahihkan 837S using 1x477 MCM ACSR conductor per phase, lines to be designated as 7L157 and 7L160.

d. Re-build 144 kV line 7L74 from Wolf Lake 822S and re-terminate it from Mahihkan 837S to Bourque 970S using 1x795 MCM ACSR conductor per phase.

e. Re-build 144 kV line 7L83 from Leming Lake 715S and re-terminate it from Mahihkan 837S to Bourque 970S using 1x477 MCM ACSR conductor per phase.

f. Re-build 144 kV line 7L87 from Marguerite Lake 826S to Wolf Lake 822S using 1x795 MCM ACSR conductor per phase.

g. Remove existing thermal protection schemes in the Cold Lake area.

h. Salvage the SVC equipment and associated building at Bonnyville 700S prior to new 144kV bay development for 7L146.

3. Provost Planning Area:

a. Re-build 144 kV line 7L749 from Lloydminster 716S to ownership boundary using 1x477 MCM ACSR conductor per phase.

4. Lloydminster and Battle River Planning Areas:



a. Restore capacity of the 144 kV lines 7L14 (from Vermilion 710S to Hill 751S) and 7L701 (from Battle River 757S to Strome 223S) to their respective full thermal conductor rating by mitigating line clearance issues.

b. Upgrade the existing 72 kV Heisler 764S and Kitscoty 705S substations to 144 kV by connecting them to nearby 7L701 and 7L14 lines, respectively. Install 144/72/25 kV tie transformer that is relocated from Vermilion 710S.

c. Salvage 72 kV line 6L06 from Kitscoty 705S to Vermilion 710S and demobilize all 72 kV equipment at Vermilion 710S.

d. Install a new 144 kV 25 MVAr capacitor bank at Vermilion 710S.

e. Install a new 144/25 kV transformer at Vermilion 710S.

The proposed ISD for stage I development is Fourth Quarter 2012.

The intention is that all components of the Stage I development be completed by Q4 2012. In the event the Q4 2012 in-service date cannot be met for all the Stage I components and in order to facilitate connection projects and address operational issues, the following Stage I components are identified as priority development:

1. Cold Lake Planning Area:

• Build a new 144 kV switching station (named as Bourque 970S) near the existing Mahihkan 837S.

• Build a new 240 kV line on double circuit towers, one side strung from Bourque 970S to Bonnyville 700S using 2x795 MCM ACSR conductor. This line will be initially operated at 144 kV level

• Build a new 144 kV double circuit line from Bourque 970S to Mahihkan 837S using 477 MCM ACSR conductors.

• Re-build 144 kV 7L83 line from Leming Lake 715S and re-terminate it from Mahihkan to Bourque substation using 1x795 MCM ACSR conductor.

2. St. Paul Area:

• Re-build the existing 72 kV Willingdon 711S substation to 144 kV (named as Watt Lake) and connect it via tapping nearby 144 kV line 7L92 line.

3. Lloydminster area Area:

• Restore the capacity of the 144 kV lines 7L53 and 7L117 (from Vermilion 710S to Bonnyville 700S) by line clearance mitigation measures.

• Restore the capacity of the 144 kV lines 7L14 (from Vermilion 710S to Hill 751S) by line clearance mitigation measures.



• Install a new 144 kV 25 MVAr capacitor bank at Vermilion 710S.

4.1.2 Stage II development:

1. Re-build the aging 138/144 kV 7L50 line from Battle River 757S to Buffalo Creek 526S using 1x477 MCM ACSR conductor per phase.

2. Build a new double circuit 240 kV line with one side strung from Bourque 970S to Marguerite Lake 826S using 2x795 MCM ACSR conductors per phase. This line will be initially operated at 144 kV.

The proposed ISD for stage II development is Fourth Quarter 2017.

4.2 FUTURE / ULTIMATE DEVELOPMENT

Refer to the AESO Long-term Transmission System Plan for possible future development in Central East Region.



5. SCOPE OF WORK

5.1 GENERAL

TFOs and Customers are accountable for all engineering, design, land or land-use acquisition, siting, applicable regulatory approvals and permits, material procurement, construction, commissioning, and associated permitting requirements for their facilities. TFOs and customers shall coordinate as required on all design details (e.g., protection & control, grounding, insulation, point of interconnection, site layout, power quality, etc.) and develop Joint Operating Procedures and/or Interconnection Agreements as required to ensure that interconnected facilities are operated safely and reliably.

In accordance with ISO Rule 9.1 the TFO’s must provide, as a minimum, project reporting as per Section 9.1.3 Project Reporting by Designated TFO’s and project material and labor procurement as per Section 9.1.5 Project Procurement.

All new or modified facilities will be adequately inspected by their owner or qualified representative to ensure compliance with this functional specification. All final design and as-built facility information shall be supplied in the format and content as required by the AESO for purposes of updating and maintaining the AESO’s technical records and system models. This information shall be submitted under signature of a registered Professional Engineer in Alberta who is representing the facility owner and is assuming responsibility for the preparation and accuracy of the submission. The AESO accepts no responsibility for facilities designed by or for any third party, or installed on a third parties behalf, to accomplish the interconnection. The facility owners shall ensure that their facilities have been inspected and declared safe for operation prior to energization. No facilities are to be energized until an Energization Certificate has been issued by the AESO.

5.2 STANDARDS

All work undertaken by TFOs and customers must be designed, constructed, and operated to meet the functional requirements of the Specification and all applicable standards, guidelines, codes and regulations governing such installations including, but not limited those listed below. All AESO documentation can be found on the AESO website (www.aeso.ca).

• AESO Operating Policies and Procedures

• Independent System Operator (ISO) Rules

• AESO Alberta Reliability Standards

• AESO Measurement System Standard Rev 1 (dated September 18, 2007)

• AESO Generation and Load Interconnection Standard (dated September 19, 2006)

• Technical Requirements (Part 3) for Connecting Transmission Facilities (dated December 29, 1999)



• AESO Alberta Interconnected Electric System Protection Standard (dated December 1, 2004)

• AESO Operational Voice Communication Standard (dated September 7 2005)

• AESO SCADA Standard (dated September 6, 2005)

• AESO Transmission Modeling Data Requirements ( dated April 29, 2003)

• AESO PMU Requirements Version 2.0 (dated July 6, 2005)

• AESO Wind Power Technical Requirements (dated November 15, 2004)

5.3 SUBSTATION EQUIPMENT SPECIFICATIONS

All transmission equipment must meet the following minimum specifications:

• Temperature rating of -50ºC for all outdoor equipment.

• Equipment maximum and minimum voltage ratings as indicated in Table 1

• Minimum continuous equipment current ratings as indicated in Table 2

• Maximum Fault Level 31.5kA at 144 kV and 40kA at 240kV

Table 1: Equipment Maximum and Minimum Voltages (kV)

Area 72 kV 144 kV 240 kV 500 kV

Minimum 65 130 220 500

Maximum 78 155 275 550

Note: Typical transmission operating voltages can be found in OPP #702.

Table 2: Minimum Continuous Equipment Current Ratings (A)

Component 69/72 kV 138/144 kV 240 kV

Main Bus1 1200 1200 2000

Cross Bus2 600 600 2000

Feeder3 600 600 2000

1. Main bus includes all sections of ring bus scheme and single bus of simple bus scheme. 2. Cross bus includes diameter sections of breaker and a half or breaker and a third schemes. 3. Feeder includes all equipment from the connection to the low voltage bus to the riser pole.



5.4 ATCO SCOPE OF WORK (STAGE I)

5.4.1 General Requirements

• Carry out transmission line routing, insulation coordination and protection coordination studies.

• Install station terminal control (e.g. 3 pole tripping and re-closing provisions), supervisory control and data acquisition facilities.

• Undertake all required grounding studies, testing and mitigation to ensure the facilities are safe.

• Ensure project safety is appropriately managed from design through construction.

• Carry out all site preparation, fencing, foundations, grounding, support structures, termination structures, cabling, bus work, station service, control building, protection, controls, SCADA equipment, etc. as required to complete the additions and/or modifications outlined in this Functional Specification.

5.4.2 Conversion of St. Paul 707S and Willingdon 711S

5.4.2.1 Transmission Lines

o Build approximately 5km in length of 266.8 MCM ACSR single circuit from 7L92 tap off point to Watt Lake 956S (new Willingdon substation). The tap off point is approximately midway between Vegreville 709S and Vilna 777S.

o Facility code of the tapped line is 7LA92.

o Build approximately 32km in length of 266.8 MCM ACSR double circuit from 7L70 connection point to St. Paul 707S. (7L70 will be split approximately midway between Bonnyville and Whitby Lake.)

o Re-number facility code of the 144 kV line between St. Paul 707S and Whitby Lake 819S as 7L139.

o Retain facility code of the 144 kV line between St. Paul 707S and Bonnyville 700S as 7L70.

o Retain existing 72kV line 6L79 at Vegreville 709S and Watt Lake 956S (new Willingdon substation) ends. This line will serve as back up supply from Vegreville 709S.

o Disconnect existing 72kV line 6L79 at Willingdon 711S and St. Paul 707S. Disconnect existing 72 kV line 6L82 at St. Paul 707S and Bonnyville 700S. Portion of these lines may be retained for use by ATCO



Distribution due to large amount of distribution line understrung on the existing structures.

