Attachment a - Iqaluit System Report - Engish

8/9/2019 Attachment a - Iqaluit System Report - Engish

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Attachment A

Iqaluit Long Term Power Distribution System Study

o Appendix A Iqaluit 30 Year load Forecasto Appendix B Iqaluit System Key Single Line Designo Appendix C Proposed 25 kV Substation Design Philosophy


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Qulliq Energy Corporation

Long Term Power Distribution System Study

Iqaluit, NU

REVISION

NUMBER:

DATE

ISSUED:

ORIGINATED

BY:

REVIEWED

BY:

APPROVED

BY:

DOCUMENT

STATUS:

A Nov 05 AEC PM PM Issue for ReviewB Dec 05 AEC PM PM Issue for UseC July 09 AEC RB RB Revise & Re-

issue for Use

Attachment A


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Scope

This report will identify and assess current problems associated with electrical load growth on theIqaluit distribution system in the past several years and projected future problems that will occurwith continued load growth. The report will explore best cost alternative to correct problemsthrough the standard engineering economic processes, such as simple pay back, rate of return,

and cost/benefit ratios. Conceptual engineering drawing designs, calculations, and philosophieswill also be included in this report to ensure proper direction on QEC standards and requirements.

System Background

The Iqaluit distribution system consists of eight (8) radial fed, overhead wood pole structureddistribution lines of various vintages, ranging from 5 years to over 50 years old. The carriedconductor ranges from AWG #4/0 AASC conductor (current utility standard) to AWG #2 softdrawn copper conductor (1950s post war utility standard). All eight feeders are connected via aswitchgear lineup at the main plant, where the systems main generation exists. Two feeders areinter-connected (feeders 3 & 4) intermittently to the Federal standby plant located at QECsfederal road building and provides a standby capability of approximately 3 Megawatts (Mw) forpeak load shaving and local waste heat recovery/cogeneration for the facility. Refer to Appendix

B for a key single line diagram and distribution map of the Iqaluit System.

Applicable Codes, Standards, & Correspondence

The following codes, standards, and public documents were used to form the basis of this reportand serve as the base line design philosophy;

NFPA Standard 70B Recommended Practice for Electrical EquipmentMaintenance

CSA Code C22.1-02 Canadian Electrical Code Part 1 (Safety Standards forElectrical Installations.)

CSA Code C22.3 1-01 Overhead Systems

CSA Code CAN-3-C235-83 Preferred Voltage Levels for AC Systems, 0 to 50Kv

EEMAC Standard Y1-2 Performance Specification for Finishing Systems forOutdoor Electrical Equipment

ANSI Standard C57.12.90 General Requirements for Liquid ImmersedDistribution, Power and Regulating Transformers

Iqaluit Core Area and Capital District Redevelopment Plan City of Iqaluitdevelopment concept plan, 2005.

Personal Correspondence Mr. Clifton Rose, P. Eng, Senior System PlanningEngineer, Newfoundland Power. 2005.


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Problem Identification

Due to increased load growth within Iqaluits capital core area and extensive development ofmulti-unit housing structures, significant demand has been placed on various sections of ourdistribution system that will eventually create problems as early as the winter of 2005-2006. Themain problem will be voltage regulation, created by a low distribution voltage, high peak currents,

and sub-standard conductor sizing.

Secondary to the issue of feeder loading is power loss, while it does not affect the customerspower quality directly, it affects QECs overall system efficiency and removes potential revenuethat could be recovered through sales to the customer or it can be translated to fuel savings tothe corporation by the releasing of system generation capacity.

Voltage Regulation Backgrounder

As a power utility we are required to maintain an acceptable power quality level to our customers,mainly standard North American voltages within a slight tolerance. These values are specified inthe Canadian Standards Associations standard #C235, which is the benchmark for CanadianUtilities to follow with regard to voltage regulation. If a feeders load growth is projected to put

voltage levels outside these guidelines corrective action must be taken. Various alternatives areavailable depending on the severity of the problem, such as capacitor placement, re-conductoring, load balancing, autotransformer tapping, and converting to a higher distributionvoltage level.

QEC has developed the following process to generate the best alternative;

I. Complete a long range load forecast of 30 Years, which forms the pay back period basisand the useful life cycle of the associated equipment involved.

II. Include financial projections, including lost revenue over 30 years due to power losses,outage time, costs of capital, inflation, and maintenance costs over the same period.

III. Develop each alternative and carry it over the life of the 30 year project, alternativesshorter than this life span should not be considered. The least cost alternative shouldthen be examined.

IV. Consider energy costs for each alternative, since our energy costs are very high we wantto give projects which reduce power loss priority (Example: initiatives that lower ourdistribution currents will improve voltage regulation and reduce power loss, such as avoltage conversion project.)

Feeder Assessment

The following section details each feeder section in Iqaluit and gives brief recommendations onupgrading and future load growth trends.

Feeder #1

Power Losses

Feeder one in Iqaluit feeds primarily the downtown (lower base) area of the city. The Connectedload is mainly residential, with exception of the courthouse and the Northern Stores. The winter


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of 2005 the peak demand was 860 Kw. The projected Kilowatt hour (Kwh) losses are calculatedto be 94,695 for the 2005 Year.

Voltage Regulation

Voltage regulation on this feeder currently falls within CSA C235 standard, the base voltage is344 volts (600Y/347 volt service located at the northern store), nominal at the furthest customerpoint. While voltage regulation does not present a problem, conversion of the feeder should beeventually completed to standardize the equipment and hardware; various sections of the feederrequire replacement of the system neutral conductor and certain sections of the feeder have avintage of over 30 years old. It is recommended that the feeder be upgraded to meet anacceptable safety and reliability standard.

Feeder #2

Power Losses

Feeder two in Iqaluit feeds the core section of town, mainly the hospital and the high risebuildings. It is physically the shortest feeder of the Iqaluit System. The connected load is mainly

commercial with a peak demand of 1220 kW in the winter of 2005. The projected Kilowatt hour(Kwh) losses are calculated to be 290,832 for the 2005 Year.

Voltage Regulation

Voltage regulation on this feeder currently falls within CSA C235 standard, the base voltage is116 volts, nominal at the furthest customer point. While voltage regulation does not present aproblem, conversion of the feeder should be eventually completed to standardize the equipmentand hardware; various sections of the feeder require replacement of the system neutral conductorand certain sections of the feeder have a vintage of over 30 years old. It is recommended that thefeeder be upgraded to meet an acceptable safety and reliability standard.

Feeder #3

Power Losses

Feeder three in Iqaluit feeds the West 40, tank farm, water booster station #2, and select loads inthe North 40 area, while connecting to the federal plants G5 and G6 standby units. Theconnected load is mainly commercial with a peak demand of 1340 kW in the winter of 2005. Theprojected Kilowatt hour (Kwh) losses are calculated to be 209,013 for the 2005 Year.

