SaskPower 10-Year Transmission Development Plans3.amazonaws.com/zanran_storage/ · 10-YEAR...

SaskPower10-Year TransmissionDevelopment Plan

May 2002

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Table of contentsExecutive Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .i

1.0 Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .11.1 Context . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .11.2 Document Scope . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2

2.0 Definition of SaskPower’s Facilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .32.1 Grid Transmission Facilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .32.2 Sub-Transmission Facilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .42.3 Distribution Facilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4

3.0 Transmission System Performance Criteria . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .53.1 Transmission System Adequacy . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .83.2 Transmission System Security . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .83.3 Transmission System Reliability . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .103.4 Cost Effectiveness of the Transmission System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .11

4.0 Major Drivers of Need for New Transmission Facilities . . . . . . . . . . . . . . . . . . . . . . .124.1 Load Growth . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .12

4.1.1 Corporate 10-Year Load Forecast . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .124.1.2 Regional Load Forecast . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .13

4.2 Connection of New Generation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .154.2.1 New SaskPower Generation Developments . . . . . . . . . . . . . . . . . . . . . . . . . . .16

4.3 Connection of New Major Loads . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .174.4 SaskPower’s Open Access Transmission Tariff (OATT) . . . . . . . . . . . . . . . . . . . . . . . . . .174.5 Aging Infrastructure . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .184.6 Compliance with NERC Reliability Standards . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .19

5.0 Evaluation of Requirements for Transmission System Developments . . . . . . . . . . . . . .205.1 The Prince Albert and La Ronge Study Area . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .22

5.1.1 Reinforcement of the Supply to La Ronge . . . . . . . . . . . . . . . . . . . . . . . . . . . .225.1.2 Transmission Reinforcement for the Prince Albert Area . . . . . . . . . . . . . . . . . .24

5.2 The Meadow Lake Study Area . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .255.2.1 Reinforcement of the Supply to the Area North of Meadow Lake . . . . . . . . . . .255.2.2 Interconnection of a New OSB Plant Near Meadow Lake . . . . . . . . . . . . . . . . .275.2.3 Transmission Grid Reinforcement for the Meadow Lake Area . . . . . . . . . . . . .27

5.3 The Pelican Narrows – Deschambault Lake Study Area . . . . . . . . . . . . . . . . . . . . . . . . .295.3.1 Supply Reinforcement for Pelican Narrows – Deschambault Lake . . . . . . . . . .29

5.4 The Kindersley – Kerrobert – Unit Study Area . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .305.4.1 Supply Reinforcement for the Area West of Kindersley . . . . . . . . . . . . . . . . . .305.4.2 Transmission Reinforcement for Kindersley, Kerrobert, Unity . . . . . . . . . . . . .30

5.5 The City of Saskatoon Study Area . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .315.6 The City of Regina Study Area . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .335.7 Other Projects . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .35

5.7.1 Alberta – Saskatchewan Interconnection at Lloydminster . . . . . . . . . . . . . . . . .355.7.2 Connection of Wind Generation in the Area Southwest of Swift Current . . . . .365.7.3 Alberta Newsprint Mill . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .36

APPENDICES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .37A NERC Planning Standards – Table I . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .37B Summary of Capital Expenditures on Transmission System for 2002 to 2006 . . . . . . . . .39

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Executive Summary

The SaskPower 10-Year TransmissionDevelopment Plan provides a discussionof SaskPower’s anticipated transmissiondevelopments for the period 2002-2011.

The impetus for preparing theTransmission Development Plan is foundin the work of the Transmission LineRouting Review Panel, established in June2000. When the Transmission LineRouting Review Panel was convened, itsFinal Report was envisioned as a guide tohelp SaskPower manage these changingexpectations. The Panel recommendationsregarding public consultation andbenchmarking have become an importantpart of SaskPower’s efforts to ensure thatcorporate guidelines and processes reflectcurrent realities and best practices withinthe industry.

The publication of SaskPower’s 10-YearTransmission Development Plan addressesissues identified by the Panel, as found inRecommendations #4 and #5 of its FinalReport:

#4 The Panel recommends thatSaskPower annually publish andcommunicate to stakeholders a 10-year forecast of load growth thatassesses system reliability, identifiesupcoming deficiencies, and outlinesa general plan of improvements toaddress them.

#5 The Panel recommends thatSaskPower annually publish a

capital investment plan that outlinesthe transmission improvementsplanned for the next 5 years. Theplan should be detailed andcomprehensive and include thereason for the investment; thelocation, probable type, andcapacity; the estimated cost; andthe expected dates of public reviewand commissioning.

With publication of this TransmissionDevelopment Plan, SaskPower hasfulfilled the commitment made in responseto the Panel’s Final Report of February2001. Starting with this first Plan,SaskPower will provide update reports onan annual basis.

This Plan discusses planned facilityadditions along with anticipated butunbudgeted additions to SaskPower’stransmission facilities and sub-transmission facilities over the next 10years. This Plan does not discuss plannedadditions to SaskPower’s distributionsystem. This is consistent with the termsof reference for the Transmission LineRouting Review Panel and the definitionof Transmission Facilities as used bythe Panel.

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The transmission developments that arediscussed in this Plan are related to thereinforcement of a number of areas in theprovince. The prime study areas identifiedin the Plan are:

• The Prince Albert and La Ronge StudyArea,

• The Meadow Lake Study Area,

• The Pelican Narrows – DeschambaultLake Study Area,

• The Kindersley – Kerrobert – UnityStudy Area, and

• The City of Saskatoon and City ofRegina Study Areas.

The requirement for new transmissionfacilities into or within these areas isalmost exclusively related to the growth oflocal load in the study areas. There is nodiscussion of specific transmissionassociated with new generation facilities,as at the time the Plan was prepared, noplans for major new generationdevelopments within the province hadbeen identified. SaskPower’s OpenAccess Transmission Tariff may also resultin requirements to build transmissionfacilities within the province. There are anumber of requests for transmissionservice pending under the provisions ofthe tariff. However, at the time ofpreparation of this Plan, it had not beendetermined whether additionaltransmission facilities would berequired to satisfy the requests fortransmission service.

The full Plan can also be found onSaskPower’s web site atwww.saskpower.com.

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SaskPower 10-YearTransmission Development Plan

1.0 Introduction

The SaskPower 10-Year TransmissionDevelopment Plan provides a discussionof SaskPower’s anticipated transmissiondevelopments for the period 2002-2011.

Starting with this first Plan, SaskPowerwill update this document on anannual basis.

The preparation and publication of this 10-Year Transmission Development Plan is inkeeping with SaskPower’s commitment toprovide clear and open communication toour customers across Saskatchewan.

When reviewing the contents ofSaskPower’s 10-Year TransmissionDevelopment Plan, it is important to keepthe following considerations in mind:

• Customer service needs and resultingprojects may arise that are notincluded.

• SaskPower may be in discussions withcustomers who do not wish to have thediscussions prematurely disclosedbecause of the potential to compromisecommercial or competitive interests.

1.1 ContextThe impetus for preparing a SaskPowerTransmission Development Plan is foundin the work of the Transmission LineRouting Review Panel, established in June

2000. The Panel’s mandate was to adviseSaskPower on guidelines and practices toguide the routing of transmission lines onprivate and municipal land in the surveyedportion of Saskatchewan.

The construction of transmission lines hasbecome an increasingly challengingproposition for not only SaskPower, butalso all electrical utilities across NorthAmerica. Increased emphasis onenvironmental issues and public reviewsregarding proposed transmission facilitieshas meant additional responsibilities forSaskPower.

When the Transmission Line RoutingReview Panel was convened, its FinalReport was envisioned as a guide to helpSaskPower manage these changingexpectations. The Panel recommendationsregarding public consultation andbenchmarking have become an importantpart of SaskPower’s efforts to ensure thatcorporate guidelines and processes reflectcurrent realities and best practices withinthe industry.

The publication of SaskPower’s 10-YearTransmission Development Plan addressesissues identified by the Panel, as found inRecommendations #4 and #5 of itsFinal Report:

#4 The Panel recommends thatSaskPower annually publish andcommunicate to stakeholders a 10-year forecast of load growth thatassesses system reliability, identifiesupcoming deficiencies, and outlines

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a general plan of improvements toaddress them.

#5 The Panel recommends thatSaskPower annually publish acapital investment plan that outlinesthe transmission improvementsplanned for the next 5 years. Theplan should be detailed andcomprehensive and include thereason for the investment; thelocation, probable type, andcapacity; the estimated cost; andthe expected dates of public reviewand commissioning.

With publication of this TransmissionDevelopment Plan, SaskPower hasfulfilled the commitment made inresponse to the Panel’s Final Report ofFebruary 2001.

1.2 Document ScopeThis document discusses planned facilityadditions along with anticipated butunbudgeted additions to SaskPower’stransmission facilities and sub-transmission facilities. This documentdoes not discuss planned additions toSaskPower’s distribution system. This isconsistent with the terms of reference forthe Transmission Line Routing ReviewPanel and the definition of TransmissionFacilities as used by the Panel.