5.4.2.2 St. Paul 707S Substation (Appendix 7.3.3)

o Design, procure, install and commission the following equipment:

Expand existing site to allow for 144kV bay development.

Two (2)144 kV line breakers c/w three phase sets of CTs and associated ganged manual disconnects.

Terminate the new line 7L139 from Whitby Lake 819S.

Terminate the new line 7L70 from Bonnyville 700S.

Two (2)144 kV transformer breakers c/w associated ganged manual breaker disconnects.

One (1) set three phase 144 kV bus PTs.

Two (2) 144/25kV 25/33.3/41.6 MVA POD transformers with +5/-15% LTC – specified for low noise emission.

Two (2) 25kV motor-operated load break switches (one for each transformer)

One (1) 25kV bus tie load break switch.

Demobilize all 72kV equipment and 25kV voltage regulators 501VR, 502VR and 503VR.

All necessary changes including protection changes, apparatus renumbering and associated drawing revisions.

o Protection Requirements:

Install a set of “A” and “B” line protections as required for 7L139 and 7L70 lines at St. Paul 707S substation.

Add breaker fail protection as required to the 144 kV circuit breakers associated with 7L139 and 7L70 lines.

Install all other required protection and control equipment at St. Paul 707S substation to accommodate the additional equipment as per AESO’s Protection standard.

o SCADA Requirements:



Addition of status, analog, control and alarm information at St. Paul 707S, which is to be communicated to TFO’s control centre and the AESO control centre for real time operations.

o Telecommunication Requirements:

Install telecommunication equipment as required at St. Paul 707S for protection signaling and SCADA communication.

5.4.2.3 Watt Lake 956S (Appendix 7.3.10)


Relocate existing Willingdon 711S substation and convert to 144kV.

One (1) 144 kV transformer breaker c/w associated ganged manual disconnects.

One (1) set three phase 144 kV bus PTs.

One (1) 144/25kV 15/20/25 MVA POD transformer with +5/-15% LTC.

One (1) 144 kV ganged manual line disconnect.

Terminate the new line 7LA92 which tapped on to 7L92 line at approximately the mid point between Whitby Lake 819S and Vegreville 709S.

One (1) 25kV motor-operated load break switch.

Two (2) 25kV breakers and associated switches.

Install the following equipment to facilitate a back up supply from Vegreville 709S:

• One (1) 72kV circuit breaker c/c associated ganged manual disconnects.

• Two (2) 72/25 kV 6/8MVA transformers.

• Two (2) 25 kV voltage regulators.

• Two (2) 25 kV breakers with associated switches.





Install all required protection and control equipment at Watt Lake 956S substation to accommodate the additional equipment as per AESO’s Protection standard.


Addition of status, analog, control and alarm information at Watt Lake 956S, which is to be communicated to TFO’s control centre and the AESO control centre for real time operations.


Install telecommunication equipment as required at Watt Lake 956S for protection signaling and SCADA communication.

5.4.2.4 Willingdon 711S Substation (Appendix 7.3.5)

o Demobilize 6L79D4 and existing two 25kV bays.

o Re-install 72kV breaker, transformer and voltage regulator at Watt Lake 956S as required to retain back-up supply for the town load.

5.4.2.5 Bonnyville 700S Substation (Appendix 7.3.1)


One (1) 144 kV transformer breaker c/w and associated ganged manual disconnects.

Two (2) new 25kV breakers c/w associated CTs and disconnects to replace 5L17 and 5L47 bays to line up with the new POD transformer location.

One (1) 144/25kV 25/33.3/41.6 MVA POD transformer with +5/-15% LTC.

Two (2) 25kV motor-operated load break switches (one for the new transformer, one to replace the existing transformer LS switch)

One (1) 25kV bus tie load break switch.

Demobilize existing 25kV 5L17 and 5L47 bays.

Demobilize all 72kV equipment and the 144/72kV tie transformer.

Retain line number 7L70, change destination substation from Whitby Lake 819S to St. Paul 707S after completion of this project.





Install all required protection and control equipment at Bonnyville 700S substation to accommodate the additional equipment as per AESO’s Protection standard.


Addition of status, analog, control and alarm information at Bonnyville 700S, which is to be communicated to TFO’s control centre and the AESO control centre for real time operations.


Install telecommunication equipment as required at Bonnyville 700S for protection signaling and SCADA communication.

Note: Further Development is proposed for Bonnyville 700S under Cold Lake Area Reinforcement – Part II. Refer to section 5.4.4 for details.

5.4.2.6 Whitby Lake 819S Substation (Appendix 7.3.7)


One (1) 144 kV line breaker c/w three phase sets of CTs and associated ganged manual breaker/line disconnects.

Salvage auto-sectionalizing scheme and associated PTs.

Renumber line 7L70 to 7L139, change destination substation from Bonnyville 700S to St. Paul 707S after completion of this project.



Install a set of “A” and “B” line protections as required for 7L139 line at Whitby Lake 819S substation.

Add breaker fail protection as required to the 144 kV circuit breaker associated with 7L139 line.

Install all other required protection and control equipment at Whitby Lake 819S substation to accommodate the re-built line as per AESO’s Protection standard.




Addition of status, analog, control and alarm information at Whitby Lake 819S, which is to be communicated to TFO’s control centre and the AESO control centre for real time operations.


Install telecommunication equipment as required at Whitby Lake 819S for protection signaling and SCADA communication.

5.4.3 Cold Lake Area Reinforcements – Part I


o Build approximately 2km of 1x477 MCM ACSR double circuit lines 7L157 and 7L160 from Mahihkan 837S to the new Bourque 970S substation.

o OPGW to be installed in the shield wire to accommodate line differential protection on these short lines.

5.4.3.2 Bourque 970S Substation (Appendix 7.3.11)

Build a new switching station designated as Bourque 970S in the vicinity of existing Mahihkan 837S substation. The switching station shall initially consist of the 144 kV switchyard with a breaker and one-third bus configuration.

o Major equipment in the new substation shall include the following:

Five (5) 144 kV breakers c/w isolation switches and CTs in a breaker and one third arrangement.

Seven (7) sets of three phase 144 kV PTs (One (1) set for each of the five (5) line terminals and one (1) set for each of the 144kV buses).

Five (5) 144 kV motorized line disconnects.

Terminate the new lines 7L157 & 7L160 from Mahihkan 837S.

Terminate the re-built line 7L83 from Leming Lake 715S.

Terminate the re-built line 7L74 from Wolf Lake 822S.

Terminate the new line 7L146 from Bonnyville 700S.

All site preparation, fencing, foundations, grounding, support structures, termination structures, cabling, bus work, station service, control building, protection, controls, SCADA equipment &



Control Center data mapping and verifications, etc. as required for this new substation.

Allow sufficient land for the substation ultimate configuration of possible 240kV tie transformer and line with a one and one-half breaker arrangement on the 240kV section and expansion capabilities on the 144 kV breaker and one-third arrangement.


Install a set of “A” and “B” line protections as required for 7L157, 7L160, 7L83, 7L74 and 7L146 lines at Bourque 970S substation.

Add breaker fail protection as required to the 144 kV circuit breakers associated with 7L157, 7L160, 7L83, 7L74 and 7L146 lines.

Install all other required protection and control equipment at Bourque 970S substation to accommodate the re-built lines as per AESO’s Protection standard.


Addition of status, analog, control and alarm information at Bourque 970S, which is to be communicated to TFO’s control centre and the AESO control centre for real time operations.


Install fibre optic telecommunication equipment as required at Bourque 970S for protection signaling and SCADA communication.

Note: Further Development is proposed for Bourque 970S under Cold Lake Area Additions (Year 2017). Refer to section 5.5.3 for details.

5.4.3.3 Mahihkan 837S Substation (Appendix 7.3.9)


Remove line 7L83 and terminate the new line 7L157 from Bourque 970S.

Remove line 7L74 and terminate the new line 7L160 from Bourque 970S.



Install a set of “A” and “B” line protections as required for 7L157 and 7L160 lines at Mahihkan 837S substation.




Install all other required protection and control equipment at Mahihkan 837S substation to accommodate the new lines as per AESO’s Protection standard.


Addition of status, analog, control and alarm information at Mahihkan 837S, which is to be communicated to TFO’s control centre and the AESO control centre for real time operations.


Install fibre optic telecommunication equipment as required at Mahihkan 837S for protection signaling and SCADA communication.