Voltage Regulation

Voltage regulation on this feeder currently falls within CSA C235 standard, the base voltage is

113 volts, nominal at the furthest customer point. The far ends of this feeder are lightly loaded,while the main load center is closer to the main plant (source) which reduces line voltage dropand currently creates good voltage regulation. The use of the cogeneration source G5 & G6located in the federal plant also gives improved voltage levels when connected to feeder four,raising the base voltage to about 122 volts. While the federal plant corrects voltage regulationslightly, it is recommended that it not be considered in the overall regulation of the feederbecause of its standby function on the Iqaluit system.


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Feeder #4

Power Losses

Feeder four in Iqaluit feeds North 40, upper base, and sections of the downtown core section ofthe city. The connected load is mainly commercial with a peak demand of 1450 kW in the winterof 2005. The projected Kilowatt hour (Kwh) losses are calculated to be 588,672 for the 2005Year.

Voltage Regulation

Voltage regulation on this feeder currently falls within CSA C235 standard, the base voltage is115 volts, nominal at the furthest customer point. The far ends of this feeder are lightly loaded,while the primary load center is closer to the main plant (source) which reduces line voltage dropand currently creates good voltage regulation. The use of the cogeneration source G5 & G6located in the federal plant also gives improved voltage levels when connected to feeder four,raising the base voltage to about 118 volts. While the federal plant corrects voltage regulationslightly, it is recommended that it not be considered in the overall regulation of the feederbecause of its standby function on the Iqaluit system.

While voltage regulation does not present a problem, conversion of the feeder should beeventually completed to standardize the equipment, hardware, and reduce power line lossassociated with high currents experienced on the feeder section.

Feeder #5

Power Losses

Feeder five in Iqaluit feeds Happy Valley, 200s, and the 300s area of the city, the connectedload is mainly residential, with the exception of water booster station #1. Load growth on thisfeeder has been slow, peaking at 750 kW in the winter of 2005. The projected Kilowatt hour(Kwh) losses are calculated to be 114,055 for the 2005 Year.

Voltage Regulation

Voltage regulation on this feeder currently falls within CSA C235 standards. The base voltagevalue is projected to be 110 Volts, nominal at the furthest customer point. While voltageregulation does not present a problem, conversion of the feeder should be eventually completedto standardize the equipment and hardware; various sections of the feeder require replacement ofthe system neutral conductor and certain sections of the feeder have a vintage of over 30 yearsold. It is recommended that the feeder be upgraded to meet an acceptable safety and reliabilitystandard.

Feeder #6

Power Losses

Feeder six in Iqaluit feeds the capital core district of Iqaluit and feeds the bulk of the commercialload growth over the next several years, mainly Innuksugait Plaza Phase two (400 Kw projecteddemand for 2006-2007), new plateau subdivision (80 Kw projected demand for 2006-2007),Nunavut Justice Centre (115 Kw projected demand for 2005-2006), City of Iqaluit sewagetreatment plant (200 Kw projected demand for 2006-2007), RCMP V division Headquartersbuilding (112 Kw projected demand for 2007-2008). In the winter of 2005 the feeder demandpeaked at 1170 Kw prior to the connection of the previous mentioned loads. Power losses on this


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feeder section are also a concern; the projected Kilowatt hour (Kwh) losses are calculated to be543,248 for the 2005 Year.

Voltage Regulation

Voltage regulation on this feeder will be predicted to fall outside CSA C235 standards by the fallof 2006 when the Nunavut Justice centre and Innuksugait Plaza Phase two are completed. Thebase voltage value is projected to be 107 Volts, nominal at the furthest customer point. Thecurrent CSA C235 standard value for extreme operating value is 106 volts, indicating a borderlineoperating condition that will eventually cause problems.

Feeder #7

Power Losses

Feeder seven in Iqaluit feeds sections of the road to nowhere, west view, cross winds, and Apex.It also feeds several commercial customers, mainly the AWG complex, the Middle Schoolcomplex, and the Telesat radar site. Load growth since 2000 has been steady on this feedersection, peaking at 1090 Kw in the winter of 2005. While this feeder does not experience the

highest load growth of the Iqaluit system or have a significant impact on the core development ofthe city, it has the longest length of any feeder in the system and large sections of this feeder arewell over 35 years vintage (Apex Section). The projected Kilowatt hour (Kwh) losses arecalculated to be 124,392 for the 2005 Year.

Voltage Regulation

Voltage regulation on this feeder currently falls outside CSA C235 standards. The base voltagevalue is projected to be 94 Volts, nominal at the furthest customer point. The current CSA C235standard value for extreme operating value is 106 volts, indicating a substandard operatingcondition. To mitigate this problem the use of distribution transformer winding taps set to themaximum (low) setting where employed to raise the voltage to approximately 105 Volts. This is atemporary solution and does not adequately correct the voltage at peak loading times (Mid

January to late February).

The feeder also consists of a large gauge conductor (#2 ACSR), which impacts on the voltageregulation of the feeder over the long distance, causing voltage drop. Any further development inthe area serviced by this feeder should be discouraged due to the low voltage levels beingexperienced.

Feeder #8

Power Losses

Feeder eight in Iqaluit feeds the road to nowhere and Tundra Valley sections of Iqaluit. The

connected load on this feeder is primarily residential, with the exception of the Joamie School,which has a connected load of approximately 180 kilowatts. Load growth since the 2003development has been slow, peaking at 780 kW in the winter of 2005. This feeder representsone of the smallest connected loads of any feeder within the Iqaluit system and has a vintage ofabout 10 years. The projected Kilowatt hour (Kwh) losses are calculated to be 98,112 for the2005 Year.


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Voltage Regulation

Voltage regulation on this feeder currently falls within CSA C235 standards. The base voltagevalue is projected to be 118 Volts, nominal at the furthest customer point. While voltageregulation does not present a problem, conversion of the feeder should be eventually completedto standardize the equipment and hardware; various sections of the feeder require replacement ofthe system neutral conductor due to size inconsistency and poor connection integrity. It isrecommended that the feeder be upgraded to meet an acceptable safety and reliabil ity standard.

Total System Power Loss

The total system losses for the Iqaluit system in 2005 are calculated at 2,062,499 kWh. At a costof $0.40 per kWh this represents equivalent lost revenue of $783,428.52 annually. Iqaluitsgeneration efficiency is currently 3.90 kWh/L, which equates to 528,846 Litres of diesel fuelconsumed in 2005 to generate power system losses. This loss will continue to rise proportionalto the square of the current on each feeder, representing a sharp upward trend in projectedlosses over the next several years with a distribution voltage of 4.16 kV and an average loadgrowth of 3-5% per year. Table 1 details system losses per feeder over the 2005 year.