For the purposes of this document,SaskPower differentiates between plannedfacilities and anticipated but unbudgetedfacilities. Planned facilities are thosefacilities that have had funds, for the

purposes of covering the cost of projectconstruction, allocated in the capitalbudget which is part of SaskPower’s five-year business plan. SaskPower, has alsoidentified projects that may occur withinthe next five years, but are not currentlyincluded in its business plan document.These projects may have been left out ofthe plan because of their tentative nature,or because they may be driven bycustomer requirements and are still at thepreliminary stages of discussion.SaskPower has also identified projectswhich are beyond the five-year businessplan, but which are expected to occurbased upon the 10-year load forecast andsupply development requirements.

As a matter of clarification, transmissionprojects that are identified in SaskPower’sfive-year capital plan are not necessarilycommitted. Major projects that areincluded in the business plan are normallysubmitted on the basis of a preliminaryassessment of need. These projects arestill required to go through final technicalstudies and internal approval bySaskPower’s Executive and Board (asdictated by the notional value of aproject). During the internal reviewprocess, projects listed in the BusinessPlan may change because of the finaltechnical studies, changes in theload forecast or changes incustomer requirements.


2.0 Definition of SaskPower’s Facilities

SaskPower’s power line facilitiesassociated with the delivery of electricalpower from the source to the end usercan be broken down into threegeneral categories:

• Grid Transmission Facilities

• Sub-transmission Facilities

• Distribution Facilities

2.1 Grid Transmission FacilitiesThe North American Electric ReliabilityCouncil (NERC)1 identifies the purpose ofthe grid transmission system or‘interconnected transmission system’as follows2:

The interconnected transmission systemsare the principal media for achievingreliable electric supply. They tie togetherthe major electric system facilities,generation resources, and customerdemand centers. These systems must beplanned, designed, and constructed tooperate reliably within thermal, voltage,and stability limits while achieving theirmajor purposes. These purposes are to:

Deliver Electric Power to Areas ofCustomer Demand — Transmissionsystems provide for the integration ofelectric generation resources and electricsystem facilities to ensure the reliabledelivery of electric power to continuously

changing customer demands under a widevariety of system operating conditions.

Provide Flexibility for Changing SystemConditions — Transmission capacity mustbe available on the interconnectedtransmission systems to provide flexibilityto handle the shift in facility loadingscaused by the maintenance of generationand transmission equipment, the forcedoutages of such equipment, and a widerange of other system variable conditions,such as construction delays, higher thanexpected customer demands, andgenerating unit fuel shortages.

Reduce Installed Generating Capacity —Transmission interconnections withneighboring electric systems allow for thesharing of generating capacity throughdiversity in customer demands andgenerator availability, thereby reducinginvestment in generation facilities.

Allow Economic Exchange of ElectricPower Among Systems — Transmissioninterconnections between systems, coupledwith internal system transmissionfacilities, allow for the economic exchangeof electric power among all systems andindustry participants. Such economytransfers help to reduce the cost of electricsupply to customers.

SaskPower’s grid transmission system(Figure #1, pg. 6) consists of theinterconnected power lines and associatedequipment involved in the transfer of

1 The North American Electric Reliability Council (NERC) is a not-for-profit corporation. NERC's members are the ten Regional Transmission Councils. The members of theseRegional Councils come from all segments of the electric industry: investor-owned utilities; federal power agencies; rural electric cooperatives; state, municipal and provincialutilities; independent power producers; power marketers; and end-use customers. These entities account for virtually all the electricity supplied in the United States, Canada, and aportion of Baja California Norte, Mexico. Since its formation in 1968, NERC has operated as a voluntary organization to promote bulk electric system (transmission system) reliability and security

2 NERC Planning Standards document, September 1997, page 7


electric energy between major points ofsupply and major points of delivery. Bydefinition, grid transmission lines alwaysoriginate and terminate at switchingstations. The switching station may beassociated with a supply point (connectionof a power plant) or load points where thetransmission voltage is stepped down to avoltage suitable for use on the sub-transmission or distribution system. Thetransmission system includes the facilitiesassociated with the bulk transfer ofelectric energy between Saskatchewan andAlberta, Manitoba and North Dakota. Thegrid transmission lines in Saskatchewangenerally operate at voltages of 230,000volts (230 kV3) or 138,000 volts (138 kV).SaskPower has grid transmission lines innorthern Saskatchewan that operate at110,000 volts and 115,000 volts. Powerflow levels on individual grid transmissionlines operating at 230,000 volts canexceed 300,000 kW4.

2.2 Sub-Transmision FacilitiesThe sub-transmission system (Figure #2pg. 7) consists of the power lines that takeelectrical energy from switching stationsand deliver it directly to larger customers,or to smaller load centers (sub-stations) inurban and rural areas where it istransformed for delivery onto SaskPower’sdistribution system. The majority ofSaskPower’s sub-transmission systemoperates at 72,000 volts (72 kV); however,there are some sub-transmission facilitiesoperating at 138,000 volts (138 kV).SaskPower has approximately 4,400 km of

72 kV sub-transmission power lines.Power flow levels on individual sub-transmission lines are normally below30,000 kW. The exception to this is theshorter sub-transmission lines that supplythe highly concentrated loads inurban areas. The loading on these sub-transmission lines can exceed 100,000 kW.

2.3 Distribution FacilitiesThe distribution system delivers electricalenergy from SaskPower’s sub-stations tothe majority of SaskPower’s customers.The distribution system consists of powerlines in the range of 25,000 volts down to4,160 volts, and secondary distribution,which operates at voltages below 4,160volts. The majority of SaskPower’sdistribution system is a25,000 volt (three phase –three wire) / 14,400 volt (single phase –single wire) system. SaskPower hasapproximately 22,800 km of overhead25,000 volt powerline, 700 km ofunderground 25,000 volt powerline,72,400 km of overhead 14,400 voltpowerline and 42,900 km of underground14,400 volt powerline. The majority ofSaskPower’s distribution system, in termsof the length of facilities, is associatedwith the supply of loads in rural areas.Farm and rural residence loads aregenerally supplied directly from the14,400 volt system via individualtransformers at the customer’s site whichdrop the voltage to the customer’sutilization voltage. In urban areas, thedistribution system includes secondary

3 kV is an abbreviation meaning thousands of volts4 kW is an abbreviation meaning thousands of watts. Watt is a measure of electrical power. The term electrical power is used interchangeably withelectrical demand.


voltage power lines operating at 120/240volts (generally located in alleys or ineasements) which are used to collect theloads of a number of individual customersin a city block for supply from anindividual transformer. The power transferon individual 25,000 volt power lines inrural areas is typically in the order of3,000 kW. However, the loading onindividual 25,000 volt power lines thatsupply highly concentrated loads in urbanareas can exceed 8,000 kW.

3.0 Transmission System Performance Criteria

SaskPower plans additions to its gridtransmission and sub-transmissionfacilities in an attempt to ensure that theywill continue to operate in a satisfactorymanner in the future as the requirementsimposed on the system changes.SaskPower uses a number of criteria toassess what constitutes satisfactoryperformance. These criteria can be placedinto the following general categories:

• adequacy - the ability of the electricsystem, with all facilities in service, tosupply the aggregate electrical demandand energy requirements of customersat all times, while maintainingadequate system voltages and withoutincurring apparatus overloads, andtaking into account scheduled andreasonably expected unscheduledoutages of system elements,

• security (applies to the interconnected

grid transmission system) – refers tothe ability of the interconnectedtransmission system to withstandsudden disturbances such as electricshort circuits or unanticipated loss ofsystem transmission elements withoutcausing extended loss of load oruncontrolled shut down of thepower system,

• reliability- reliability is an allencompassing description. As used byNERC, it includes an assessment of theadequacy and security of thetransmission system. SaskPower usesthe term reliability as a term distinctfrom adequacy and security, whendiscussing the performance of the sub-transmission system where the NERCconcepts of system security do notapply. When assessing the reliabilityof the sub-transmission system,SaskPower’s objective is to ensure thatthe frequency and duration of poweroutages to customers is kept to anacceptable level, and

• cost effectiveness - ensuring that thetotal annual cost of the transmissionsystem (including capital costs,transmission loss costs andmaintenance costs) is minimized.

Adequacy and security criteria receiveequivalent consideration when assessingthe need for grid transmission facilityadditions. As noted, security criteria arenot applicable to the sub-transmissionsystem. Adequacy and reliability are themost important criteria in assessing the


Figure #12002 Grid Transmission Facilities


Figure #2 2002 72kV Subtransmission Facilities


need for sub-transmission facilities. Costeffectiveness by itself rarely becomes adriver for new transmission facilities.Cost criteria come in to play whendetermining such items as the mosteffective conductor size for a transmissionline, or when evaluating the merits of oneparticular reinforcement scheme againstanother scheme.

3.1 Transmission System AdequacyThe flow of electric power overtransmission lines generally causes thevoltage at the receiving end of the powerline to be lower than the voltage at thesending end of the power line.SaskPower’s objective is to maintain thelevel of the voltage at delivery points highenough such that it is able to meet theCanadian Standard Association (CSA)standard Preferred Voltage Levels for ACSystems 0 to 50,000 V (CAN3-C235-83).This generally requires that the voltage atdelivery points on the sub-transmissionsystem not be allowed to drop below 90%of nominal voltage. Voltages at sourcepoints on the grid transmission systemnormally operate at nominal or greaterbecause of transmission securityconsiderations and a desire to minimizelosses on the transmission system.