5.4.4 Cold Lake Area Reinforcements – Part II


o Build approximately 50km of 2x795 MCM ACSR double circuit line with only one side strung from Bonnyville 700S to the new Bourque 970S substation. The line shall be built to 240kV standard and initially energized at 144 kV. The new line shall be designated as 7L146.

o OPGW to be installed in the shield wires.

5.4.4.2 Bonnyville 700S Substation (Appendix 7.3.1)

Design, procure, install and commission the following equipment:

o One (1) 144 kV line breaker c/w three phase sets of CTs and associated ganged manual disconnects.

o Relocate 7L24 into the new bay.

o Terminate the new line 7L146 from Bourque 970S into existing 7L24 bay (after 7L24 relocation).

o Salvage existing SVC and SVC building including breaker 700, 703T, 700D3 and all 6.6kV and associated equipment.

o All necessary changes including protection changes, apparatus renumbering and associated drawing revisions.




Install a set of “A” and “B” line protections as required for 7L24 and 7L146 lines at Bonnyville 700S substation.


Install all other required protection and control equipment at Bonnyville 700S substation to accommodate the new and re-located lines as per AESO’s Protection standard.


Addition of status, analog, control and alarm information at Bonnyville 700S, which is to be communicated to TFO’s control centre and the AESO control centre for real time operations.


Install fibre optic telecommunication equipment as required at Bonnyville 700S for protection signaling and SCADA communication.

5.4.5 Cold Lake Area Reinforcements – Part III


o Re-build existing 144 kV line 7L87 on new right of way (‘ROW”), approximately 15 km in length, from Marguerite Lake 826S substation to Wolf Lake 822S substation with 1x795 MCM ACSR conductor per phase. Install OPGW in the shield wire for existing tele-protection scheme. Salvage existing 7L87 after the new line is in service.

o Re-build existing 144 kV line 7L74 on new ROW, approximately 20 km in length, from Bourque 970S substation to Wolf Lake 822S substation with 1x795 MCM ACSR conductor per phase. Install Dual OPGW in the shield wires for existing tele-protection scheme. Salvage existing 7L74 after the new line is in service.

o Re-build existing 144 kV line 7L83, approximately 10 km in length, from Bourque 970S substation to Leming Lake 715S substation with 1x477 MCM ACSR conductor per phase on a new ROW. Install OPGW in the shield wire for existing tele-protection scheme. Salvage existing 7L83 line.

5.4.5.2 Leming Lake 715S Substation




Remove existing line 7L83 and terminate the re-built line 7L83 (no change in facility code) from Bourque 970S.

All necessary changes including protection changes and associated drawing revisions.

Salvage the SEL-79 relay on 7L66 and thermal protection scheme.


Install a set of “A” and “B” line protections as required for 7L83 line at Leming Lake 715S substation.


Install all other required protection and control equipment at Leming Lake 715S substation to accommodate the re-built line as per AESO’s Protection standard.


Addition of status, analog, control and alarm information at Leming Lake 715S, which is to be communicated to TFO’s control centre and the AESO control centre for real time operations.


Install fibre optic telecommunication equipment as required at Leming Lake 715S for protection signaling and SCADA communication.

5.4.5.3 Wolf Lake 822S Substation


Remove existing line 7L74 and terminate the re-built line 7L74 (no change in facility code) from Bourque 970S.

Remove existing line 7L87 and terminate the re-built line 7L87 (no change in facility code) from Marguerite Lake 826S.

All necessary changes including protection changes and associated drawing revisions.


Install a set of “A” and “B” line protections as required for 7L74 and 7L87 lines at Wolf Lake 822S substation.




Install all other required protection and control equipment at Wolf Lake 822S substation to accommodate the re-built lines as per AESO’s Protection standard.


Addition of status, analog, control and alarm information at Wolf Lake 822S, which is to be communicated to TFO’s control centre and the AESO control centre for real time operations.


Install fibre optic telecommunication equipment as required at Wolf Lake 822S for protection signaling and SCADA communication.

5.4.5.4 Marguerite Lake 826S Substation (Appendix 7.3.8)


Remove existing line 7L87 and terminate the re-built line 7L87 (no change in facility code) from Wolf Lake 822S.


Salvage the SEL-79 relay on 7L89 and thermal protection scheme.

Remove the SEL-2100 relay and thermal protection schemes for 7L89 and 7L66 sending signal to ESSO Mahkeses as well as AEC at Foster Creek.


Install a set of “A” and “B” line protections as required for 7L87 line at Marguerite Lake 826S substation.


Install all other required protection and control equipment at Marguerite Lake 826S substation to accommodate the re-built line as per AESO’s Protection standard.


Addition of status, analog, control and alarm information at Marguerite Lake 826S, which is to be communicated to TFO’s control centre and the AESO control centre for real time operations.




Install fibre optic telecommunication equipment as required at Marguerite Lake 826S for protection signaling and SCADA communication.

Note: Further Development is proposed for Marguerite Lake 826S under Cold Lake Area Additions (Year 2017). Refer to section 5.5.3 for details.

5.4.6 Provost and Lloydminster Areas Line Re-builds


o Re-build existing 144 kV line 7L749, approximately 47 km in length, from Lloydminster 716S substation to AltaLink’s service boundary, with 1x477 MCM ACSR conductor per phase. Install OPGW in the shield wire for existing tele-protection scheme.

o ATCO shall coordinate with AltaLink on construction of the remaining portion of the line to Edgerton 899S substation.

5.4.6.2 Lloydminster 716S Substation


Remove existing line 7L749 and terminate the re-built line 7L749 (no change in facility code) from Edgerton 899S.



Install a set of “A” and “B” line protections as required for 7L749 line at Lloydminster 716S substation.


Install all other required protection and control equipment at Lloydminster 716S substation to accommodate the re-built line as per AESO’s Protection standard.

ATCO shall coordinate with AltaLink on protection setting changes at Edgerton 899S substation.


Addition of status, analog, control and alarm information at Lloydminster 716S, which is to be communicated to TFO’s control centre and the AESO control centre for real time operations.




Install fibre optic telecommunication equipment as required at Lloydminster 716S for protection signaling and SCADA communication.

5.4.7 Line Clearance Mitigations


o Restore ratings of the 144 kV lines 7L14, 7L701, 7L117 and 7L53 to their respective full conductor thermal capacities by mitigating line clearance issues.

5.4.8 Battle River and Lloydminster Areas Reinforcements


o Build a new double circuit 144 kV line extension, approximately 10 km in length, from Kitscoty 705S to the existing 7L14 line, with 1x266.8 MCM ACSR conductor per phase. Split the existing 7L14 to accommodate tie-in of the double circuit line from Kitscoty 705S. Install a 144 kV manual line disconnect switch, operated as normally open, at the split point.

o Build a new single circuit 144 kV line, approximately 3 km in length, from Heisler 764S to tap on existing 7L701 line, with 1x397.5 MCM ACSR conductor per phase. Install three (3) 144 kV manual line load break switches at the tap point. The line section from Heisler 764S to the tap point shall be re-numbered as 7LA701.

o Salvage the 72kV line 6L06 from Kitscoty 705S to Vermilion 710S.

5.4.8.2 Kitscoty 705S Substation (Appendix 7.3.2)


Expand substation as required to facilitate new equipment.

Install new control building and new control panel for the substation.

One (1)144 kV transformer breaker c/w associated ganged manual bus disconnects.

One (1) 144 kV manual disconnect for line bypass.

Terminate both 144 kV line sections of 7L14 from Vermilion 710S and from Hill 751S (to accommodate sectionalize motorized switches at Kitscoty).



Two (2) 144 kV line motorized disconnect switches.

One (1) set of three phase 144 kV bus PTs.

Two (2) sets of 144 kV line PTs.

One (1) 144/25kV 10/13/16.6 MVA POD transformer (re-located from Heisler 704S).

One (1) 25 kV voltage regulator (re-located from Heisler 704S).

One (1) 25kV motor-operated load break switch.

Two (2) 25kV breaker bays and re-connect existing 25kV lines.

Retain existing 72/25kV transformer as back up supply for town load.



Install a set of “A” and “B” line protections as required for 7L14 and 7L130 lines at Kitscoty 705S substation.


Install all other required protection and control equipment at Kitscoty 705S substation to accommodate the additional equipment as per AESO’s Protection standard.


Addition of status, analog, control and alarm information at Kitscoty 705S, which is to be communicated to TFO’s control centre and the AESO control centre for real time operations.


Install fibre optic telecommunication equipment as required at Kitscoty 705S for protection signaling and SCADA communication.

5.4.8.3 Hill 751S Substation





5.4.8.4 Heisler 764S Substation (Appendix 7.3.6)


Expand substation as required to facilitate new equipment.

Install new control building and new control panel for the substation.