Table 1

Feeder Peak Load (kW)Loss

Factor Load FactorPeak Loss @ 4.16 kV

(kW)Average Loss @ 4.16 kV

(kW)

1 860 0.468 0.65 23.1 10.81

2 1220 0.468 0.65 71.1 33.2

3 1340 0.243 0.44 98.2 23.86

4 1450 0.352 0.55 190.9 67.2

5 750 0.261 0.46 49.9 13.0239

6 1140 0.418 0.61 149.7 62

7 1090 0.266 0.47 53.2 14.2

8 780 0.261 0.46 43 11.2

Potential Substation Transformer Losses & Unrecoverable losses

With distribution system voltage conversion a high voltage distribution substation must beconstructed to step-up the voltage from the main plant bus from 4.16 kV to the new distributionvoltage of 25 kV. The main component of the substation will be the step-up power transformers,these units are projected to be approximately 20 MVA in size, talking into account the 35 Yearload forecast of Iqaluit (See Appendix A) and a design life of 30 Years. Based on nameplateloading, loss factor of 0.3 and an auxiliary loss factor of 0.1 the unit will produce the followinglosses;

Table 2

3 Power Rating(MVA) Core Losses(kW) Winding Losses(kW) Auxiliary Losses(kW) Annual kWhLosses

20/25 18 72 2 349,000

These losses must be subtracted from the savings of the distribution voltage conversion and befactored into the payback period over the life of the equipment to determine if a completeconversion of the system is feasible. Losses contained in the system secondary lines, such aspole mounted transformers and service drops are not recoverable at any voltage level, since thesecondary circuits are not affected by such an upgrade. These losses are estimated at


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approximately 240,000 kWh or 12% of total system losses as per accepted utility industrypractice.

Recommendation

The priority with any power utility should be the control and reduction of lost energy within theredistribution systems, unfortunately there will always be electrical energy lost in the delivery tocustomer and QEC must implement an energy loss program that will aid in making well informeddecisions about the allocation of funding to reduce system loss. While financial performance isthe main incentive for loss control, voltage regulation and the ability of the distribution system toproperly accept load growth should also be a key factor. The loss reduction program in Iqaluitmust be based on the concept of increasing the nominal distribution voltage to a higher industrystandard, such as 25 kV. In deciding to convert the distribution voltage to take advantage of costsavings we must look at the system wide implications and complete an economic analysis of thekey factors involved, mainly;

New substation facilities to supply the required system voltage.

Stocking of higher voltage distribution equipment (i.e. transformers, cabling, fuses,cutouts, etc.)

Possible need for step-down power transformers to permit partial conversion of feedersections.

Installation of surge arrestors and line sectionalizers to deal with increased reliabilityrequirements and longer feeder lengths.

Procurement of new tools and equipment for maintaining a higher voltage class system.

The training of personnel in working with higher voltages, (i.e. substation electriciancertifications, safety requirements, etc.)

25 Kilovolt Distribution System Scenario

The total system losses for the Iqaluit system, based on the 2005 load are calculated at 684,494kWh. At a cost of $0.40 per kWh, this represents equivalent lost revenue of $273,797 annually.Iqaluits generation efficiency is currently 3.90 kWh/L, which equates to 175,511 Litres of dieselfuel consumed in 2005 to generate equivalent power system losses if the system weredistributing at 25 kV. The following table depicts various elements associated with power lossbetween the two classes of voltage.

Table 3 (In 2005 Dollars)

Distribution Voltage 4.16 kV 25 kV Savings @ 25 kV

Annual Losses (kWh) 2,062,499 684,494 1,378,005Equivalent Lost Revenue $783,428 $273,797 $ 509,631

Equivalent Fuel Consumption (Litres) 528,846 175,511 353,335


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Operations & Maintenance Requirements

When converting a distribution system to a higher voltage class consideration must be given tothe impact on the operational maintenance and overall safety requirements. Tools andequipment used by maintenance crews must be certified at the required voltage class and aerialdevices such as bucket trucks must be regularly tested to meet proper insulation levels. It is also

recommended that QEC develop standard work methods for distribution practice, such asreplacing broken poles, hold off (protection code) procedures, and temporary working grounds.Regular training and certification must also be performed to keep personnel current to Canadianutility practice.

The installation of a high voltage substation in Iqaluit will also broaden the scope of the linemaintenance department to perform periodic maintenance on various pieces of major equipment,such as high voltage cabling, air-disconnecting switches, breakers, and power transformers. It isrecommended that a full maintenance strategy be developed to identify future requirements.

Salvageable Equipment

The salvageable equipment from a 25 kV conversion project would primarily be 5 & 15 kV class

transformers (pole and pad mounted types). Transformers typically represent the largest capitalcost of a voltage conversion project. Most of these units can be reused in our 15 kV systems inResolute Bay and Coral Harbor. The Resolute Bay system would require upgrading of varioussections in the 2010-2014 time frame, mainly converting 2,400 volt delta connected sections tostandard 15 kV class (12.47 kV). The salvaged transformers from the Iqaluit upgrade wouldsignificantly reduce the capital cost of such a project and represent a large investment in reliabilityand safety for the community.

Project Costing

The scope of the system wide voltage conversion can be broken into a multi year, multi phaseproject that initially constructs the substation facility at the main plant, followed by upgrading atthe federal plant. To coordinate with this will be the conversion of each feeder over a two yearperiod to make the upgrade complete within two fiscal years. The Project can be divided into twokey parts, substation construction and distribution feeder upgrading.

Distribution Feeder Upgrading

Feeder upgrading will involve the following key tasks;

I. Re-insulating of the entire primary system, including grounding and bonding or insulatingof down guys and anchor rods.

II. Pole replacements at various feeder sections to improve safety clearance, aerial

trespass, and proper right-of-way easements.

III. The replacement of transformers and associated fusing, including cutouts with properpole mounting brackets (proper creep and flashover clearances).

The initial phase of this project (2006-2007) will see the temporary installation of automaticvoltage regulators on two feeder sections to provide proper voltage regulation during theconversion process. This phase can be considered an intermediate measure to create anacceptable time frame to complete the system wide upgrade. Additional phases will see the


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conversion of feeders #7, #4, #5 and #8 (in 2009-2010), and feeders #1, #2, #3 and #6 (in 2010-2011). Iqaluit system would then be reduced to three (3) trunk feeders, breaking the city intothree larger zones of protection, which would improve reliability and reduce the amount ofequipment required to be in service, such as feeder breakers, bus work, protection relays, andcabling.