In addition to maintaining adequatevoltages, it is also SaskPower’s objectiveto ensure that its facilities are capable ofdelivering power without exceeding theratings of the transmission equipment.Equipment limits are normally determinedby the ability of the equipment to

withstand the increasing internaltemperature rise resulting from increasedloading (elevated temperatures lead toaccelerated aging of insulation andeventual insulation breakdown). In thecase of transmission lines, ratings mayalso be set by the available clearancebelow the energized conductor. As thelevel of power flow on a transmission lineincreases, the conductor heats up. Thethermal expansion resulting from thehigher operating temperature of theconductor causes it to lengthen, with theresult that it droops more between supportstructures. This results in a reduction inthe clearance between the conductor andground. The CSA establishes standardsfor the minimum acceptableground clearance.

As power flow increases on transmissionfacilities, it may be necessary to upgradeor add additional facilities in order tomaintain adequate voltages and maintainequipment within acceptableloading levels.

3.2 Transmission System SecuritySaskPower’s grid transmission systemexperiences regular disturbances, whichcan cause a forced outage of atransmission line or other transmissioncomponents. The most significant causeof transmission line forced outages isadverse weather (greater than 45%.)5

SaskPower designs its interconnected gridsystem so that it can tolerate a singleelement outage (a single grid line or gridtransformer) without seriously degrading

5 Annual average for the 10-year period from 1992-2001


customer service reliability. The factorsSaskPower takes into consideration inevaluating the security of its transmissiongrid are the ability to withstand the loss ofany single transmission element withoutcausing:

• cascade tripping of any remainingtransmission lines,

• cascade tripping of generator units dueto real or reactive power overloads,

• the transmission system to becomedynamically unstable, or

• incurring system voltage collapse.

The security criteria for SaskPower’s gridtransmission facilities are largelyconsistent with the NERC systemadequacy and security requirements.NERC’s planning standards for systemadequacy and security are as follows 6:

‘1A S1. The interconnected transmissionsystems shall be planned,designed, and constructed suchthat with all transmissionfacilities in service and withnormal (pre-contingency)operating procedures in effect,the network can delivergenerator unit output to meetprojected customer demandsand provide contracted firm(non-recallable reserved)transmission services, at alldemand levels, under theconditions defined in CategoryA of Table I (attached).’

‘1A S2 The interconnected transmissionsystems shall be planned,designed, and constructed suchthat the network can beoperated to supply projectedcustomer demands andcontracted firm (non-recallablereserved) transmission services,at all demand levels, under theconditions of the contingenciesas defined in Category B ofTable I (attached).’

‘The transmission systems alsoshall be capable ofaccommodating planned bulkelectric equipment maintenanceoutages and continuing tooperate within thermal, voltage,and stability limits under theconditions of the contingenciesas defined in Category B ofTable I (attached).’

‘1A S3. The interconnected transmissionsystems shall be planned,designed, and constructed suchthat the network can beoperated to supply projectedcustomer demands andcontracted firm (non-recallablereserved) transmission services,at all demand levels, under theconditions of the contingenciesas defined in Category C ofTable I (attached). Thecontrolled interruption ofcustomer demand, the plannedremoval of generators, or thecurtailment of firm (non-

6 NERC Planning Standards document, September 1997, page 9 -10


recallable reserved) powertransfers may be necessary tomeet this standard.’

‘The transmission systems alsoshall be capable ofaccommodating planned bulkelectric equipment maintenanceoutages and continuing tooperate within thermal, voltage,and stability limits under theconditions of the contingenciesas defined in Category C ofTable I (attached).’

1A S4. The interconnected transmissionsystems shall be evaluated forthe risks and consequences of anumber of each of the extremecontingencies that are listedunder Category D of Table I(attached).

In NERC standard IA S2, Category Bconditions include the loss of a singleelement such as a generator, transmissioncircuit or transformer. The NERCstandard 1A S2 criteria requires that theloss of this element be withstood whetherit be induced by a single line to groundfault or a three-phase line to ground fault.The significance of this is that the three-phase fault imposes a much more severedisturbance on the power system than thesingle line to ground fault; however, three-phase faults are extremely rare. The 10-year average for all grid transmission lineforced outages is 2117 per year forSaskPower’s system. However, theaverage for three-phase faults on its grid

transmission system is only five per year.Because of their low probability,SaskPower has not explicitly designed itstransmission system to provide servicewithout interruption following a three-phase fault. As a result, not all theelements of SaskPower’s existingtransmission system are compliant withthe NERC category B requirement forwithstanding three phase faults.SaskPower is generally planning its futureadditions to the transmission system suchthat they follow the NERC planningstandards for adequacy. SaskPower iscurrently reviewing options forcompliance on existing facilities.

SaskPower is generally in compliancewith the performance requirements ofNERC standard 1A S3; however, it doeshave some non-conformance issues withrespect to the systems it uses forcontrolling the loss of load.

3.3 Transmission System ReliabilityAs noted, SaskPower uses the termreliability, as a term distinct fromadequacy and security, when discussingthe performance of the sub-transmissionsystem. The concepts of system securityespoused by the NERC planningstandards, which require the ability tomaintain service following the loss of oneor two elements, do not apply to the sub-transmission system. The majority of thesub-transmission system consists of serialelements with only one point of supply.There are no parallel paths connected overwhich power can flow in the event that

7 For the 10-year period from 1992 to 2001


one of the serial elements fails.

When assessing the reliability of the sub-transmission system, SaskPower’sobjective is to ensure that the frequencyand duration of power outages tocustomers is kept to an acceptable level.SaskPower does not currently set specifictargets for sub-transmission system outagefrequency and duration, in part becauseoutage frequency is affected by the lengthof the sub-transmission line (longer lineswill be have a greater possibility ofweather induced outages due to theirgreater exposure). The 10-year averagefor SaskPower’s average interruptionfrequency per sub transmission line, due toall causes, is 4.88 interruptions per year.The 10-year average annual interruptionduration per sub-transmission line is 1289

minutes per year. When particular lineshave significant deviation from theaverage, SaskPower assesses remedialaction, such as it is carrying out on thePA8 and ML3 72 kV sub-transmission lines.

The reliability of the transmission linesthat extend north from the Island FallsSwitching Station to Rabbit Lake andUranium City are not assessed on thesame basis as southern sub-transmissionlines. These power lines are built inremote areas, through the CanadianShield, which does not permit effectivegrounding and lightning protection on thepower lines. As a result, these power linesexperience a very high frequency oflightning induced outages. Restoration

times can be long because of the length ofthe system, complexity of the system, andaccess issues in the event of permanentequipment damage. These power lineswere built for the express purpose ofproviding electrical service to northernmine sites and the limitations imposed bythe location of the facilities wasrecognized in the supply arrangements thatwere negotiated with the customers.

3.4 Cost Effectiveness of theTransmission System

The flow of electrical power over atransmission element results in parasiticpower and energy loss due to theresistance of the element. This energyloss manifests itself as heating of thetransmission element. At peak load, theparasitic losses on SaskPower’s gridtransmission system use up about 5% ofthe power that is delivered fromgeneration sources.

Parasitic losses can be reduced by addingadditional transmission circuits to reducethe magnitude of flows on individualelements, raising the operating voltage oftransmission lines, or increasing the size oftransmission conductors.

The reduced energy losses represent a costsaving to SaskPower since less fuel isrequired to serve the loads. Also, thereduction in losses results in a lower overallsystem instantaneous power demand whichreduces the amount of generation capacitythat is required to serve the load, whichrepresents a further capital cost saving.

8 For the 10-year period from 1992-20019 For the 10-year period from 1992-2001


4.0 Major Drivers of Need for NewTransmission Facilities

Additions to the transmission system arenormally required because of an expectedviolation of SaskPower’s performancecriteria. Violation of system adequacy, inparticular the ability to maintainsatisfactory voltage, is the performancecriteria that most often drives requirementsfor new transmission or sub-transmissionfacilities. SaskPower checks for violationsof its performance criteria using analyticalcomputer models. Violations of theperformance criteria predicted by themodels usually results from forecastincreases in power flow over transmissionor sub-transmission facilities. The majordrivers contributing to increased powerflows include:

• Growth of general provincial load,

• Connection of new generation,

• Connection of new large industrialloads, and

• Increased utilization of thetransmission system as a result ofSaskPower’s Open AccessTransmission Tariff

Other factors, which are unrelated toincreased power transfers, but mayresult in a requirement for newtransmission include:

• Aging infrastructure, and

• Compliance with the NERCreliability standards

A general discussion of each of thesedrivers follows.

4.1 Load GrowthSaskPower generates two load forecasts;the Corporate load forecast and theRegional load forecast. The Corporateforecast provides an end-use basedforecast of the total annual domesticelectrical energy requirements thatSaskPower will have to supply for the next10 years. The Regional Load Forecastprovides a breakdown of the expectedannual peak demand 10 and annual energyusage at every major delivery point(switching station or large industrialcustomer) that is connected toSaskPower’s transmission system.

4.1.1 Corporate 10-Year Load Forecast

The load forecast is developed on anannual basis in order to determine theenergy requirements and peak demand forSaskPower’s customers in the province ofSaskatchewan. This forecast forms thebasis for capacity additions, maintenanceschedules, power plant operations, fuelbudgets, operation budgets andCorporate revenue.