One (1) 144 kV transformer breaker c/w associated ganged manual breaker disconnects.

One (1) 72/25kV 6/8 MVA POD transformer (from maintenance spares).

One (1) 144kV line disconnect switch.

Terminate 144 kV line 7LA701.

One (1) set of three phase144 kV bus PTs.

One (1) 144-72/25kV 25/33 MVA POD transformer that is re-located (after refurbishment) from Vermilion 710S.

One (1) 72kV transformer breaker associated ganged manual disconnects.

One (1) 72kV motorized disconnect switch.

One (1) set of 72kV three phase bus PTs.

One (1) 25 kV voltage regulator that is relocated from Vermilion 710S.

Two (2) 25kV motor-operated load break switches.

Remove existing 72/25 kV transformer and voltage regulator and relocate it to Kitscoty 705S. Replace with 6/8/10 MVA transformer and regulator from maintenance spare.



Review and revise line protection settings as required at Strome 223S and Battle River 757S for the additional equipment at Heisler 764S substation.



Install all other required protection and control equipment at Heisler 764S substation to accommodate the additional equipment as per AESO’s Protection standard.


Addition of status, analog, control and alarm information at Heisler 764S, which is to be communicated to TFO’s control centre and the AESO control centre for real time operations.


Install telecommunication equipment as required at Heisler 764S for protection signaling and SCADA communication.

5.4.8.5 Vermilion 710S Substation (Appendix 7.3.4)


One (1) 144 kV transformer breaker c/w associated ganged manual disconnect (project team to determine whether existing 706A switch could be re-used).

One (1) 144/25kV 25/33.3/41.6 MVA POD transformer with +5/-15% LTC.

One (1) 25kV motorized load break switch.

Demobilize/Salvage 701TCS and all 72kV equipment. 144/72/25kV tie transformer and 25kV regulator to be relocated to Heisler 746S.



Install all required protection and control equipment at Vermilion 710S substation to accommodate the additional equipment as per AESO’s Protection standard.


Addition of status, analog, control and alarm information at Vermilion 710S, which is to be communicated to TFO’s control centre and the AESO control centre for real time operations.

5.4.9 Vermilion Area Voltage Support

5.4.9.1 Vermilion 710S Substation (Appendix 7.3.4)




One (1) 144 kV 25MVAr un-grounded capacitor bank.

One (1) 144 kV circuit breaker with zero crossing control, c/w three phase sets of CTs and associated ganged manual disconnects.



Install all required protection and control equipment at Vermilion 710S substation to accommodate the additional equipment as per AESO’s Protection standard.


Addition of status, analog, control and alarm information at Vermilion 710S, which is to be communicated to TFO’s control centre and the AESO control centre for real time operations.

5.5 ATCO SCOPE OF WORK (STAGE II)

5.5.1 General Requirements

• Carry out transmission line routing, insulation coordination and protection coordination studies.

• Install station terminal control (e.g. 3 pole tripping and re-closing provisions), supervisory control and data acquisition facilities.

• Undertake all required grounding studies, testing and mitigation to ensure the facilities are safe.

• Ensure project safety is appropriately managed from design through construction.

• Carry out all site preparation, fencing, foundations, grounding, support structures, termination structures, cabling, bus work, station service, control building, protection, controls, SCADA equipment, etc. as required to complete the additions and/or modifications outlined in this Functional Specification.

5.5.2 7L50 Re-build


o Re-build existing 144 kV line 7L50, approximately 160 km in length, from Battle River 757S substation to Buffalo Creek 526S substation with 1x477 MCM ACSR conductor per phase. Install OPGW in the shield wire for existing tele-protection scheme.



o ATCO shall coordinate with AltaLink on termination of the re-built 7L50 to AltaLink’s substations.

5.5.2.2 Battle River 757S Substation


o Remove existing line 7L50 and terminate the re-built line 7L50 (no change in facility code) from Buffalo Creek 526S.


o Protection Requirements

Install teleprotection on 7L50 between Battle River 757S, Jarrow 252S and Buffalo Creek 526S substations to mitigate existing sequential clearance at Jarrow 252S.

Review and revise protection settings as required on 7L50 at Battle River 757S, and Vermilion 710S substations.

ATCO shall coordinate with AltaLink on protection setting changes at affected substations.

o Telecommunication Requirements

Install fibre optic telecommunication equipment as required at Battle River 757S substation for protection signaling and SCADA communication.

5.5.3 Cold Lake Area Additions (Year 2017)


o Build approximately 20km of 2x795 MCM ACSR double circuit line with only one side strung from Bourque 970S substation to Marguerite Lake 826S substation. The line shall be built to 240kV standard and initially energized at 144 kV. The new line shall be designated as 7L163.

o OPGW to be installed in the shield wires.

5.5.3.2 Marguerite Lake 826S Substation (Appendix 7.3.8)


One (1) 144 kV line breaker c/w three phase sets of CTs and associated ganged manual breaker disconnects.

One (1) 144kV motorized line disconnect switch.



Terminate the new line 7L163 from Bourque 970S.

One (1) set of three phase 144kV PTs.




Install a set of “A” and “B” line protections as required for 7L163 line at Marguerite Lake 826S substation.


Install all other required protection and control equipment at Marguerite Lake 826S substation to accommodate the new line as per AESO’s Protection standard.


Addition of status, analog, control and alarm information at Marguerite Lake 826S, which is to be communicated to TFO’s control centre and the AESO control centre for real time operations.


Install fibre optic telecommunication equipment as required at Marguerite Lake 826S for protection signaling and SCADA communication.

5.5.3.3 Bourque 970S Substation (Appendix 7.3.12)


One (1) 144 kV line breaker c/w three phase sets of CTs and associated ganged manual breaker disconnects.


Terminate the new line 7L163 from Marguerite Lake 826S.



Install a set of “A” and “B” line protections as required for 7L163 line at Bourque 970S substation.




Install all other required protection and control equipment at Bourque 970S substation to accommodate the new line as per AESO’s Protection standard.


Addition of status, analog, control and alarm information at Bourque 970S, which is to be communicated to TFO’s control centre and the AESO control centre for real time operations.


Install fibre optic telecommunication equipment as required at Bourque 970S for protection signaling and SCADA communication.



6. TRANSMISSION SYSTEM OPERATING CHARACTERISTICS

The following sections provide data to outline the electrical environment in which the facilities outlined in the Specification will operate. TFOs and customers shall incorporate these characteristics into their facility designs and operating procedures as deemed appropriate.

6.1 SHORT CIRCUIT CURRENT LEVELS

The following short circuit current levels in Tables 3 and 4 have been developed by the AESO based on information provided by Transmission Facility Owners (“TFO’s”), Generation Facility Owners ("GFO’s") and adjacent operating areas. Available fault current levels will continue to increase as generation, transmission, and system inter-ties are added to the ATS. Although future values have been provided it is the facility owners’ responsibility to regularly verify the fault levels and review their equipment ratings for adequacy. Any future upgrades are the responsibility of the facility owner.

The following assumptions were incorporated into AESO short circuit models:

• All expected ATS generation is dispatched.

• All transmission elements are in service.

• Vbase = Vbus, MVAbase = 100



Table 3: Existing Maximum Short Circuit Current Levels

Substation Name and Number

Voltage (kV)

Pre-Fault

Voltage (p.u.)*

3 Phase Fault

Current (kA)

Positive Sequence Impedance (R1

+ jX1) (p.u.)

1 Phase Fault

Current (kA)

Zero Sequence Impedance (R0

+ jX0) (p.u.)