Substation Construction

The construction of a high voltage substation would be required in the Iqaluit upgrade to bring thecurrent generation voltage from 4.16 kV to the distribution voltage of 25 kV. The proposedconfiguration of the substation would be a double ended, tie breaker configuration with redundantpower transformers. The main consideration for this type of substation would be to takeadvantage of built in redundant systems that can be used in the event of emergency (i.e.transformer or incomer cable failure on A bus.) or for planned maintenance routines. As well itwill maintain energized spare equipment for quick restoration and remove the down time requiredto replace failed equipment and reduce preservation maintenance on spares that would be instorage.

The proposed configuration for the federal plant would be a single radial feeder, with in-plantswitchgear modification and a simple outdoor pad mount transformer construction (refer toAppendix C for single line drawings). This system would not be of redundant design due to thefact that the federal plant is standby in nature and is not required for prime power use (i.e. thecost is unjustifiable).

Each project should be related to give provision in the initial substation construction for futureconnection of additional power transformers and associated equipment. By making allowance inphase one QEC can easily integrate a phase to interconnect any potential hydraulic sources thatare developed in the future without incurring large capital costs involved with modifying thesubstation.

System protection & Fault current limiting

An ongoing and common problem with electrical systems in Arctic regions with permafrost isproper grounding and bonding. Frozen earth exhibits very poor conductive properties which makeproper low resistance earth ground paths nearly impossible and often results in high neutralreturn current to the source neutral point at the plant neutral bus and can cause a groundpotential rise (GPR) on the station ground grid. During summer months the top active layerthaws, giving a temporary ground path for only a few short months. The concept of grounding inthe arctic requires further study, but one method of mitigating the effects of high neutral return(zero sequence) or unbalance current is providing electrical isolation by means of a Delta/Wyetransformer between the plant (source) and the connected system load. This configuration willlimit the GPR and potential arcing ground fault current to the substation side of the system onlyand effectively isolate the generation plant equipment from damaging ground fault levels that

presently exist.

Construction of a high voltage substation will provide this isolation as well as a more stablesystem for protective relaying and selective coordination between generation, substation, anddistribution fusing. Zones of protection will be effectively setup and fault current will be limited tosafe levels throughout the system.


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Conclusion & Recommendation

The conversion of the Iqaluit distribution system would generate various benefits, mainly:

Reduction of Greenhouse gas emissions by approximately 960 tonnes per year.

Reduce diesel fuel consumption by approximately 350,000 liters per year.

Reduce primary voltage regulation and allow for easy load growth within the city for thenext 35-50 years.

Standardize construction methods and improve safety of the overhead system to reduceoverall maintenance cost and eliminate nuisance power outages during bad weatherconditions.

The simple payback of this complete project would be approximately 16-18 years, the average lifeexpectancy of the major equipment is 35 years, making it a viable project for QEC to undertakeand pursue further engineering economic analysis studies.

Appendix C to this report contains QECs intended design philosophy for the new 25 kVsubstation and associated systems. This document will form the technical guidance for thedetailed design, costing, construction, and maintenance operation of the proposed new system.


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Appendix A

Iqaluit 30 Year Load Forecast


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FiscalYear

TotalSales

(KWh)Domestic

Sales(KWh) CommercialSales(KWh)

StreetlightSales(KWh)

StationService(KWh) Generation(KWh)

PeakLoad(KW)

2005 44422805 14888135 29127976 406694 2290776 47553680 85762006 44586726 14676604 29503428 406694 2385647 48852970 85402007 47288991 15520898 31361399 406694 2554608 50546160 88632008 45884110 15372579 30104837 406694 2581450 52260250 89442009 47640508 15349096 31878503 412909 2569561 54445810 89432010 51525675 16879438 34222071 424166 2705842 58685311 96392011 53138194 17387407 35326620 424166 2791192 60444894 99282012 55119443 18010353 36684924 424166 2889307 62606836 102832013 56703213 18529731 37742834 430648 3082315 64335048 105672014 58398608 19085833 38875547 437228 3286917 66185066 108712015 59839188 19557995 39837284 443910 3382409 67757029 111292016 61478601 20146041 41254400 440565 3478057 69531443 114212017 63164472 20703271 42440356 444104 3571503 71484193 117412018 64850343 21260500 43626312 447643 3667312 73436943 120622019 66536214 21817730 44812268 451182 3764203 75389693 123832020 68222085 22374960 45998224 454720 3865102 77342443 127042021 69907956 22932190 47184180 458259 3967879 79295193 130242022 71593827 23489420 48370136 461798 4070655 81247943 133452023 73279698 24046650 49556093 465337 4173431 83200693 136662024 74965569 24603879 50742049 468876 4276208 85153443 139872025 76651440 25161109 51928005 472414 4378984 87106193 143072026 78337311 25718339 53113961 475953 4481760 89058943 146282027 80023182 26275569 54299917 479492 4584536 91011693 149492028 81709053 26832799 55485873 483031 4687313 92964443 152702029 83394924 27390029 56671829 486570 4790089 94917193 155902030 85080795 27947259 57857785 490108 4892865 96869943 159112031 86766666 28504488 59043741 493647 4995642 98822693 162322032 88452537 29061718 60229697 497186 5098418 100775443 165532033 90138408 29618948 61415653 500725 5201194 102728193 168732034 91824279 30176178 62601609 504264 5303971 104680943 171942035

93510150

30733408

63787565 507802 5406747 106633693

17515

2036 95196021 31290638 64973521 511341 5509523 108586443 17836


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Appendix B

Iqaluit System Key Single line Diagram


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Appendix C

Proposed 25 kV Substation Design Philosophy


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Qulliq Energy Corporation

Design Philosophy

Iqaluit 25 Kilovolt Distribution Substation

By

Adam Chubbs, B.Tech, CET

Engineering Department

April 2006

Revision 01


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Table of Contents

PAGE

1.0 Introduction

1.1 Overview 41.2 Abbreviations & ANSI Device Numbers 41.3 Reference Codes & Standards 51.4 Site Data 61.5 Site Layout 6

2.0 25 kV Substation Design Requirements

2.1 Civil/Structural Site Requirements2.1.1 Site preparation & Survey 72.1.2 Site Remediation 72.1.3 Site Access & Lot Setback 72.1.4 Permitting & Land Acquisition 72.1.5 Foundations and Superstructures 82.1.6 Grading & Soil Sterilization 82.1.7 Drainage 82.1.8 Oil Containment 82.1.9 Power Distribution Centre (PDC) Building 8

2.2 Site Electrical Requirements2.2.1 Grounding, Bonding & Shielding 92.2.2 Station services & Small Power 102.2.3 Site DC Power & Battery Bank 112.2.4 Cable Raceways 11