The 2001 Load Forecast was prepared forthe years 2001-2011 using inputs from the2001 SaskPower Economic Forecast,historical energy sales, and individualcustomer forecasts. This forecast is acompilation of energy sales forecasts forKey Account, Oilfield, Commercial,Residential, Farm, and Reseller customers.The forecast also includes projections for

10 DEMAND – The rate at which electrical energy is delivered to or used by a system or part of a system at a given instant or averaged over anydesignated interval of time. Demand is generally expressed in kilowatts (kW) or megawatts (MW). The term electrical power is used interchangeablywith electrical demand.


internal corporate use, system losses andunaccounted energy use, and non-gridenergy use.

Weather can have a significant impact onthe amount of electricity used byResidential, Commercial, Farm, andReseller customers. Due to this weathersensitivity, average daily weatherconditions for the last 30 years areassumed throughout the forecast horizon.

The 2001 Load Forecast predicts anincrease in the total system energyrequirements of 3,082 GW.h11 over thenext 10 years. This increase from 18,179GW.h in 2001 to 21,261 GW.h in 2011translates into an average annual growthrate of 1.6% (Figure #3, pg. 14). Thehistorical average annual growth rate was3.2% for the years 1990-2000.

The system peak load is expected toincrease by 475 MW from 2,882 MW12 in2001 to 3,357 MW in 2011(Figure #4,pg. 14). This equates to an average annualgrowth rate of 1.5%. The demand at timeof system peak grew at an average annualrate of 2.0% for the years 1990-2000.

A report documenting the methodologybehind the derivation of the forecast data,the assumptions and the forecast resultsfor the 2001-2011 timeframe, is availablefrom SaskPower on request.

4.1.2 Regional Load Forecast

The Corporate forecast is useful formaking decisions about future energy andcapacity supply requirements for the

province as a whole. The Corporateforecast is not particularly useful forforecasting future requirements for thetransmission system since it does notidentify the location of load growth withinthe province. As an example, theCorporate forecast will provide anestimate of total oilfield load growthwithin the province, but will not bespecific as to which oilfields willexperience the growth. To address thisdeficiency, SaskPower creates a separateload forecast report called the RegionalLoad Forecast.

The Regional Load Forecast is developedon an annual basis in order to determinethe energy requirements and peak demandfor SaskPower’s major delivery points onthe transmission system. The RegionalLoad Forecast provides the expectedannual peak demand and annual energyusage at every major delivery point(switching station or large industrialcustomer) that is connected toSaskPower’s transmission system. Theforecast for each delivery point has beendeveloped based on the historicalrelationship between the peak demand atthe delivery point and the aggregatedemand for the whole system.Information about the historicalrelationship between delivery pointdemands and the system demand isderived from SaskPower’s real timemonitoring system for the grid and itsinterval metering system for gridconnected customers.

11 GW.h means Giga watt-hours. Electrical energy is measured in units of watt-hours. A giga watt-hour is 1,000,000,000 watt-hours.12 MW is an abbreviation meaning millions of watts.


Total Energy Requirements Forecast

12,000

14,000

16,000

18,000

20,000

22,000

1990 1992 1994 1996 1998 2000 2002 2004 2006 2008 2010

GW.h

ActualRequirements

ForecastRequirements

Energy Requirements = Energy Sales + Losses

System Peak Load Forecast

1,500

2,000

2,500

3,000

3,500

1990 1992 1994 1996 1998 2000 2002 2004 2006 2008 2010

MW

Actual Peak

Forecast Peak

Figure #3

Figure #4


The Regional Forecast provides anindication as to where the load increasesare occurring. An increase in the peakdemand is normally the biggest factor indriving the requirement for reinforcementof the transmission system. This forecastforms the primary basis for determiningthe requirements for reinforcing thetransmission system to supply increasingcustomer demand at the various bulkelectric system delivery points onSaskPower’s transmission system.

4.2 Connection of New GenerationNew generation facilities requireinterconnection with SaskPower’s systemif the generation is going to be used tosupply energy to SaskPower customers orfor export out of the province. In general,generators up to about 1,000 kW in sizecan be incorporated into the distributionsystem. Any generators above 5,000 kWwill almost certainly require connectioninto the sub-transmission ortransmission system.

Connection of major generationdevelopments such as a hydro project or acoal fired generation project, which aretypically remote from load centers,requires the addition of significanttransmission facilities. Generationdevelopments, which are based around co-generation at existing industrial loads, canquite often be integrated with minimalamounts of transmission. This isespecially true if the load sites are close tomajor provincial load centers, or if theeffect of the generation is to reduce,

or reverse flows on existingtransmission facilities.

Integration of wind power generationprojects presents an unusual problem.Individual wind turbines tend to be lessthan 1,000 kW in size; however, becausethe wind resource is very site specific, thepractice is to develop large clusters ofmachines at individual sites or ‘windpower projects’. Integration of these windpower projects usually requires theconstruction of some transmission or sub-transmission facilities. This comment alsoapplies to so called smaller ‘distributionconnected generation’ technologies if alarge number of these generation units areclustered at a particular location.

For details on the technical requirementsassociated with the connection ofgeneration to SaskPower’s system, refer tothe documents ‘Non-Utility GenerationInterconnection Requirements at Voltages25 kV and Below’ and ‘Non-UtilityGeneration Interconnection Requirementsat Voltages 72 kV and Above’ which areavailable at www.saskpower.com.

SaskPower posts an interconnection queueon the public portion of its OASIS13 website (http://mapp.oasis.mapp.org/documents/SPC/spc_info_public.htm). The purposeof the interconnection queue is to facilitatethe non discrimination provisions inSaskPower’s Standard of Conduct14 bymaking public all requests that have beenmade for a study to evaluate aninterconnection with SaskPower’s

13 OASIS - OASIS stands for Open Access Same Time Information System and is the internet based system which provides information related to theprovision of transmission service under SaskPower’s Open Access Transmission Tariff (OATT) along with providing the means for eligible customers tosubmit requests for transmission service under the SaskPower’s OATT.


transmission system. Interconnectionstudy requests are typically for generators,but may also be submitted by entities thatare requesting the interconnection oftransmission facilities with SaskPower’ssystem. The queue lists the date of therequest, the size of the interconnection, thelocation of the interconnection and thestatus of the request. Due toconfidentiality issues, the queue does notidentify the requestor; however, allrequests, including those submitted bySaskPower for the supply of domesticload, and requests submitted bySaskPower’s affiliates NorthPoint EnergySolutions and SaskPower International, arelisted in the queue. As of 2002 March 31,there were no requests for studies forinterconnection of new generation projectswith SaskPower’s transmission system.

4.2.1 New SaskPower Generation Developments

Prior to 1990, SaskPower did all of itsown planning and development in terms ofnew generation resources required tosupply increasing domestic load. Giventhis approach to supply planning,SaskPower was able to develop a long-term view on where all major generationprojects and associated transmissionfacilities were going to be located. In themid-1990s, SaskPower changed itsapproach to supply development.SaskPower still continues planning interms of identifying the quantity andtiming for new generation developments,but it no longer acts as the exclusivedeveloper of generation projects in the

province for domestic supply. Examplesof projects which have or are being builtto supply SaskPower load but which arenot under the direct ownership ofSaskPower are the Meridian CogenerationProject at Lloydminster, the SunBridgeWind Power Project near Gull Lake andthe Cory Cogeneration Stationnear Saskatoon.

SaskPower is no longer acting as the onlyproject developer in the province, and assuch, it does not have an exclusive viewon the location and associatedtransmission for all future generationdevelopments in the province. Potentialgeneration developers will take intoconsideration the location of resources, beit the availability of suitable hosts foreconomical cogeneration projects, oroptimal wind power regimes. The amountthat SaskPower is prepared to pay apotential developer for the supply ofelectrical energy is influenced by the costof integrating that resource intoSaskPower’s system. Developers mayselect sites with the objective ofminimizing the amount or cost oftransmission required to integrate aparticular generator site. SaskPowercurrently posts information (internalresource penalty factors) on its OASISinternet web site which allows potentialdevelopers to assess the impact of anypotential generation site on transmissionsystem losses.

At present, SaskPower has two newsupply sources, the Cory Non-utility co-

14 Copies of the Standard of Conduct are available on SaskPower’s OASIS web site


generation project and Queen ElizabethPower Station Unit #1 repowering project.Both will be in service by year-end 2002.As a result, SaskPower’s most recentreview of its resource requirements hasdetermined that major new supplydevelopments for domestic load are notexpected before 2008. This date is basedupon SaskPower’s current load forecastand is subject to revisions in the loadforecast. In addition, SaskPower may beengaging in some small-scale generationdevelopments prior to 2008 to facilitatespecific programs such as GreenPower.