Briker 880S 144 1.0279 1.89 0.10836 + j0.19752 1.26 0.14335 + j0.55259

Irish Creek 706S 144 1.0239 2.66 0.07585 + j0.14023 1.68 0.11762 + j0.42504

Vermilion 710S 144 1.0186 3.66 0.05796 + j0.09920 2.48 0.05796 + j0.09909

Vermilion 710S (To be salvaged)

72 1.0548 3.29 0.09080 + j0.24848 2.66 0.08812 + j0.44600

Kitscoty 705S 72 1.0258 1.99 0.22515 + j0.35942 1.43 0.24927 + j0.93627

Hill 751S 144 1.0266 2.35 0.09659 + j0.15268 2 0.05184 + j0.28047

Hill 751S 72 1.0214 2.66 0.12669 + j0.29002 2.34 0.06488 + j0.45245

Lloydminster 716S 144 1.0281 2.29 0.09830 + j0.15696 1.86 0.06656 + j0.31976

Mahkeses 889S 144 1.0792 6.65 0.01819 + j0.06535 7.27 0.00359 + j 0.05159

Wolf Lake 822S 144 1.0835 7.69 0.01709 + j0.05636 7.19 0.01553 + j0.07084

Foster Creek 877S 144 1.0811 3.58 0.03087 + j0.12253 4.05 0.00536 + j0.09125

Primrose 859S 144 1.0746 5.73 0.02201 + j0.07522 5.91 0.00730 + j0.07355

Mahihkan 837S 144 1.0655 6.81 0.02209 + j0.06156 6.06 0.01919 + j0.08878

Leming Lake 715S 144 1.0719 7.15 0.02009 + j0.05935 7.04 0.01068 + j0.06595

Marguerite Lake 826S 240 1.0828 5.89 0.0098 + j0.04310 5.7 0.0035 + j0.04888


La Corey 1315 144 1.0785 5.01 0.03412 + j0.08306 3.86 0.04226 + j 0.16621

Ethel Lake 717S 144 1.0648 5.18 0.03173 + j0.07985 4.55 0.02358 + j0.12071

Ethel Lake 717S 72 1.0803 3.14 0.05072 + j0.28287 3.65 0.01616 + j0.16801

Grande Centre 846S 144 1.0563 4 0.04533 + j0.10056 2.97 0.05506 + j0.22046

Bonnyville 700S 144 1.0607 4.67 0.04162 + j0.08488 3.98 0.02873 + j0.14473

Bonnyville 700S (to be salvaged)

72 1.0489 3.24 0.06822 + j0.26088 3.35 0.02967 + j0.24399

IPF Lindberg 144 1.033 1.79 0.10803 + j0.21422 1.11 0.18483 + j0.66349

Heisler 764S 72 1.0426 2.06 0.23145 + j0.35451 1.46 0.28132 + j0.91095

Bigknife Creek 843S 72 1.059 5.08 0.03561 + j0.17035 4.66 0.02168 + j0.22036

Mannix Mine 765S 72 1.0585 5.01 0.03783 + j0.17221 4.53 0.02236 + j0.23232

Battle River 757S bus 1 240 1.0656 9.73 0.00493 + j0.02589 9.19 0.00326 + j0.03087


Battle River 757S 144 1.0803 11.96 0.00626 + j0.03716 9.64 0.00546 + j0.06480

Battle River 757S 72 1.0595 5.38 0.03164 + j0.16441 5.03 0.01540 + j0.19321

Bigfoot 756S 72 1.0574 3.46 0.06343 + j0.22601 2.87 0.07139 + j0.45024

Whitby Lake 819S 144 1.0389 3.31 0.05657 + j0.11795 2.14 0.09431 + j0.33423

Vilna 777S 144 1.0371 3.16 0.05947 + j0.12300 2.03 0.09936 + j0.35333

Willingdon 711S 72 1.0087 1.78 0.18045 + j0.43506 1.48 0.11768 + j0.76517

Vegreville 709S 144 1.0205 3.83 0.04974 + j0.09901 2.82 0.05062 + j0.22844

Vegreville 709S 72 1.0218 3.2 0.06523 + j0.25766 3.07 0.04424 + j0.29790

St. Paul 707S (To be salvaged)

72 1.0165 1.49 0.25278 + j0.50728 1.51 0.06207 + j0.57360

Paintearth Creek 863S 240 1.0659 6.16 0.00882 + j0.04070 4.55 0.01949 + j0.08346

Cordel 755S 240 1.0656 9.76 0.00494 + j0.02580 9.18 0.00340 + j0.03115



Table 3: Estimated Year 2017 Maximum Short Circuit Current Levels

Substation Name & Number

Voltage (kV)

Pre-Fault

Voltage (p.u.)*

3 Phase Fault

Current (kA)

Positive Sequence Impedance

(R1 + jX1) (p.u.)

1 Phase Fault

Current (kA)

Zero Sequence Impedance

(R0 + jX0) (p.u.)

Briker 880S 144 1.0649 2.36 0.07247 + j0.17455 1.64 0.09715 + j0.42912

Irish Creek 706S 144 1.0462 2.92 0.06700 + j0.13448 1.8 0.11613 + j0.41949

Vermilion 710S 144 1.0556 3.92 0.05157 + j0.10070 2.61 0.07316 + j0.27556

Vermilion tap sub (NEW)

144 1.0499 3.48 0.05481 + j0.11426 2.21 0.08912 + j0.33427

Kitscoty 705S (NEW) 144 1.0695 2.88 0.07076 + j0.13904 2.23 0.06622 + j0.28761

Kitscoty 705S 72 1.0788 1.22 0.35045 + j0.65614 1 0.36117 + j1.19765

Hill 751S 144 1.0824 2.64 0.07794 + j0.15349 2.58 0.02547 + j0.18865

Hill 751S 72 1.078 2.49 0.09898 + j0.34968 3.32 0.00769 + j0.09198

Lloydminster 716S 144 1.0819 2.64 0.07563 + j0.15449 2.4 0.03888 + j0.22689

Mahkeses 889S 144 1.0797 8.19 0.01197 + j0.05395 8.54 0.00348 + j0.04908

Wolf Lake 822S 144 1.0624 9.53 0.01003 + j0.04571 7.97 0.01371 + j0.07372

Foster Creek 877S 144 1.0726 3.76 0.02900 + j0.11610 4.24 0.00494 + j0.08747

Primrose 859S 144 1.0383 7.66 0.01186 + j0.05561 6.7 0.00822 + j0.08211

Bourque 970S (NEW) 144 1.0651 10.88 0.00957 + j0.03994 9.25 0.01085 + j0.06229

Mahihkan 837S 144 1.0648 10.46 0.01001 + j0.04151 8.54 0.01282 +j0.07086

Leming Lake 715S 144 1.0712 9.42 0.01243 + j0.04605 8.81 0.00884 + j0.05744



La Corey 1315 144 1.0641 5.61 0.02847 + j0.07431 4.09 0.04168 + j0.16419

Ethel Lake 717S 144 1.0626 6.03 0.02522 + j0.06953 5.03 0.02289 + j0.11697

Ethel Lake 717S 72 1.0798 3.28 0.04525 + j0.27211 3.79 0.01584 + j0.16589

Grande Centre 846S 144 1.0527 4.44 0.03821 + j0.09188 3.14 0.05440 + j0.21784

Enb_Bonn (NEW) 144 1.0516 3.22 0.05322 + j0.12642 2.1 0.09002 + j0.34729

Bonnyville 700S 144 1.0578 6.46 0.02244 + j0.06495 5.05 0.02444 + j0.12504

IPF Lindberg 144 1.0435 2.2 0.08432 + j0.18077 1.33 0.15717 + j0.57407

Heisler 764S (NEW) 144 1.0763 4.96 0.02570 + j0.08750 3.2 0.05101 + j0.23648

Heisler 764S 72 1.066 3.69 0.08104 + j0.22882 3.02 0.07561 + j0.40140

Bigknife Creek 843S 72 1.0657 6.13 0.03132 + j0.14262 5.42 0.02377 + j0.20330

Mannix Mine 765S 72 1.0668 5.72 0.03669 + j0.15243 4.76 0.01913 + j0.25242



Battle River 757S 144 1.094 12.33 0.00563 + j0.03698 10.47 0.00444 + j0.05743

Battle River 757S 72 1.0656 6.41 0.02778 + j0.13689 5.92 0.01581 + j0.17430

Bigfoot 756S 72 1.0634 4.31 0.05953 + j0.19857 3.15 0.07180 + j0.43133

Whitby Lake 819S 144 1.0349 2.78 0.06858 + j0.14031 1.7 0.12299 + j0.43796

Vilna 777S 144 1.0337 2.73 0.07026 + j0.14282 1.68 0.12434 + j0.44569

Watt Lake 956S (NEW) 144 1.0311 2.54 0.07510 + j0.15328 1.63 0.12194 + j0.44368

Willingdon 711S 72 1.0885 1.37 0.21341 + j0.63415 0.9 0.32750 + j1.69379

Vegreville 709S 144 1.0318 3.74 0.05102 + j0.10408 2.76 0.04902 + j0.23847

Vegreville 709S 72 1.0874 2.92 0.06499+ j0.30658 2.8 0.04899 + j0.35003

St. Paul 707S (NEW) 144 1.0439 2.68 0.06972 + j0.14828 1.64 1.12684 + j0.46072

Paintearth Creek 863S 240 1.077 7.6 0.00684 + j0.03360 5.8 0.01538 + j0.06452

Cordel 755S 240 1.0799 11.5 0.00414 + j0.02236 11.6 0.00245 + j0.02255



6.2 INSULATION LEVELS

Table 6 provides the minimum required Basic Insulation Levels (“BIL”) levels for the ATS. Station equipment with lower BIL levels can be used provided protection and coordination can be maintained with judicious insulation design and use of appropriate surge arresting equipment. For 25 kV circuit breakers where there is a grounded wye transformer and surge arrestors are installed a BIL of 125 kV is acceptable.