3.0 25 kV Switchgear Lineup

3.1 Structural Design & Layout 12

3.2 Breaker & Power Fuse Requirements 12

3.3 Protective Relaying 13

3.4 PLC & SCADA Requirements 14

3.5 Cable & Wire Requirements3.5.1 High Voltage Cables 14


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3.5.2 Control & Secondary Wiring 153.5.4 Wire & Cable Nomenclature 153.5.5 Nameplates & Finish 15

4.0 Substation Communications 15

5.0 Fire Alarm System 16

Appendix A Iqaluit Main Plant Lot Survey Excerpt 18

Appendix B Proposed Preliminary Design Drawings 19

P146-5264-E01 Key Singleline Diagram (4 Sheets)

P146-5264-E02 Protection & Control Diagram (3 Sheets)

P146-5264-E03 Proposed Site General Layout (2 Sheets)

P146-5264-E04 Proposed PDC Layout (2 Sheets)

P146-5264-E05 Proposed Switchgear Layouts (2 Sheets)

P146-5264-E06 3 Line AC Schematics (4 Sheets)

P146-5264-E07 DC Breaker Control Schematics (3 Sheets)

P146-5264-E08 Station Secure DC Singleline Diagram (1 Sheet)

P146-5264-E09 PLC I/O Rack Layout & Module Schematic (2 Sheets)


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1.0 Introduction

1.1 Overview & Scope

This document serves as direction and guidance for the detailed design of a 25 kilovolt(27.6 kV class) distribution substation in the City of Iqaluit, Nunavut. This will include allaspects of design of a double ended, tie breaker single bus system with four incomers toprovide redundant supply and interconnect between the Iqaluit main diesel plant and afuture 69 kV transmission line. Provision will be provided for the future interconnectionphase as indicated in the drawings and specified in this report. The single line diagramin the drawing set P146-5264-E01 details the intended layout and functionality of thesubstation.

The second phase of this project also requires for upgrading of the Iqaluit Federalstandby plant for interconnection to the new 25 kV system. Replacement andreconfiguration of the plant switchgear and installation of a pad mounted powertransformer will be the main focus, but will only be included in the scope of this projectfor information purposes. This phase will be identified in future requirements.

1.2 Abbreviations & ANSI Device Numbers

The following list explains commonly used technical abbreviations used by QEC intechnical reports and drawings:

AI Analogue InputAO Analogue OutputDI Digital or Discrete InputDO Digital or Discrete OutputAVR Automatic Voltage RegulatorACP Alternator Control PanelLECP Local Engine Control PanelVFD Variable Frequency DriveCT Current TransformersPT Potential TransformersIED Intelligent Electronic DevicePDC Power Distribution Center

The following lists ANSI device function number used on this project:

89 Switch or Disconnect52 - Breaker50 Instantaneous Over Current51 Timed Over Current50N Instantaneous Neutral Over Current51N Timed Neutral Over Current87 Differential Protection81U Under-Frequency79 AC Reclosing


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67 Directional Over Current63 Gas Pressure49 Transformer Thermal Protection25 Sync-Check22 Temperature Control

1.3 Reference Codes & Standards

The following codes and standards shall be considered part of this philosophy insofar asthey give definitions and describe requirements and tests to which equipment to besupplied shall meet. They include but are not limited to the following;

CSA C22.2 No 0-M91, General Requirements Canadian Electrical Code Part II;

CSA C22.2 No. 31-M89 (R1995), Switchgear Assemblies;

EEMAC, Standard Light Grey Color For Indoor Switchgear;

IEEE 980-1994, Guide for Containment and Control of Oil Spills in Substations;

CAN3-C13-M83 (R1992), Instrument Transformers;

EEMAC Standard LB-1, Instrument Transformers;

ANSI/IEEE C37.20, Electrical Power System Device Function Numbers;

ANSI/IEEE C37.06, Ratings and Related Required Capabilities for AC High-VoltageCircuit Breakers Rated on a Symmetrical Current Basis;

ANSI/IEEE C37.09, Test Procedures for AC High-Voltage Circuit Breakers Rated on aSymmetrical Current Basis;

ANSI/IEEE C37.30, (plus supplement), Definitions and Requirements for High-VoltageAir Switches, Insulators and Bus Supports;

ANSI/IEEE C37.90, Relays and Relays Systems Associated with Electrical PowerApparatus;

ANSI/IEEE C557-12.91, Standard Test Code for Dry Type / Distribution and PowerTransformers;

C9-M1981, Dry Type Transformers;

CAN/CSA-C233.1-87, Gapless Metal Oxide Surge Arrestors;

NEMA SG4, AC High- Voltage Circuit Breakers;

NEMA SG5, Power Switchgear Assemblies;

NEMA SG6, Power Switching Equipment;


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NEMA Standard ST-20, Dry Type Transformers for General Applications;

EEMAC Standard G8-2, Switchgear assemblies;

IEC Standard 61850, Communication Networks and Systems in Substations;

IEEE Standard 485-1983, Recommended Practice for Sizing Large Lead StorageBatteries for Generating Stations and Substations.

1.4 Site Data

The following table details the site requirements and environmental Data:

Data Type ValueInstallation Indoor Switchgear

Elevation Above Sea Level 40 MetersMaximum Ambient Temperature 30C

Minimum Ambient Temperature -50C

Relative Humidity 20%

Maximum Wind Velocity 110 Km/h

Maximum Ice Loading 20 mm Radial Thickness

Snow load Ss = 2.7 kPa, Sr = 0.2 kPa

Frost Type Permafrost

Keraunic Level 1 thunderstorm day per year

Fault Current 35 kA

Setback Required As per CSA C22.1, Section 26

Oil Spill containment (Transformers) Yes

Zoning Restrictions Yes

Height Restrictions Yes (to prevent exhaust contamination)

1.5 Site Layout

The proposed physical layout of the substation yard is indicated in the drawing set P146-5264-E03 and includes an allowance for a future 69 kV class section. It is the intentionof QEC to make provision for this section in areas that will impact on the overall designof the substation and to mitigate the need for future modifications during that phase ofconstruction. This will coincide with the interconnection of possible hydraulic generationsources within the Iqaluit area.

2.0 25 kV Substation Design Requirements

2.1 Civil & Structural Site Requirements

The following section details requirements for Civil & Structural design within thesubstation yard and surrounding area. Identification of these key items does not


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constitute complete design requirements. It is recommended that a geotechnical andbedrock profiling study be completed to accurately model the site and help indetermining ground electrical resistance, permafrost active layering, etc.

2.1.1 Site Preparation & Survey

Initial preparation of the proposed area adjacent to the main plant in Iqaluit will requirethe removal of all debris to provide a clear, open space to perform necessaryengineering studies. Drawing P146-5264-E03 shows a general location layout of theproposed site.

Legal surveying of the lot will be required to assess land requirements and determine ifadditional land is required to accommodate the substation. Appendix A shows thecurrent lot survey from the city of Iqaluit and should be used as a baseline site reference.