4.3 Connection of New Major LoadsDepending on the characteristics of theload, it may be possible to accommodatean individual customer load as large as1,000 to 5,000 kW on the distributionsystem, if it is located in or near urbanareas. Without special consideration, it isgenerally not possible to supply a load thislarge via the distribution system in ruralareas. New loads greater that 5,000 kWwill almost certainly require connection tothe sub-transmission system or thetransmission system. The choice ofconnection to the sub-transmission systemor the transmission system will depend onthe proximity of existing SaskPowerfacilities, the size (peak demand) of theload, characteristics of the load and theeconomics of the overall project. Thelatter factor tends to balance the fact thatthe higher transmission voltages tend tohave lower transmission losses and lowertransmission rates, but the cost for the

facilities to connect the load is higher.Depending on the loads peak demand andannual energy requirements, the rate andloss savings may or may not pay for thehigher facilities cost.

4.4 SaskPower’s Open AccessTransmission Tariff (OATT)

In November of 2001, SaskPower postedan Open Access TransmissionTariff (OATT).

Under the provisions of SaskPower’sOATT, eligible transmission customers canrequest transmission service fromSaskPower which may require theconstruction of new transmission or sub-transmission facilities in Saskatchewan.This transmission service may, or may notbe associated with the supply of loadlocated within Saskatchewan. Under theprovisions of its tariff, SaskPowerprovides equal treatment and considerationfor all transmission whether it is beingbuilt by SaskPower for the supply ofdomestic load, or to satisfy a servicerequest under the provisions ofSaskPower’s OATT.

Traditionally, generation projects weredeveloped exclusively by SaskPower forthe purpose of supplying domestic load.Under SaskPower’s Open AccessTransmission Tariff (OATT), proponentsinterested in the development ofgeneration projects for the purpose ofsupplying energy to entities other thanSaskPower can request connection to thetransmission system and service over


SaskPower’s transmission system todeliver that energy to the desired location.SaskPower may be required to buildtransmission to integrate these projects, orto provide the transmission servicerequired to facilitate the ultimate deliveryof this energy. These projects may bedriven by market conditions for electricalenergy outside of Saskatchewan. Due tothe volatility of some of these markets,project proponents tend to defer decisionson these projects to the last possiblemoment. As SaskPower receives requestsfor new interconnections to itstransmission system, these requests areadded to the Interconnection Study Queue,which is posted on the public portion ofSaskPower’s OASIS web site.

SaskPower has received a number ofrequests for transmission service under theprovisions of its tariff. Some of theseservice requests exceed the transmissionsystem transfer limits that are currentlyposted on SaskPower’s OASIS site.Analytical studies are currently under wayto assess the requirements associated withservicing these requests. The first groupof studies has yet to be completed, and assuch, it is not known whether anytransmission facilities will have to beadded to service the requests. In addition,the transmission customers have to agreeto the terms and conditions of thetransmission service before any facilitieswould be built.

4.5 Aging InfrastructureSaskPower currently has slightly over

13,000 circuit kilometers of transmissionand sub-transmission power lines inservice. In 1972, SaskPower hadapproximately 9,100 kilometers oftransmission and sub-transmission powerline in service. Without consideration ofthe small amount of sub-transmissionfacilities that have been removed fromservice since 1972, approximately 70% ofSaskPower’s transmission and sub-transmission facilities are in excess of 30years of age. SaskPower has a largenumber of 138 kV transmission lines inservice that date back to construction inthe 1950s, which is the same timeframefor the construction of the majority ofSaskPower’s 72 kV sub-transmission system.

For accounting purposes, SaskPowercurrently uses a composite expected assetlife of 45 years for transmission lineassets. The expected asset life, and thecurrent age of the majority of SaskPower’stransmission line assets would suggest thatSaskPower has an emerging issueassociated with the replacement of agingtransmission lines. The reality is thatSaskPower engages in a program ofcontinual monitoring of the condition ofits transmission line assets. In the case ofwood pole construction, deterioration ofthe poles due to rot at the ground line isnormally the biggest problem. WhereSaskPower detects pole deterioration, itcarries out stubbing or replacement of thefailing poles. SaskPower also checks linehardware for integrity and tightness.


SaskPower’s older transmission lines havereached the point where they requireregular inspection and a higher level ofmaintenance than a new transmission line.However, the cost of this annualinspection and maintenance is well belowthe cost of replacement. Due to theinspection and maintenance program,SaskPower’s older transmission lines arenot approaching the end of their useful lifebased upon their physical condition.Since 1987, all new major transmissionand sub-transmission projects have beenconstructed with tubular steel instead ofwood. To date, the tubular steel designhas proven to require very low levelsof maintenance.

Based upon the transmission linemaintenance practices that SaskPower hasengaged in, and the new steel designs thatSaskPower has adopted, it is anticipatedthat there will be very little newtransmission line construction required toaddress replacement of existingtransmission lines solely due to age relateddeterioration. There may be some caseswhere some older transmission lines areexceeding their rating due to increasedloading, and a decision has been made toreplace them; however, this is an issue oftransmission adequacy, not age.

There are a couple of locations wheretransmission line replacement is in partbeing precipitated by facility age andcondition. There are a number of sub-transmission lines in north centralSaskatchewan, among them PA8 and

ML3, that were built with insulatorsknown as pin-type insulators. Thesepin–type insulators have a design flawcalled cement growth, which leads to thedevelopment of cracks in the porcelaininsulator skirt and its subsequent failure.In the case of PA8 and ML3, because thepower lines are also running into problemswith voltage adequacy, a decision has beenmade to retire the lines and replace themwith new facilities.

4.6 Compliance with NERC ReliabilityStandards

Since its formation in 1968, the NorthAmerican Electric Reliability Council(NERC) has operated as a voluntaryorganization to promote bulk electricsystem (transmission system) reliabilityand security. In promoting electric systemreliability and security, one of NERC’sactivities is the on-going development ofoperating policies and planning standardsto ensure bulk electric system reliability.NERC has also been active in developinga process for measuring compliance withits operating policies and standardsthrough the Regional Councils thatconstitute its membership.

NERC’s mandate for ensuring security andreliability does not extend to settingstandards for the sub-transmission systemor the distribution system. Compliancewith the operating policies and planningstandards is not currently enforced throughany federal or provincial regulations;however, the policies and standards are tosome extent viewed as ‘good utility


practice’. Some of the regionaltransmission entities, which haveestablished contractual agreements withtheir members, make compliance with theNERC policies and standards acondition of membership, which isestablished through the contractualmembership agreements.

SaskPower is participating in theassessment of compliance with the NERCpolicies and standards being carried out bythe Mid-continent Area Power Pool(MAPP), the Regional Council with whichSaskPower is associated. Most of thecompliance issues that have beenidentified are associated withdocumentation deficiencies thatSaskPower is working to address.However, the NERC standards set outrequirements that are more onerous thanSaskPower’s current performance criteriawhen it comes to withstanding certaintypes of forced outages on transmissionequipment. SaskPower is aware that itmay have some compliance issues relatedto the performance of the transmissionsystem following the loss of particularcomponents of its grid transmissionsystem. These compliance issues arediscussed in more detail in section 5.3.Addressing these performance deficienciesmay require the construction of newtransmission facilities.

Grid transmission reliability and securityhave always been historical drivers oftransmission need in Saskatchewan.However, compliance with the specific

requirements of NERC has not.SaskPower has yet to make a decision asto whether it is going to adopt fullcompliance with the NERC standards.This decision will in part be driven by thebusiness issues associated with being partof the overall interconnected mid-continent transmission system of theUnited States and Canada, along with thecost of achieving full compliance.

5.0 Evaluation of Requirements forTransmission SystemDevelopments

The evaluation of the requirement fortransmission system reinforcement hasbeen carried out by study areas within theprovince. The study areas are shown onFigure #5, (pg 21). The projects that fallwithin each study area are discussed. Thestatus of each of the projects is indicatedon the following basis:

• The project has been approved bySaskPower for construction (externalapprovals may still be pending),

• The project is in SaskPower’s five-yearcapital plan,

• It is anticipated that the project couldoccur within the next five years, butthe project is not currently inSaskPower’s five-year capital plan, and

• It is anticipated that the project couldoccur within the next five to 10 years.

Appendix B provides a listing of all thetransmission projects that have been


MEADOW LAKESTUDY AREA

PRINCE ALBERT -LA RONGE STUDY AREA

PELICAN NARROWS -DESCHAMBAULT LAKE

STUDY AREA

KINDERSLEY -KERROBERT - UNI TY

STUDY AREA

Figure #5 Provincial Study Areas


included in SaskPower’s five-year capitalplan. The five-year spending plan isupdated quarterly. The plan attached asAppendix B was the most current versionwhen this document was being prepared.In the interest of keeping the list relevant,not all transmission projects inSaskPower’s five-year capital plan arelisted in Appendix B. Projects that involvethe communication, protection or controlfacilities associated with SaskPower’stransmission system are not listed becausethey generally do not have any impact onthe public. Projects that have expendituresover the five year period that total lessthan $50,000 have also been deleted fromthe list in the interests of brevity.

5.1 The Prince Albert and La RongeStudy Area

5.1.1 Reinforcement of the Supply to La Ronge

La Ronge, and most of the communitiesnorth of Prince Albert, are provided withelectrical service via the PA8 power line.PA8 is a 256 km long, 72 kV power linefed from the Prince Albert SwitchingStation. It supplies power to fourdistribution substations north of PrinceAlbert; Spruce Home, Timber Cove,Weyakwin and La Ronge. The majority ofthe load on the line (about 65%) is at theLa Ronge Substation located at the northend of the line.