Table 6: BIL Levels (kV)

Nominal Voltage Classification (kV rms)

240 144/138 72/69 25

Station Post Insulators and Airbreaks

900 550 350 150

Circuit Breakers 1050 650 350 150

Current and Potential Transformers

1050 650 350 150

Transformer Windings (Protected by Surge Arresters))

850 550 350 125

6.3 OPERATIONAL CONSTRAINTS

No Operational Constraints have been identified at this stage of the project.



7. APPENDICES

7.1 CENTRAL EAST REGION TRANSMISSION SYSTEM - EXISTING



7.2 CENTRAL EAST REGION TRANSMISSION SYSTEM - PROPOSED

DEVELOPMENTS

7L

749

Briker880S

Lloydminster 716S

7L12

9 (7

L50)

Buffalo Creek 526S

701

L

Sedgewick 137S

Hardisty 377S

Wainwright 51S

704

L

Rosyth296S

HRT Express 329S

704AL

Edgerton 899S

Provost 545S

Hayter 277S

703L

Paintearth863S

9L279L948/948L

9L953/953L

Battle River 757S Cordel

755S

756S

765S

843S

701

L

Heisler 764S

6L0

5

Wainwright

Provost

Battle River

Bardo197S

7L50

702L

9L20715L

Hansman Lake 650S

61

AL

61L

Vermilion 710S

7L50

7L14

174L Vegreville709S

7L65

7L77

7L702

Hill 751S

7L42

7LB749

7L

749

748L

74

9L

703BL

North Holden395S

Strome223S

Cochin968S

Hughenden213S

Sunken Lake221S

Nevis766S

7L5

3

Irish Creek 706S

Tucuman 478S

769L

703AL

7L70

6L82

La Corey721S

Leming Lake715S

7L

35

7L89

9L36

Foster Creek

Primrose859S

Mahkeses889S

Marguerite Lake826S

Bonnyville700S

Wolf Lake822S

Grand Centre846S

877S1200S

Ethel Lake717S

Existing 69/72 kV

Existing 138/144 kV

Existing 240 kV

Generator

Substation

7L7

4 7L10

5

MahNo909S

9L37

Approved Substation

IPFLindbergh

969S

Foster CreekGeneration Station

St. Paul707S

Watt Lake 956S(New

Willingdon)

6L79

6L7

9

7L91

7L66

7L28

7L24

7L89

7L87

7L83

7L74

7L86

7L95

Cold Lake

Lloydminster

68

1L

7L24

953L

Legend

Vilna 777S

Whitby Lake 819S

7L9

2

New Mahihkan

Kitscoty 705S

Rebuilt 138/144 kV

New 138/144 kV

New 240 kV

Salvaged Line

Proposed Substation

Notes: Developments reflect 2012 ISD, unless otherwise specified.

Proposed in Hanna NID

Nilrem 574S Killarney Lake

267S

Metiskow 648S

Jarrow 252S

Energized at 144 kV

ISD 2017;Energized at 144 kV

749

L

Alternative 2 - 240 kV from Nilrem to New Vermilion

Clearance mitigations on 7L701,7L14, and 7L53.

Mahihkan837S

May convert to

Distributio

n

May convert to

Distributio

n

ISD 2017

ISD 2017

6L06

7L117

To Anderson

801S

9L

59

Nabiye

Customer Project



7.3 SUBSTATION SINGLE LINE DIAGRAMS

7.3.1 Bonnyville 700S Substation – Proposed Development

Bonnyville 700S

144 kV811-SLD-700S


Proposed Stage 1 Configuration

To Upgraded

144 kV bus atSt. Paul 707S

25/33.3/41.6 MVA

7L24(Relocated from

existing bay)

144/25 kV

To New

Bourque 970S 7L146(Terminated to existing bay previously for 7L24)

SVC

72 kV

605T6/8 MVA

25 kV

604T6/8 MVA 25 kV

Convert to Distribution (Line number will be re-

assigned)

Legend

Circuit Breaker

Solid Disconnect Switch

Ganged Air Switch(Manual Operation)

Ganged Air Switch (Motor Operated)

Proposed Scope

Salvaged Equipment

Proposed Addition/Change

701T144/72kV

25/33.3/41.6 MVA

15/20/25 MVA

702T144/25 kV

5L17

5L47

5L83

5L414

5L47

5L17

To Marguerite

Lake

7L89

7L70

To Vermilion via Irish Creek

7L53

C/S

16.2 MVAr

16.2 MVAr

16.8 MVAr (Ungrounded)

To Grand Centre

Note: Salvage all 6.6kV equipment associated with the SVC which are not shown in this simplified SLD.



7.3.2 Kitscoty 705SSubstation – Proposed Development

Legend

Kitscoty 705S

811-SLD-705S



Regulator

To Vermilion 710S

25 kV

6L06

Circuit Breaker




144 kV

144/25 kV10/13.3/16.6 MVA

601T72/25 kV6/8 MVA

To Hill 751S

6L06

N.O.

To Vermilion 710S

To Hill 751S

Regulator

25 kV

Transformer retained as

back-up supply

7L14

7L130

Proposed Scope

Salvaged Equipment




7.3.3 St. Paul 707S Substation – Proposed Development

St. Paul 707S

144 kV

811-SLD-707S



To Whitby Lake

819S25 kV

72 kV

603T15/20/25 MVA

25 kV

601T6/8 MVA

25 kV

602T6/8 MVA

25 kV

25 kVTo

Bonnyville 700S

Legend

Circuit Breaker




7L70

7L139

Convert to Distribution (Line

number will be re-assigned)


assigned)

Proposed Scope

Salvaged Equipment


25/33.3/41.6 MVA

25/33.3/41.6 MVA

144/25 kV

144/25 kV



7.3.4 Vermilion 710S Substation – Proposed Development

Legend

Vermilion 710S

811-SLD-710S



144/25 kV

7L14

Circuit Breaker




144 kV

To Hill 751S

7L53ToBonnyville 700S via Irish Creek)

ToVegreville 709S 7L65

7L129ToBuffalo Creek

526S

701T144/72/25 kV25/33 MVA 72 kV

To Kitscoty 705S

6L06

25 kV

25 kV

25 MVAr

** Relocate 701T to Heisler

764S

Proposed Scope

Salvaged Equipment


25/33.3/41.6 MVA



7.3.5 Willingdon 711S Substation – Proposed Development

Willingdon 711S

811-SLD-711S



72 kV

601T6/8 MVA

602T6/8 MVA

Legend

Circuit Breaker



Ganged Air Switch (Motor Operated) Proposed Scope

Salvaged Equipment


Regulator

25 kV

5L42

Regulator

5L334

6L79 to St. Paul

6L79 to

Vergreville



7.3.6 Heisler 764S Substation – Proposed Development

Legend

Heisler 764S

811-SLD-764S



Regulator72/25 kV6/8 MVA

To 6L02 Junction

25 kV

6L05

Circuit Breaker




144 kV

To Strome 223S

To Battle River 757S

7L701

7L701

144/72/25 kV25/33 MVA

72 kV

Regulator601T72/25 kV

10/13.3/16.6 MVA

** Relocate 601T & Regulator to Kitscoty 705S

7LA701

Proposed Scope

Salvaged Equipment


Regulator

$$

##

$$

##

##

$$ --From maintenance spares

--Relocated from Vermilion 710S



7.3.7 Whitby Lake 819S Substation – Proposed Development

Whitby Lake 819S

811-SLD-819S



144 kV

7L139

ToLac La Biche

7L92

Legend

Circuit Breaker




ToSt. Paul 707S

ToVergerville (via Vilna)

7L794

Proposed Scope

Salvaged Equipment




7.3.8 Marguerite Lake 826S Substation – Proposed Development

Legend

Marguerite Lake 826S

811-SLD-826S


Proposed Configuration

901T240/144 kV

120/160/200 MVA

902T240/144 kV

120/160/200 MVA

To Wolf Lake

822S

To Bourque

970S

To Leming Lake

715S

To Bonnyville

700S

7L87Re-build

7L1637L91

Circuit Breaker




To 240 kV Network To 240 kV

Network

144 kV144 kV

7L89

Proposed Scope

Salvaged Equipment




7.3.9 Mahihkan 837S Substation – Proposed Development

Mahihkan 837S

811-SLD-837S



144 kV

701T22/33.3/41.5 MVA

25 kV7L157

702T25/33/41.6 MVA

25 kVTo

Bourque 970S (re-use existing bay)

7L160

ToMahNo 909S

7L105

Legend

Circuit Breaker




ToBourque 970S (re-use

existing bay)

Proposed Scope

Salvaged Equipment




7.3.10 Watt Lake 956S Substation – Proposed Development

Watt Lake 956S(New Willingdon)

144 kV

144 / 25 kV15/20/25 MVA

811-SLD-956S



To 7L92 tap point

25 kV

Legend

Circuit Breaker




Proposed Scope

Salvaged Equipment


5L42

5L334

Note: Re-install 72kV breaker, transformer and regulator, salvaged from Willingdon 711S, as required to retain back up supply to the town load.