Relocation of the main plant fuel re-supply pipeline may also be required to createadditional space to accommodate the substation. Requirements of this relocation and

scope of work should be identified in the site civil design.

2.1.2 Site Remediation

Possible environmental site remediation should also be investigated at the proposedsite, such as the removal of hydrocarbon contaminated soil, any diversion of streams ordrainage ditches, and its close proximity to a watershed area. Any information regardingthis site can be made available through QECs environmental department.

2.1.3 Site Access & Lot Setback

Access to the proposed site shall be made by two gates, located at the Northeast andSouthwest sections of the substation fencing and allowance shall be made for a 5 meterfire lane around the outside of the fenced area. The minimum setback inside thesubstation from the fence to the nearest un-energized equipment shall be a minimum of1.1 meters and 3.7 meters for energized equipment (i.e. bus work and cabling), whileproviding adequate space for bucket/maintenance truck access.

All fencing shall be constructed as per CSA C22.1-02, section 26-300 and be of agalvanized chain link construction.

The side of the substation adjacent to the Iqaluit main plant shall have a setback

minimum of 25 meters from the plant north exterior wall to allow for future expansion ofthe building to accommodate two engine bays into its existing machine hall.

2.1.4 Permitting & Land Acquisition

Upon completion of the requirements of section 2.1.1, land acquisition and permittingmay be required through the municipal level of government for development of the site.Once civil engineering requirements have been met, submission of the site development


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drawings to the planning department of the city of Iqaluit for approval should be carriedout. The city can then identify any requirements for permitting, etc.

2.1.5 Foundations and Superstructures

All foundations supporting major equipment within the substation will be installed onpilings elevated from finished grade to allow for air flow to prevent melting of the activelayer of permafrost. All above ground raceways, such as cable tray will also besupported with pilings along its entire route, at a minimum height of 1 meter abovefinished grade. All riser structures and dead end gantries shall be self supporting andmounted on pile structures to avoid the use of guying within the yard area.

2.1.6 Grading & Soil Sterilization

The substation yard and surrounding right-of-ways will be level graded, compacted withaggregate, and chemically sterilized to prevent the growth of tundra grass and moss

within the substation yard area. The grading design should include the plan andelevation of the finished sub-grade and existing contours of the substation andsurrounding area. Cross sectional views indicating slopes for cut and fill areas, roads,and all graveled surfaces shall also be completed.

2.1.7 Drainage

The finished grade of the substation yard will be a high grade, washed crush stone. Thiswill facilitate good drainage of the yard and prevent standing water from forming aroundhigh voltage equipment. A well devised drainage system must also be implemented tocarry all runoff water away from the substation area, especially during the spring melt

when potentially large amounts of snow will melt away from areas within the yard.

2.1.8 Oil Containment

The option of Transformer oil containment must also be investigated for the proposedsite due to the close proximity of a stream adjacent to the main plant. It is recommendedthat each power transformer support structure be equipped with a primary oilcontainment system (i.e. self-dyking tank or oil basin containment). It is alsorecommended that the guidelines of IEEE Std 980-1994 IEEE - Guide for Containmentand Control of Oil Spills in Substations be used as a guideline.

2.1.9 Power Distribution Centre (PDC) Building

The PDC building shall be waterproof and shall consist of an insulated, prefabricated,modular enclosure that is suitable to be mounted on site to a pile support structure. Thebuilding will contain all the switchgear and auxiliary equipment as indicated in drawingP146-5264-E04. The building shall be constructed according to the latest edition of theNational Building Code of Canada and have a design life of at least 30 years.


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The module will have two exit doors, one at each wall end, and have access steps and alanding for ease of entry. The southeast end of the PDC will have a double doorconfiguration to allow for the removal of breakers and various other large pieces ofequipment. Refer to drawing P146-5264-E04 for orientation.

The building shall be suited for an arctic climate, with minimum R40 insulation for the

walls, and R50 insulation for the floor and roof. Allowance must also be given forventilation of the PDC due to battery hydrogen release during discharge and equipmentheat rejection. Section 26-546 of the CEC shall be followed when determining batteryventilation requirements. The PDC shall maintain an ambient temperature of 25C.

The Exterior color of the building shall be painted ASA 61 Grey. Color samples shouldbe submitted to the project manager for approval prior to painting.

The floor shall be designed to accept incoming and outgoing cabling, while maintainingthe integrity of the floor insulation. It is recommended that a recessed, removable cablegland entry plate system be used at the rear of the switchgear to provide extra protectionof connectors and associated hardware.

Grounding pads for the attachment of NEMA 2 hole wire lugs will also be provided at;each corner of the PDC building; any section of the structure were major structural jointsexist; and points were cable raceways attach to the PDC for the purposes of bonding.

The module will be pre-wired where possible, for lighting and small power receptacles asper drawing P146-5264-E04. All interior small power raceways will be of rigid aluminumconduit construction.

The module shall be constructed and factory acceptance tested (FAT) prior to shippingto site. Requirements of FAT and commissioning will be specified by the owner at alater date.

The construction of the PDC will require that it be disassembled for marine transport andreassembled on site. The current heavy lift capability within the city of Iqaluit isapproximately 20 tonnes and the maximum dimensions of the right of way adjacent tothe main plant is approximately 8 meters in width by 6.5 meters in height, due to theproximity of the existing feeder risers. These factors must be taken into account whendesigning the modular construction of the building and its contents.

2.2 Site Electrical Requirements

2.2.1 Grounding, Bonding & Shielding

Grounding design and calculations must be completed to determine the extent of thegrounding required and the overall size of the ground grid. Obtaining proper groundresistance in a permafrost environment will be a challenging task and may requireinnovative techniques to achieve the required result. Proper impedance levels must bereached to ensure proper operation of protective relaying and ensure good selectivecoordination of fuses within the distribution system. Personnel safety must also be


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considered through proper bonding of site equipment to reduce the possibility of step-touch potentials, etc.

The following criteria shall be met:

Ground grid burial a minimum of 460mm below finished grade

The ground grid should extend a minimum of 1 meter outside the fenced area,with a gate bypass extending a minimum of 460mm beyond the opened gate.

Ground conductor shall be a minimum of AWG #4/0, bare, softdrawn strandedcopper conductor.

All above and below ground connections shall be compression type connections.

All lightning and surge suppressor grounding shall be continuous, directly to thegrounding grid.

Adequate grounding conductor shall be buried to allow for expansion duringfreeze and thaw cycles.

All substation fencing to be a minimum of 2.1 Meters, with a 305mm barbed wireextension. Proper grounding of the fence as per CSA C22.1-06, Section 26 shallalso be implemented.