The annual growth in peak load demand atLa Ronge has averaged 5.8% since 1981,which is well above the provincial averageof approximately 2.4% for the same

period. This rapid growth has resulted inan ongoing problem associated withmaintaining acceptable voltage atLa Ronge. To date, this problem has beenhandled by adding 72 kV voltageregulators15 to the line and installingcapacitors at the various substations alongthe line. There are presently five, 72 kVvoltage regulators in the PA8 power line.

In addition to the voltage problems, asnoted in Section 4.5, there have beeninsulator problems with sections of thePA8 power line, which compromise thereliability of service to La Ronge. ThePA8 power line structures have alsoexperienced pole failures as a result ofdamage to the poles caused by carpenterants and woodpeckers.

The current solution of continuing to add72 kV voltage regulators to the PA8 powerline has led to deteriorating service qualityfor the customers supplied from PA8, thepotential for customer equipment damage,and increasing costs for SaskPower and itscustomers. As the number of seriesvoltage regulators in the line increases,coordination of the operation of theindividual voltage regulators has alsobecome increasingly difficult. As a resultof the coordination problems, customersexperience increased voltage fluctuations(shows up as flickering of lights). At peakload times, customers could ultimatelyexperience extended periods of alternatelyhigh and low voltage leading to thepotential for improper operation of, ordamage to, customer equipment.

15 Voltage regulators are devices, connected in series with the power line, which boost the operating voltage along the power line. The purpose of thevoltage regulator is to attempt to compensate for the voltage drop in a power line caused by the flow of line current through the impedance of thepower line.

Prince Albert and LaRonge Study Area


Prince Albert

Weyakwin

WaskesiuLake

Timber Bay

Spruce HomeMeath Park

Prince Albert

National Park

La Ronge

NipawinProvincial Park

Candle Lake

Christopher Lake

Melfort

Lac La Ronge

Provincial Park

Emma Lake

Air Ronge

Phase I ReinforcementPhase II ReinforcementExisting line

Figure #6


Because of the size of wire utilized onPA8, the existing power line incurs veryhigh transmission line losses. At the timeof peak load, approximately 35% of thepower that is supplied into the line goestowards the supply of losses. These lossescost SaskPower and its customersapproximately $1.5 million in 1999. Theannual cost of supplying these losses willincrease as the load supplied from theline increases.

SaskPower’s plan for reinforcement of LaRonge is based upon a multi-stagereplacement / reinforcement of the PA8power line. The first stage ofreinforcement provides for replacement ofthe portion of PA8 between Prince Albertand Timber Cove with a power lineequipped with larger conductor andinsulated for future 138 kV operation.This project has been approved and is inthe process of being completed. The newsection of power line will continue tooperate at 72 kV until 2003. In 2003, thesecond stage of the reinforcement planprovides for conversion of the new line to138 kV operation to supply a new 138-72kV switching station to be built at TimberCove. This project has been approved forconstruction. After completion of stagetwo, the portion of PA8 from Timber Coveto La Ronge will continue to operate at72 kV.

A third stage of reinforcement, consistingof rebuilding the section of PA8 betweenTimber Cove and Tracy Road(approximately 74 km north of Timber

Cove) is being studied. The tentative in-service date for stage three is 2004. Thestage three project is in SaskPower’s five-year capital plan.

The larger conductor and higher operatingvoltage will address the voltage controland transmission loss problems on PA8.The use of steel poles structures withmodern composite insulators will improveservice reliability.

5.1.2 Transmission Reinforcement for the PrinceAlbert Area

The loads in the immediate Prince Albertarea, along with communities north (up toLa Ronge) and northeast of Prince Albert,are supplied from a number of 72 kV and138 kV distribution substations, which areall supplied from the Prince AlbertSwitching Station. The Prince AlbertSwitching Station, which is located justsouthwest of Prince Albert is, in turn,supplied via a double circuit 138 kVtransmission line (designated B1P andB2P) from the Beatty Switching Stationlocated west of Melfort. Based on currentforecast peak demand growth in the PrinceAlbert area, reinforcement may berequired by 2010 because of an inability tomaintain satisfactory voltages at the PrinceAlbert Switching Station. However, thepossibility of new industrial sites orexpansion at existing industrial sites in thearea will accelerate this requirement. It isexpected that this reinforcement would beprovided via a new 230 kV transmissionline extending between the Prince AlbertSwitching Station load supply point and


the Beatty Switching Station.

It is anticipated that reinforcement couldbe required within the next five to10 years.

There has been some discussion of thepossibility of additional or new non-utilitygeneration in the Prince Albert area. Theaddition of a moderate amount ofgeneration in the Prince Albert area couldpossibly defer the need for systemreinforcement. However, a very largegeneration project could accelerate therequirement for reinforcement to ensure asecure connection of the generation to theprovincial grid.

5.2 The Meadow Lake Study Area

5.2.1 Reinforcement of the Supply to the AreaNorth of Meadow Lake

The communities north of Meadow Lakeare provided with electrical service via theML3 power line. ML3 is a 300 km long,72 kV power line fed from the MeadowLake Switching Station. It supplies powerto five distribution substations north ofMeadow Lake; Dore Lake, Beauval, Ile ala Crosse, Buffalo Narrows and TurnorLake, as well as to NorSask ForestProducts, located just northeast of thetown of Meadow Lake.

The annual growth in peak demandassociated with the load on ML3 hasaveraged 4% since 1981, which is wellabove the provincial average ofapproximately 2.4% for the same period.This rapid growth has resulted in an

ongoing problem associated withmaintaining acceptable voltage at thecommunities along the line. To date, thisproblem has been handled by adding72 kV voltage regulators to the line,rebuilding portions of the line andinstalling capacitors at the varioussubstations along the line. There arepresently two 72 kV voltage regulators inthe power line.

In addition to the voltage controlproblems, as noted in Section 4.5, therehave been insulator problems on sectionsof the ML3 line, which compromise thereliability of service for the customerssupplied from ML3. The ML3 linestructures have also experienced polefailures as a result of damage to the polescaused by carpenter ants.

Due to the size of wire utilized on ML3,the existing power line incurs very hightransmission line energy losses. At thetime of peak load, approximately 23% ofthe power that is supplied into the linegoes towards the supply of losses. Theselosses cost SaskPower and our customersapproximately $1.2 million in 2001. Theannual cost of supplying these losses willincrease as the load supplied from theline increases.

SaskPower’s reinforcement plan for theML3 feeder is a staged developmentsimilar to the La Ronge reinforcementplan. SaskPower has been replacingsections of ML3 with new power lineequipped with much larger conductors,


Meadow LakeSawmill

LITTLE AMYOT LAKE72-25 kV SUBSTATION

BUFFALO NARROWS72-25 kV SUBSTATION

Dillon

La Loche

Turnor Lake

BEATTY LAKE 72 kV VOLTAGE RGULATOR

LITTLE AMYOT 72 kVVOLTAGE REGULATOR

DORE LAKESUBSTATION

BEAUVAL 72-25 kV SUBSTATION

Dore Lake

ILE A LA CROSSE72- 25 kV SUBSTATION

Ile a la Crosse

Patuanak

LEGEND25 kV Line

72 kV Line

Pine House

TURNOR LAKE72-25 kV SUBSTATION

MEADOW LAKESWITCHING STATION

BuffaloN

ML3 72 kV FEEDER

Meadow Lake Study AreaFigure #7


and insulated to allow future conversion to138 kV operation. In March of 1999, the37 km section of ML3 directly north ofBeatty Lake was rebuilt and placed intoservice. In April of 2002 the replacementof the 30 km section of ML3 directlysouth of Beauval will be completed.

Several methods of addressing the futuregrowth in demand, line loss and reliabilityissues have been explored. The results ofthe analyses carried out by SaskPowerindicated that the continued multi-stagereplacement of the ML3 powerline is thepreferred reinforcement option. The thirdstage of reinforcement provides for thereplacement of the 26 km section of ML3from Green Lake to Beatty Lake in late2002. The fourth stage reinforcementprovides for replacement of the 22 kmsection of ML3 from Green Lake, westtowards Meadow Lake by 2004. Furtherreinforcement or extension of the ML3line will depend on the load growth in thearea, the performance of the existing lineand the operating limitations of theexisting system. Current indications arethat the next steps in reinforcement mayconsist of the conversion of the MeadowLake to Beauval section of ML3 to138 kV operation to supply a new 138-72 kV switching station to be located nearBeauval. In addition, the significantincrease in consumer load at La Lochemay require the extension of ML3 from itscurrent northern terminus of Turnor Laketo La Loche.

The third stage of replacement of ML3 has

been approved. The fourth stage ofreplacement of ML3 is in SaskPower’sfive-year capital plan. Conversion of ML3to 138 kV operation and extension of72 kV to La Loche are anticipated tooccur within the next five to 10 years.

5.2.2 Interconnection of a New OSB Plant NearMeadow Lake

To provide process power to the proposednew Tolko Oriented Strand Board (OSB)plant, near Meadow Lake, a new 7.2km,230 kV transmission line will be required.This line will tap off of the existing BR11230 kV transmission line. By tapping offof an existing line, the required newtransmission line length is minimized.

The OSB plant is expected to be in serviceby the end of 2003. The project is inSaskPower’s five-year capital plan.Preliminary engineering and line routingwork has been approved.