72 kV

601T6/8 MVA

602T6/8 MVA

Regulator

25 kV

Regulator

6L79 to

Vergreville



7.3.11 Bourque 970S Substation – Proposed Development

Legend

Bourque 970S

811-SLD-970S



144 kV

144 kV

Circuit Breaker




To Leming Lake 715S

To Mahihkan 837S

7L157

To Wolf Lake 822S

7L83

7L74

To Bonnyville 700S

To Mahihkan 837S

7L146

7L160

Proposed Scope

Salvaged Equipment




7.3.12 Bourque 970S Substation – Proposed 2017 Development

Legend

Bourque 970S

811-SLD-970S



144 kV

144 kV

Circuit Breaker




To Leming Lake 715S

To Mahihkan 837S

7L157

To Wolf Lake 822S

7L83

7L74

To Bonnyville 700S

To Mahihkan 837S

7LXXX

To Marguerite Lake

826S

7L163

7L160

Proposed Scope

Salvaged Equipment




7.4 ENERGY DATA REQUIREMENTS

7.4.1 SCADA Point Requirements

7.4.1.1 Bonnyville 700S Substation

Bonnyville 700S

144 kV811-SLD-700S



To Upgraded

144 kV bus atSt. Paul 707S

25/33.3/41.6 MVA

7L24(Relocated from

existing bay)

144/25 kV

To New

Bourque 970S 7L146(Terminated to existing bay previously for 7L24)

SVC

72 kV

605T6/8 MVA

25 kV

604T6/8 MVA 25 kV



Legend

Circuit Breaker




Proposed Scope

Salvaged Equipment


701T144/72kV

25/33.3/41.6 MVA

15/20/25 MVA

702T144/25 kV

5L17

5L47

5L83

5L414

5L47

5L17

To Marguerite

Lake

7L89

7L70

To Vermilion via Irish Creek

7L53

C/S

16.2 MVAr

16.2 MVAr

16.8 MVAr (Ungrounded)

To Grand Centre

Note: Salvage all 6.6kV equipment associated with the SVC which are not shown in this simplified SLD. RTU Failure Alarm

Communication Failure Alarm

Generator Regulating Control Status (Enabled/Disabled)

Generator MW setpoint from the generator’s control system (Analog)

MW setpoint to the Plant (Analog)

Voltage Regulation System Status (Enabled/Disabled)

Voltage Regulation System Setpoint (Analog)

Generator Mode (voltage control or constant pf)

Frequency

PSS and AVR Status

Wind Speed and Direction Analogs

RAS Armed and Operated Status

MVAR Analog

LTC Tap Position (Analog)

Voltage (kV) Analog

MW/MVar Analogs

Status

High and Low Regulation Range Limit in MW (Analog)

A status indication that AESO has control over the resource

DATA TO AESO

DATA FROM AESO

11

22

33

44

55

66

77

88

99

14

16

19

18

LTC Auto/Manual Status

910

VAR Compensating Device Status & target voltage

Total RAS MW Load available and MW Load armed

911

912

913

915

916

917

20

51

52

22

11

11



7.4.1.2 Kitscoty 705S Substation

Legend

Kitscoty 705S

811-SLD-705S



Regulator

To Vermilion 710S

25 kV

6L06

Circuit Breaker




144 kV

144/25 kV10/13.3/16.6 MVA

601T72/25 kV6/8 MVA

To Hill 751S

6L06

N.O.

To Vermilion 710S

To Hill 751S

Regulator

25 kV

Transformer retained as

back-up supply

7L14

7L130

Proposed Scope

Salvaged Equipment


RTU Failure Alarm








Frequency

PSS and AVR Status



MVAR Analog


Voltage (kV) Analog

MW/MVar Analogs

Status



DATA TO AESO

DATA FROM AESO

11

22

33

44

55

66

77

88

99

14

16

19

18


910



911

912

913

915

916

917

20

51

52

11

11

11

22

22

22

33



7.4.1.3 St. Paul 707S Substation

St. Paul 707S

144 kV

25/33/42 MVA

811-SLD-707S



To Whitby Lake

819S25 kV

72 kV

603T15/20/25 MVA

25 kV

601T6/8 MVA

25 kV

602T6/8 MVA

25 kV

25 kVTo

Bonnyville 700S

25/33/42 MVA

Legend

Circuit Breaker




7L70

7L139




assigned)

Proposed Scope

Salvaged Equipment


11

22

33

RTU Failure Alarm








Frequency

PSS and AVR Status



MVAR Analog


Voltage (kV) Analog

MW/MVar Analogs

Status



DATA TO AESO

DATA FROM AESO

11

22

33

44

55

66

77

88

99

14

16

19

18


910



911

912

913

915

916

917

20

51

52

11

11

11

22

22

22



7.4.1.4 Vermilion 710S Substation

Legend

Vermilion 710S

811-SLD-710S



144/25 kV25/33/42 MVA

7L14

Circuit Breaker




144 kV

To Hill 751S

7L53ToBonnyville 700S via Irish Creek)

ToVegreville 709S 7L65

7L129ToBuffalo Creek

526S

701T144/72/25 kV25/33 MVA 72 kV

To Kitscoty 705S

6L06

25 kV

25 kV

25 MVAr

** Relocate 701T to Heisler

764S

Proposed Scope

Salvaged Equipment


1122

1110

RTU Failure Alarm








Frequency

PSS and AVR Status



MVAR Analog


Voltage (kV) Analog

MW/MVar Analogs

Status



DATA TO AESO

DATA FROM AESO

11

22

33

44

55

66

77

88

99

14

16

19

18


910



911

912

913

915

916

917

20

51

52

11



7.4.1.5 Heisler 764S Substation

Legend

Heisler 764S

811-SLD-764S



Regulator72/25 kV6/8 MVA

To 6L02 Junction

25 kV

6L05

Circuit Breaker




144 kV

To Strome 223S

To Battle River 757S

7L701

7L701

144/72/25 kV25/33 MVA

72 kV

Regulator601T72/25 kV

10/13.3/16.6 MVA

7LA701

Proposed Scope

Salvaged Equipment


11

22

3344

5522

8899

RTU Failure Alarm








Frequency

PSS and AVR Status



MVAR Analog


Voltage (kV) Analog

MW/MVar Analogs

Status



DATA TO AESO

DATA FROM AESO

11

22

33

44

55

66

77

88

99

14

16

19

18


910



911

912

913

915

916

917

20

51

52

11

22

22

22

33

22

** Relocate 601T & Regulator to Kitscoty 705S



7.4.1.6 Whitby Lake 819S Substation

Whitby Lake 819S

811-SLD-819S



144 kV

7L139

ToLac La Biche

7L92

Legend

Circuit Breaker




ToSt. Paul 707S

ToVergerville (via Vilna)

7L794

Proposed Scope

Salvaged Equipment


11

22

RTU Failure Alarm








Frequency

PSS and AVR Status



MVAR Analog


Voltage (kV) Analog

MW/MVar Analogs

Status



DATA TO AESO

DATA FROM AESO

11

22

33

44

55

66

77

88

99

14

16

19

18


910



911

912

913

915

916

917

20

51

52



7.4.1.7 Marguerite Lake 826S Substation

Legend


811-SLD-826S


Proposed Configuration

901T240/144 kV

120/160/200 MVA

902T240/144 kV

120/160/200 MVA

To Wolf Lake

822S

To Bourque

970S

To Leming Lake

715S

To Bonnyville

700S

7L87Re-build

7L1637L91

Circuit Breaker




To 240 kV Network To 240 kV

Network

144 kV144 kV

7L89

Proposed Scope

Salvaged Equipment


11

RTU Failure Alarm








Frequency

PSS and AVR Status



MVAR Analog


Voltage (kV) Analog

MW/MVar Analogs

Status



DATA TO AESO

DATA FROM AESO

11

22

33

44

55

66

77

88

99

14

16

19

18


910



911

912

913

915

916

917

20

51

52

11

11



7.4.1.8 Mahihkan 837S Substation

Mahihkan 837S

811-SLD-837S



144 kV

701T22/33.3/41.5 MVA

25 kV7L157

702T25/33/41.6 MVA

25 kVTo

Bourque 970S (re-use existing bay)

7L160

ToMahNo 909S

7L105

Legend

Circuit Breaker




ToBourque 970S (re-use

existing bay)

Proposed Scope

Salvaged Equipment


1122

RTU Failure Alarm








Frequency

PSS and AVR Status



MVAR Analog


Voltage (kV) Analog

MW/MVar Analogs

Status



DATA TO AESO

DATA FROM AESO

11

22

33

44

55

66

77

88

99

14

16

19

18


910



911

912

913

915

916

917

20

51

52

2211



7.4.1.9 Watt Lake 956S Substation

Watt Lake 956S(New Willingdon)

144 kV

144 / 25 kV15/20/25 MVA

811-SLD-956S



To 7L92 tap point

25 kV

Legend

Circuit Breaker




Proposed Scope

Salvaged Equipment


5L42

5L334

Note: Re-install 72kV breaker, transformer and regulator, salvaged from Willingdon 711S, as required to retain back up supply to the town load.