Power transformer neutral bushing connections shall be continuous connectionsto the grounding grid.

All cable tray and associated support equipment shall be bonded as per CSAC22.1-06, Section 10.

Due to poor electrical grounding in permafrost QEC maintains a system neutral bus in allits switchgear to accommodate zero sequence current and recommend that thesubstation be designed with neutral/ground bus work. Allowance should also be madefor separate neutral conductors on feeder riser cabling to avoid sheath currents. Allcabling will be properly bonded and grounded to avoid the flow of sheath and eddycurrents.

All instrument and control cabling shall be properly shielded from EM interference whereever possible through the use of drain wiring and interlocking cable armor. Separatenon-metallic duct banks will be used to carry control cabling from field devices.

It is recommended that a grounding/ground resistance study be completed in thesummer of 2006 to identify any problems in obtaining proper grounding parameters. Tomitigate the effects of permafrost grounding the placement of ground electrodes in nearby lake bodies or the use of chemical ground enhancement products should beinvestigated.


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2.2.2 Station Services & Small Power

Substation AC small power and station services shall be designed as per Drawing P146-5264-E01. General layout of equipment shall be in accordance with Drawing P146-5264-E04 and applicable building and electrical codes. An automatic transfer switch(ATS) will be used to supply station service panel A from either bus A or bus B when

required. Normal mode of operation will be coupled to bus A, upon loss of voltage (70%of nominal bus voltage), a transfer will be initiated to bus B to maintain service to panelA. A dry contact (24 Vdc rated) from the ATS will also be provided to connect to thestation PLC and provide supervisory notification to the SCADA system of a transfer fromnormal operating conditions. The ATS will also have provision for testing locally at theunit panel.

All exterior lighting, except for PDC building perimeter lighting will be controlled via alighting contactor panel. The lighting contactor will be controlled via photocell and havea control selector switch to allow for on-auto-off control for manual override andmaintenance purposes.

Emergency lighting will be provided via wall mounted exit lighting combo packs (self-contained battery packs) and fluorescent lighting fixtures equipped with emergencylighting ballasts, fed from the station DC battery bank. Drawing P146-5264-E04 detailsrequirements and fixture type to be used. Allowance must also be given for 120 Vacreceptacles and lighting kits within the switchgear low voltage compartments, with anextra allowance for devices located in control cells 12 & 13.

2.2.3 Site DC Power & Battery Bank

The station secure DC supply shall have a nominal system voltage of 24 volts DC, with astandard voltage deviation of 10% over the total duty cycle of the battery bank. The DC

supply shall have an appropriate Amp-Hour (AH) rating to accommodate the criticalloads specified in the following table for a period not less than 8 hours at an ambienttemperature of 25C;

Device Consumption (watts @ 24Vdc)Protection Relays 600

HMIs 30

Pilot Lamps 40Emergency Lighting 350

Breaker Tripping 120

I-RIG-B GPS Receiver 45Future Requirements 200

Total Connected Load 1385

The secure DC power supply shall have its battery charger supplied via a circuit breakerin Panel A of the station service. The complete DC system shall be designed underthe configuration of full float operation and supply loads through a station DCdistribution panel. Switching of all DC circuits will be done with a minimum of 2 polebreakers, to provide switching and line protection of both legs. Refer to drawing P146-5264-E08 for the proposed single line diagram. The station DC system shall be


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designed in accordance with IEEE standard #485-1983 Recommended Practice forSizing Large Lead Acid Storage Batteries for Generating Stations and Substations.

2.2.4 Cable Raceways

All cable raceways will be either open ladder type cable tray or underground duct banks,drawing P146-5264-E03 indicates a proposed route for the raceway. Main incomersfeeding power transformers IQ-T1 & IQ-T2 shall be underground duct banks, consistingof rigid PVC ducts at properly spaced and supported intervals. Separate ducts will alsobe ran for control and instrument circuits between the power transformers and the mainplant to the corresponding feeder breaker Cells of breaker 52-GF1 & 52-GF2.

All 25 kV power, associated control and instrument cabling (except for feeder risers)shall be located above ground in CSA approved open ladder cable tray. The traysystem shall extend under the PDC, where it will be suspended from the structure toproperly carry all cabling to designated gland entry plates. All feeder riser cabling willenter underground duct banks that will run to a designated section of the dead-end

gantry. All yard tray will be supported by pile structures and be suspended a minimumof 1 meter above finished grade.

Provision shall also be made for future development of the 69 kV section of thesubstation yard. Allowing for future cable tray support will be essential, along withproviding enough cable run space on existing raceways for future cable requirements tocells 1, 11, 12, and 13 of the PDC switchgear.

A duct bank shall also be provided for the installation of an optical fiber cable from cell#13 of the substation switchgear to the main plant server room for tie-in to thecorporations Ethernet backbone.

Allowance shall be given for a riser pole and corresponding duct bank to be locatedwithin the substation boundary to carry the main plant phone, data, CATV, and SCADAoptical fiber services into a designated media closet in the main plant.

3.0 25 kV Switchgear Lineup

3.1 Structural Design & Layout

The recommended physical layout of the switchgear is indicated in drawing P146-5264-E05 and shall consist of standard 915mm wide cells where possible to utilize maximum

access to low voltage compartments and wire ways between cells. The switchgear shallbe operated and serviced from the front only. Rear exterior access doors shall beconstructed for cable termination facilities directly above cable entry gland plates locatedin the floor area and directly below blast vents.

The switchgear construction shall be of arc resistant metal clad design, capable ofwithstanding a fault current in excess of 35 kA @ 1 second interrupting, and be inaccordance with IEC/IEEE/ANSI standards. All bus ampacities shall conform to sizesindicated in the key single line diagram located in drawing P146-5264-E01.


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Each breaker cell will be equipped with thermostatically-controlled electric heaterscapable of maintaining proper ambient operating temperatures and prevent anycondensation from occurring within the enclosure areas.

3.2 Breaker & Power Fuse Requirements

All power breakers shall be of the draw-out vacuum type, complete with a motor-chargedstored-energy operating system, capable of high speed auto-reclosing duty. Provisionsshall also be made for manually charging the closing mechanism.

All breaker control shall be electrically and mechanically trip free as per NEMAStandard SG4, 56-5, and incorporate an anti-pumping relay scheme.It shall not be possible to rack out a charged or closed breaker into or out of itscubicle.

Means of testing and operating the circuit breakers in the racked out test position shall

be provided, along with a breaker testing panel located in a fixed position in the PDC.The test panel shall have a breaker control circuit connector attached to a length offlexible cord that can be ran to any breaker cubicle in the PDC. The test panels circuitshall be similar to the existing breaker trip/close logic and have a master power switch,close, trip, corresponding status lamps, and voltage test points.