5.2.3 Transmission Grid Reinforcement for theMeadow Lake Area

The consumer load in the immediateMeadow Lake area, and the load for all ofthe communities north of Meadow Lake,is supplied from a number of 72 kVdistribution substations, which are allsupplied from the Meadow LakeSwitching Station. The Meadow LakeSwitching Station is, in turn, supplied viaa single 138 kV transmission line from theBrada Switching Station near NorthBattleford. The Meadow Lake SwitchingStation is also connected to the MeadowLake Power Station, which has a single 46


MW gas turbine generator.

As noted in Section 5, SaskPower plansfacilities so that we can continue to supplythe entire load in the event of the failure ofa single piece of equipment. In the case ofthe supply to Meadow Lake, the criticalelement for supply reliability is the single138-72 kV transformer at the MeadowLake Switching Station, which serves theentire load supplied from the SwitchingStation. SaskPower’s plans were that inthe event of failure of this transformer, wewould run the Meadow Lake generator tosupply this load. Increases in the peakdemand associated with the load in thearea supplied from the Meadow LakeSwitching Station mean that the MeadowLake generator is no longer large enoughto supply the Meadow Lake load in theevent that the 138-72 kV transformer fails.

The load growth in the Meadow Lake areahas also created the potential for problemswith maintaining satisfactory voltages atthe Meadow Lake Switching Station. Dueto relatively high forced outage rates forpeaking gas turbine generators like theMeadow Lake unit, SaskPower does notrely on the operation of these units tomaintain service unless there is more thanone unit. Based upon current loadforecasts, SaskPower predicts that by thewinter of 2002 – 2003, the voltage at theMeadow Lake Switching Station will dropto unacceptable levels during peak loadperiods if the Meadow Lake generator isout of service.

SaskPower is evaluating a number ofoptions for addressing the 138-72 kVtransformer capacity problem and thevoltage support problem at Meadow Lake.SaskPower could address the voltagesupport problem by installing reactivecompensation equipment in the MeadowLake Switching Station, or reinforcing theMeadow Lake Switching Station viaconnection to the 230 kV transmission line(BR11) from the Brada Switching Stationwhich supplies the Millar Western PulpMill northeast of Meadow Lake. Althoughthese lines cross, at present there is nointerconnection between the 230 kV and138 kV lines. Reinforcement viaconnection to the 230 kV transmission linecould be accomplished via theconstruction of a 230-138 kV switchingstation at the point where the 230 kV linecrosses the 138 kV line. This wouldminimize the amount of new 230 kVtransmission line construction, but wouldrequire the construction of a newswitching station at that location. Thisalternative would still require additional138-72 kV transformer capacity at theMeadow Lake Switching Station, whichmight require some expansion of theexisting property. Another possible optionis to create a new 230-72 kV switchingstation where the 230 kV transmission linecrosses the ML3 72 kV transmission linewhich is supplied out of the Meadow LakeSwitching Station. This again wouldminimize the amount of new 230 kVtransmission line construction, but wouldrequire the construction of a new


switching station at that location. Thisalternative would also address therequirement for additional newtransformation capacity at the 72 kV level.SaskPower has not selected its preferredreinforcement alternative.

The project is in SaskPower’s five-yearcapital plan.

5.3 The Pelican Narrows –Deschambault Lake Study Area

5.3.1 Supply Reinforcement for Pelican Narrows– Deschambault Lake

The communities of Pelican Narrows, JanLake, Deschambault Lake and Sandy Bayare presently served by a 190 km long,25 kV line extending from a 110-25 kVsubstation at the Island Falls SwitchingStation. The line was constructed in the1980s in order to connect thesecommunities to the SaskPower grid and toenable SaskPower to decommission thediesel plants that had previously servedthem. The combined load of thesecommunities was initially quite small (lessthan 2 MW), but has since grownsubstantially. Over the past two years thepeak demand has increased by more than10% annually and is now approximately6.9 MW. The load in this area is expectedto continue to grow at a rate of more than5% for the foreseeable future, due to thepopulation growth in the area, combinedwith the fact that these communities havedecided to install electric heat in all newand renovated homes. Prior to 2001,propane had been used for home and

water heating.

The high winter load levels have createdprotection coordination problems and haveforced SaskPower to install five sets of 25kV voltage regulators in the line toDeschambault Lake. SaskPower typicallytries to limit the number of voltageregulators in series in a 25 kV line to nomore than three sets.

In order to accommodate the growing loadin this area, SaskPower is evaluating theconstructing of a 110 / 138 kVtransmission line between the Island FallsSwitching Station and the Village ofPelican Narrows which would be used tosupply a new 110-25 kV distributionsubstation near Pelican Narrows. Theaddition of this line would allowSaskPower to remove three of the five setsof 25 kV voltage regulators, correct theprotection coordination problems, reducethe line losses, improve the reliability ofthe electrical service in the area andaccommodate future load growth. Thenew line and substation may also be ableto accommodate the proposed sawmilldevelopments in the area, depending ontheir exact location andload characteristics.

The project is in SaskPower’s five-yearcapital plan.

5.4 The Kindersley – Kerrobert – UnityStudy Area

The loads in the Kindersley, Kerrobert and


Unity area are supplied out of the ErmineSwitching Station which is located justsoutheast of Kerrobert. The Kerrobert,Luseland and Unity 72 kV substations aresupplied out of Ermine on the ER3 72 kVfeeder. The Coleville and Kindersley 72-25 kV substations are supplied out ofErmine on the S1E 72 kV feeder. TheErmine Switching Station is in turn,supplied via three 138 kV transmissionlines designated L2E, E1L and C1E. TheL2E and E1L lines extend south fromLloydminster and North Battleford, andthe C1E line extends west fromCoteau Creek.

5.4.1 Supply Reinforcement for the Area West ofKindersley

The oilfields, in the Marengo area to thewest of Kindersley, are presently servedby a 25 kV feeder from the Kindersley72-25 kV substation. The loads in theseoilfields have been growing over the past 5years and have reached a point whereSaskPower now requires three 25 kVvoltage regulators in the feeder in order tomaintain acceptable voltage levels. Theincreased peak demand associated with theloads is forecast to become an issue interms of the rating adequacy of theKindersley substation transformer. Theincreased demand is also presentingproblems in terms of ensuring that theprotection systems on the feeder supplyingthe loads will have satisfactory protectioncoordination. A number of serviceapplications for new wells in the area haverecently been received from customers and

more are anticipated. In addition, thereare a number of oil well pumps that arepresently running off of well head gas andthe oil companies are consideringconverting these to electric drives. Therehave also been power quality problems inthe Marengo and Mantario areas. Theoperation of several large motors in theseoil fields results in voltage fluctuationsthat violate the permissible limits set bySaskPower for the operation of consumerowned equipment.

In order to accommodate the new loadsand improve the existing level of servicefor customers in the region, SaskPowerproposes to extend a 72 kV line fromKindersley, west for approximately 44 km,and to construct a new 72-25 kVsubstation near Marengo. This project isin SaskPower’s five-year capital plan. It isproposed that preliminary work wouldbegin later in 2002, with an in-service datetentatively slated for September of 2004.

5.4.2 Transmission Reinforcement forKindersley, Kerrobert, Unity

Based on the current forecast of growthfor peak load demand in the Ermine area,reinforcement of the Ermine SwitchingStation may be required by 2010 becauseof an inability to maintain satisfactoryvoltages at the switching station deliverypoint. However, load growth in this areais mainly related to oilfield and pipelineactivity, which is subject to volatility.This makes long-term forecasts difficult.It is expected that this reinforcementwould be provided via a new 230 kV


transmission line to Ermine from a 230kV supply point. This supply could comefrom the Coteau Creek, Queen Elizabeth(Saskatoon), Brada (North Battleford) orLloydminster Switching Stations.

There has been some discussion byindependent power producers of thepossibility of new non-utility generationprojects in the Kerrobert area. Theaddition of an appropriately sized, multi-unit generation facility in this area couldpossibly defer the need for transmissionbased reinforcement for the ErmineSwitching Station. At this time,SaskPower is not aware that any of theseprojects are being pursued.

It is anticipated that the transmissionreinforcement project could occur withinthe next five to 10 years.

5.5 The City of Saskatoon Study AreaThe City of Saskatoon Electricaldepartment serves that portion ofSaskatoon that is within the 1958 Cityboundaries. The area outside of the 1958boundaries, along with the University ofSaskatchewan, is in the SaskPowerfranchise area and this area hasexperienced the majority of the newdevelopments in the Saskatoon area. Thegrowth in demand associated with the loadin SaskPower’s franchise area hasaveraged 3.7% annually for the past 6years. The present peak load demand hasnow reached a point where the threeexisting transmission lines (QE6, Q3E &QE18), which serve this area, need to bereinforced. QE6 is a 72 kV line, which

serves the west side of the City, as well asthe customers in and around Dalmeny andRosthern. Q3E is a 72 kV line thatsupplies the customers on the east side ofthe City as well as the University ofSaskatchewan and the Royal UniversityHospital. QE18 serves the customers onthe north side of Saskatoon, as well asSterling Chemicals and a portion of theCity of Saskatoon’s franchise area.