72 kV

601T6/8 MVA

602T6/8 MVA

Regulator

25 kV

Regulator

6L79 to

Vergreville

RTU Failure Alarm








Frequency

PSS and AVR Status



MVAR Analog


Voltage (kV) Analog

MW/MVar Analogs

Status



DATA TO AESO

DATA FROM AESO

11

22

33

44

55

66

77

88

99

14

16

19

18


910



911

912

913

915

916

917

20

51

52

8899

33

33

111122

22 11



7.4.1.10 Bourque 970S Substation

Legend

Bourque 970S

811-SLD-970S



144 kV

144 kV

Circuit Breaker




To Leming Lake 715S

To Mahihkan 837S

7L157

To Wolf Lake 822S

7L83

7L74

To Bonnyville 700S

To Mahihkan 837S

7L146

7L160

Proposed Scope

Salvaged Equipment


22

33

RTU Failure Alarm








Frequency

PSS and AVR Status



MVAR Analog


Voltage (kV) Analog

MW/MVar Analogs

Status



DATA TO AESO

DATA FROM AESO

11

22

33

44

55

66

77

88

99

14

16

19

18


910



911

912

913

915

916

917

20

51

52

11

11

11

11

11

11

11

11

11

11

33

22

22

22

228899



7.4.1.11 Bourque 970S Substation - 2017 Development

Legend

Bourque 970S

811-SLD-970S



144 kV

144 kV

Circuit Breaker




To Leming Lake 715S

To Mahihkan 837S

7L157

To Wolf Lake 822S

7L83

7L74

To Bonnyville 700S

To Mahihkan 837S

7L146

To Marguerite Lake

826S

7L163

7L160

Proposed Scope

Salvaged Equipment


11

22

RTU Failure Alarm








Frequency

PSS and AVR Status



MVAR Analog


Voltage (kV) Analog

MW/MVar Analogs

Status



DATA TO AESO

DATA FROM AESO

11

22

33

44

55

66

77

88

99

14

16

19

18


910



911

912

913

915

916

917

20

51

52

11



7.4.2 SCADA Data Requirements

Facility / Location

Device Element Indication Update

Rate/ModeNotes

Heisler 764S

Breaker Status On Event breaker at 144/72kV low side, going to 6L05

Breaker Status On Event breaker at 144/72kV high side, going to 7LA701

line 6L05 MW 15s Outgoing MW from this station towards 6L02 Junction

line 6L05 MVAr 15s Outgoing MVAr from this station towards 6L02 Junction

line 7LA701 MW 15s Outgoing MW from this station towards 7L701 tap

line 7LA701 MVAr 15s Outgoing MVAr from this station towards 7L701 tap

144kV bus kV 15s

72kV bus kV 15s

Transformer 3 winding transformer

MW 15s MW reading at high side (flowing from high side to low side)


MVAr 15s MVAr reading at high side (flowing from high side to low side)


MW 15s MW flowing towards the transformer at 25kV winding


MVAr 15s MVAr flowing towards the transformer at 25kV winding


MW 15s MW flowing towards the transformer at 72kV winding


MVAr 15s MVAr flowing towards the transformer at 72kV winding


Analog 15s Tap position


Status On Event LTC auto/manual control status







Communications Communications Failure

Alarm On Event Ganged alarm indicating that 1 or more devices supplying data is in alarm.

Communications RTU Failure Alarm On Event AESO Internal notification that site is non-responsive

Bonnyville

700S Breaker Status On Event breaker associated with

7L146 line

Breaker Status On Event breaker associated with 144/25kV transformer

line 7L146 MW 15s Outgoing MW from this

station line 7L146 MVAr 15s Outgoing MVAr from this

station

Kitscoty 705S

Breaker Status On Event breaker associated with Line 7L14

Breaker Status On Event breaker associated with Line 7L130

MOS Status On Event MOS associated with

144/25kV transformer

144kV bus kV 15s Transformer MW 15s MW reading at high side

(flowing from high side to low side)

Transformer MVAr 15s MVAr reading at high side (flowing from high side to low side)



station


station

line 7L130 MVAr 15s Outgoing MVAr from this

station

St Paul 707S

Breaker Status On Event breaker associated with 7L70 line




Breaker Status On Event breaker for the first 144/25kV transformer

Breaker Status On Event breaker for the second 144/25kV transformer



station


station


station

Transformer 1st 144/25kV transformer


Transformer 1st 144/25kV transformer


Transformer 2nd 144/25kV transformer


Transformer 2nd 144/25kV transformer


144kV bus kV 15s

Vermilion 710S

Breaker Status On Event breaker for the 144/25kV transformer

Breaker Status On Event breaker for the capacitor bank

Transformer MW 15s MW reading at high side (flowing from high side to low side)

Transformer MVAr 15s MVAr reading at high side (flowing from high side to low side)

Capacitor Bank MVAr 15s MVAr towards the bus

Whitby Lake 819S




station





(Stage 2) MOS Status On Event MOS associated with

7L163 line line 7L163 MW 15s Outgoing MW from this


station

Whitby Lake 819S




station


station


station


station Watt Lake

956S Breaker Status On Event breaker for the 144/25kV

transformer MOS Status On Event MOS associated with

7LA92

line 7LA92 MW 15s Outgoing MW from this

station

line 7LA92 MVAr 15s Outgoing MVAr from this

station 144kV bus kV 15s

Breaker Status On Event breaker for the 69kV line

6L79


station


station



72kV bus kV 15s




Bourque 970S

Breaker Status On Event breaker between 7L83 and 7L157


Breaker Status On Event breaker between bus and 7L74


Breaker Status On Event breaker between 7L146 and bus


7L157 MOS Status On Event MOS associated with




7L160


station


station


station


station


station


station


station


station


station


station



144kV bus Bus at top kV 15s

144kV bus Bus below kV 15s




Bourque 970S (Stage

2)

Breaker Status On Event breaker between bus and 7L163


7L163


station


station

ATCO Electric Heisler Transmission Project Application to the Alberta Utilities Commission Central East Transmission Development Attachment 12 – Reference Note December 22, 2011

ATTACHMENT 12

Reference Note – Required Attachments For EAS/DDS Registration

This attachment provides information requirements in accordance with the Alberta Utilities Commission's Integrated Application Registry/Digital Data Submission (IAR/DDS) system. To avoid duplicate submission in the IAR/DDS system of an attachment that is otherwise deemed by the IAR/DDS system as a required attachment, this reference note is provided to indicate where the required attachment or information may be found and to substitute for the required or duplicate attachment. Attachments cited are considered to be submitted for the applicable facilities as referenced below.

Cross-Reference of Common Attachments

Applicable Facilities Description of

Attachment Heisler Substation

764S 7LA701

144 kV Line (7L701 to Heisler)

6L05 72 kV Line

(6L05 to Heisler) Electric Facility, Application Type

(1) Substation

(2) Transmission Lines

(3) Transmission Lines

AESO Direct Assignment Letter

Filed as Attachment 11

See Attachment 11 See Attachment 11

Application Text Filed as Attachment 1


Project Area Map Filed as Attachment 4 (Drwgs A-01 and

A-02)

See Attachment 4 (Drwgs A-01 and A-

02)

See Attachment 4 (Drwgs A-01 and A-

02) Substation Single

Line Diagram (site plan, and

electrical)

Filed As Attachment 5

(Drwgs A-04 and A-05)

n/a n/a

Air Photo Mosaics n/a Filed as Attachment 6 (Drwg A-06)

See Attachment 6

Conservation and Reclamation Plan

n/a Filed as Attachment 2 and Attachment 8

(Drwg A-08)

See Attachment 2

Functional Specification



Route Maps n/a See Attachment 6 (Drwg A-06)

See Attachment 6 (Drwg A-06)

Transmission Line Maps

n/a Filed as Attachment 7 (Drwgs A-07, RS-7SSP00, and RS-

7SSP00_U) See Attachment 6

(Drwg A-06)

See Attachment 5 (Drwg A-04)

and Attachment 7 (Drwgs A-07, RS-

7SSP00)

Public Notification Program

Filed as Attachments 3 & 10

See Attachments 3 & 10

See Attachments 3 & 10

Noise Impact Assessment


n/a n/a

Submission Filed as Attachment 5 (Drwg AC-04)

Filed as Attachment 6 (Drwg AC-06)

n/a

Switching Map Filed as Attachment 5 (Drwg A-03)

n/a n/a

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