All breakers shall have a continuous duty current rating as indicated in the key singlelinediagram in drawing P146-5264-E01 and have a rated short circuit current of 250 MVA.

The breaker shall have a 100% reclosing duty with appropriate momentary short circuitduty rating.

It is recommended that an X/R ratio of between 30 and 50 be applied, dependant onchanging fault current through future interconnection of generation sources andchanging system dynamics. The Iqaluit system tends to be mainly resistive in natureand X/R ratios tend to be low.

Power fuses will be utilized in providing protection for all instrument voltage transformersand station service transformers. All fuses shall be of the current limiting type, withblown fuse indication. Arc quenching expulsion fuse design shall also be investigatedwhen selecting fuses.

3.3 Protective Relaying & Settings Development

All protective relaying as indicated on key singleline diagrams in drawing P146-5264-E02 shall be of the microprocessor based, multi function type and be classed asintelligent electronic devices (IED).

The General Electric Multilin, SR series of relays will be utilized as the primary protectionmeans. Future provision shall be made for additional relaying associated with theaddition of the 69 kV section, including protective relays for transformers, breakers, andbus protection.


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All protective relaying and associated support equipment (i.e. Ethernet switches andoptical fiber media converters) will be supplied with secure power via the station 24 Vdcdistribution panel.

Current transformers (CTs) shall have accuracy designations of 2.5L200 or better for

relaying accuracy and 0.6B2 for metering accuracy.

Potential transformers (PTs) shall be withdrawable with a means of properly groundingthe units when withdrawed. The use of primary and secondary fusing is recommended.PTs shall have a accuracy ratings of at least 0.6ZZ (bus PT) & 0.6X (line PT).

Protection and control circuits shall be developed as per drawing set P146-5264-E06 &P146-5264-E07 to ensure the operational philosophy and flexibility of the substation ismaintained in accordance with QECs standards.

Protective relay settings will be internally developed by QEC during the final design andconstruction phase of the project through concept of operation technical reports.

3.4 PLC, HMI & SCADA Requirements

Supervisory control of the substation will be maintained via a dedicated PLC located incell #13 of the switchgear and be connected to the SCADA system (in the Iqaluit mainplant) via Ethernet fiber optical link to provide optical isolation of the main plant from thesubstation facility.

A human machine interface unit will also be mounted locally on the cell door to providemonitoring and annunciation functions. Drawing P146-5264-E08 details I/Orequirements and specifies the manufacturer type for the PLC installation.

The substation will utilize the existing SCADA tag server in the Iqaluit main plant andsupervision will be provided via the main plant control room through its existing commonalarm and shutdown system. PLC logic and soft tag development will be completedinternally by QEC during the final design through concept of operation technicalreports.

3.5 Cable & Wire Requirements

3.5.1 High Voltage Cabling

All high voltage cabling shall be cross linked polyethylene (XLPE) with a minimum of90C temperature rating. 133% Insulation and a 100% copper concentric neutral shallbe used wherever possible. The cable must be single conductor.

5 kV cabling shall be suitable for use in underground duct banks.

28 kV cabling shall be suitable for use in suspended cable tray and be easily terminatedand connected were required in designated entry gland plates.


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A complete insulation coordination study shall be performed during the design of thesubstation to ensure all cabling and associated connectors, terminations, and coronashielding are properly employed to reduce high voltage stress.

All power cabling shall have phase coding applied by color bands at each end neartermination points and be clearly visible when accessing termination cabinets and entry

throats.

3.5.2 Control & Secondary Wiring

All secondary wiring shall be type SIS thermoplastic insulation. #10 AWG shall havecolor coded covering; over #10 AWG shall have phase coding applied by color bands ateach end.

1. All CT wiring shall be a minimum of #10 AWG.

2. All PT wiring shall be a minimum of #12 AWG.

All control wiring shall be type TEW thermoplastic insulation, minimum of #14 AWG.

3.5.3 Wire & Cable Nomenclature

All control and secondary wiring shall be grey in color and all grounding, bonding anddrain conductors shall be green. All wiring shall be point to point from devices wereever possible.

All wiring shall use the highway method of marking that utilizes a reverse addressingof device numbering between terminals while being able to effectively bundle conductors

into common wire ways and reduce occupied space.

3.5.4 Nameplates & Finish

Engraved, laminated, 3mm thick plastic nameplates with white face, black core, andaffixed by screws shall be used to identify the following;

1. Each switchgear cell and function.

2. Each front mounted device.

3. Each device mounted inside the low voltage compartment including fuses,terminal block assemblies, and DC breakers.

Proper signage shall also be affixed to the switchgear notifying personnel of anyhazards, such as high voltages or devices containing multiple voltage sources. Allwarning signage shall be in accordance with CSA C22.1-06 Part 1, section 36-006.


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4.0 Substation Communications

All substation IEDs will be equipped with a communication capability for SCADA andoverall substation automation system (SAS) operations. The primary protocol will beTCP/IP and/or modbus over TCP/IP.

The substations wired network will be a 10base100 industrial grade Ethernet backbonewith an interfaced optical fiber node to connect to the main plant network, local PLC, andHMI panel located in the PDC switchgear lineup.

All structured wire systems related to the substation will be designed and built as perCSA Standard T530-99 Commercial Building Standard for TelecommunicationsPathways and Spaces and standard T529-95 Telecommunications Cabling Systemsin Commercial Buildings.

The overall design philosophy of the substation communication system shall conformwherever possible to IEC Standard 61850 Communication Networks and Systems inSubstations.

5.0 Fire Alarm System

A four zone fire alarm system shall be designed and specified for the PDC section of theproposed substation. The system shall be DC operated, have its own local auxiliarybattery pack and have normal operation supply fed from the station 24 Vdc panel.

A common fire alarm dry output contact shall be provided to the substation PLC toprovide remote alarming to the SCADA and the main plant alarm string for indication tothe control room.

Provisions shall also be made to designate a separate zone within the main plant firealarm system for the substation area if possible.

Local audible and visual annunciation shall also be mounted externally on the PDCbuilding wall to provide redundant signaling in the event of a failure of the station PLCand/or the communication link with the main plant SCADA.

The fire alarm system shall have the following designated zones;

Standard pull stations located next to lighting switches at each entrance to thePDC building.

Minimum of two flame detectors adjacent to the switchgear lineup in the PDCmain area.

Minimum of two rate-of-rise heat detectors located in the PDC main area.

Future zone to be utilized for 69 kV section of substation for installation of flamedetectors in major equipment control cabinets.


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The complete system shall conform to ULC Standard S527-99 and Section 32 of CSAC22.1 06 wherever possible and practical.


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Appendix A


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Appendix B

(Refer to Drawing Package)


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Documents

Attachment a - Iqaluit System Report - Engish