It is expected that the City of Saskatoonelectrical load will continue to grow andthat the majority of this load growth willbe in SaskPower’s franchise area. Basedon present load projections, SaskPowerplans to carry out the following work in aneffort to continue to accommodate thisincreasing load.

In 2002, the Q3E 72 kV line will be rebuiltfrom the Queen Elizabeth Switching Station,east for 10.7 km. The new line will havelarger conductor and will be insulated for138 kV, but will continue to operate at72 kV. The north-south portion of Q3Efrom the end of the new line north for 3.5km to the Wildwood Substation will have itsexisting conductor replaced with largerconductor. The larger conductor will reducelosses, voltage drop and have a highertransfer capability. This project will ensurethat the Q3E line will be able toaccommodate the new Canadian LightSource synchrotron project load as well asthe growing load on the east side of the City.

Beginning in 2002, SaskPower also plansto begin working on a 138 kV loop aroundthe west side of the City, with a proposed


South

Sask

atchewan R

iver

SASKATOON NORTH INDUSTRIAL138-25kV SUBSTATION

QE6 (72 kV)

To Dalmenyand Rosthern

QE18 (138 kV)

CONFEDERATION PARK72-25 kV SUBSTATION

Q3E (72 kV)

DUNDONALDSUBSTATION

(to be converted to 138 kV)

U of S

SterlingChemicals

City of SaskatoonW. J. Bunn Substation

LEGEND

Existing Lines

New Construction

Queen ElizabethSwitching Station

Q3C (138 kV)

NE

W Q

E1

9 W

ES

T S

IDE

LO

OP

N

ENGEN 138-25KvSUBSTATION

WILDWOOD 72-25KVSUBSTATION

SUTHERLAND 72-25 KVSUBSTATION

CORY 72-25 kVSUBSTATION

Cory GenerationProject

CITY OF SASKATOONFRANCHISE AREA

CITY OF SASKATOON

City of Saskatoon Study AreaFigure #8


in-service date of 2006. This project willinvolve extending a 138 kV line from therecently constructed C3Q line around thewest and north sides of Saskatoon and tieinto the QE18 line in the North Industrialarea. There will also be a 138 kV tap offof this new line into the DundonaldSubstation. The new line will relieve theload on the existing QE18 line and willprovide back up service for the customersin the northern part of Saskatoon. TheDundonald Substation will also betransferred to this new line and will in turnreduce the loading on the QE6 line.

The 138 kV loop project is in SaskPower’sfive-year capital plan.

5.6 The City of Regina Study AreaThe City of Regina, and the rural areasaround the City of Regina, are served by anumber of 72 kV and 138 kV power lines,extending from three Switching Stationslocated on the edges of the City. TheCondie Switching Station, located to thenorthwest of Regina, supplies theresidential and commercial customers inthe north and northwest portions of thecity via the CD4, 138 kV power line andthe C1F and R1C 72 kV power lines. Inaddition, the CD3 138 kV power lineserves the IPSCO steel making facilitynorth of Regina. The Regina SouthSwitching Station, located southeast of thecity, supplies the customers (including theUniversity of Regina) in the southernportion of the city, via the R1C R1R, RE6,and R1F 72 kV feeders. The RE9, 138kV power line supplies the Trans Canada

Pipeline Station located near Richardson.The Fleet Street Switching Station islocated in the northeast area of the cityand serves the customers in the east andnortheast portion of the city, via the C1F,R1F, FS27 and FS29, 72 kV lines and theF2B and FS7 138 kV feeders. In additionto being supply points for the Regina arealoads, the Regina South and CondieSwitching Stations are major switchingpoints on SaskPower’s transmission grid.

The east side of the City of Regina hasbeen experiencing a significant amount ofdevelopment over the past 10 years. As aresult, the adequacy of the existingelectrical distribution facilities in the areaare approaching their limits in terms ofbeing able to supply the areas peak loaddemand. SaskPower plans to address thisdeficiency by providing a new majorinfeed to reinforce the distribution systemin the area. This will be accomplished bythe construction of a new 138-25 kVsubstation, named Wascana. The proposedlocation for the new Wascana Substation isapproximately one-half of a kilometrenorth of Highway #1 and adjacent to theCPR railway tracks. SaskPower plans tosupply the substation by tapping into theexisting RE9 138 kV feeder, which issupplied out of the Regina SouthSwitching Station. The WascanaSubstation will be supplied by extendingRE9, from a point near Richardson, northfor approximately 8 km, to the newsubstation site. Work on the project isexpected to begin in 2002, with the in-


R4C (230 kV)

R2

C (

13

8 k

V)

R1

C (

72

kV

)

R1

F (

72

kV

)

Armour Siding 72-25 kV Substation

Coronation72-25 kVSubstation

Broad Street138-14.4 kV& 72-25 kVSubstations

B1

C (

72

kV

)

Powerhouse72-25/14.4 kV Substation

R1

B (

72

kV

)

Athol Street72-25/14.4 kVSubstation

Albert Park 72-25 kVSubstation

Condie 138-25 kV Substation

R1R (72 kV)

C1F (72 kV)

LEGEND:

Underground Cable:Overhead Powerline:

CONDIE SWITCHING STATION

To Lumsdenand Bulyea

CD7(72 kV) To IPSCO

CD3 (138 kV)

CD4 (138 kV)

FLEET STREET

SWITCHING STATION

F2B (138 kV)

FS7 (138 kV)

REGINA SOUTH SWITCHING STATION

RE9 (138 kV) To Trans CanadaPipelines at Richardson

RE7 (72 kV)

To Balgonie &Fort QuAppelle

FS27(72 kV)

CITY OF REGINA

City of Regina Study AreaFigure #9


service date tentatively slated for Augustof 2004.

As a result of the growth in peak demandassociated with the electrical load in theRegina area, transformer capacityincreases are planned at the Regina SouthSwitching Station and the Fleet StreetSwitching Station. These transformeradditions are needed to ensure thatSaskPower can meet its criteria ofcontinuing to supply the load in majorurban areas following failure of onetransformer. At the Regina SouthSwitching Station, additional 138-72 kVtransformation capacity will be added andat the Fleet Street Switching Station,additional 230-138 kV transformationcapacity will be added. It is anticipatedthat these additions can be accommodatedwithin the boundaries of the property thatSaskPower owns at these sites.

The Regina South and Fleet StreetSwitching station transformer projects areplanned to be completed within the nextthree years and are included inSaskPower’s five year capital plan.

SaskPower has evaluated the extension ofthe RE9 138 kV power line from thefuture Wascana Substation to the FleetStreet Switching Station. The extension ofthis power line would provide a 138 k Vtie between the Regina South and FleetStreet Switching Stations. Such aninterconnection could prove useful interms of providing back-up capacity in theevent of a transformer failure at the Fleet

Street Switching Station. This 138 kV tiewould defer the need for transformercapacity at the Fleet Street SwitchingStation. However, SaskPower is notcurrently pursuing this alternative becauseit has other lower cost options such aslocal reinforcement at Fleet Street. Thistie may become a viable option in thefuture.

5.7 Other Projects

5.7.1 Alberta – Saskatchewan Interconnection atLloydminster

SaskPower has received a request for amerchant transmission interconnectionbetween the transmission system of theAlberta Integrated System (AIS) andSaskPower’s transmission system. Theinterconnection would be located in theLloydminster area. The purpose of theinterconnection would be to facilitate thetransfer of electrical energy in and out ofthe AIS energy market under theprovisions of SaskPower’s OATT. Tofacilitate the proposed interconnection, anew 138 kV transmission line will berequired between SaskPower’sLloydminster Switching Station and theAlberta border (less than 10 km).Additional transmission reinforcements atother locations in Saskatchewan might berequired to facilitate the transfers.

The proposed in-service date for theinterconnection is 2003. The project is notcurrently in SaskPower’s five-year capital


plan as an interconnection agreement hasnot been negotiated with the proponent.

5.7.2 Connection of Wind Generation in the AreaSouthwest of Swift Current

At present, wind generation appears to bethe most economical and commerciallyavailable technology for supplyingdemands for GreenPower. The southwestarea of the province will soon be the homefor two wind projects (SunBridge &Cypress) as the region has a good windregime and a vast geographic area. Theaddition of further wind generation willrequire some upgrading of the existingtransmission facilities in the area and,depending on the location of the new windpower projects, there may be arequirement to extend the sub-transmission system.

At the present time there are no firm plansfor additional wind generation in the area,but depending on several factors (interestin green power, energy prices, technology,etc) projects may be forthcoming. Thereasonably short time frame (less than 1year) for installing a wind project, allowsdevelopers to monitor the market and actquickly when the conditions are right.The short turn around time for theseproponents makes it difficult forSaskPower to forecast and plan thedevelopment of the transmission system inpotential areas, such as the southwest partof the province.

It is anticipated that these projects couldoccur within the next five years, but the

projects are not currently in SaskPower’sfive-year capital plan.

5.7.3 Alberta Newsprint Mill

Discussions have been taking place withAlberta Newsprint with respect to thedevelopment of a new newsprint mill inthe north central part of the province.Studies by Alberta Newsprint are at apre-feasibility stage. As such, the decisionto proceed, timing and location of the millhave not been determined. However, theanticipated size of the electrical loadassociated with the facility suggests thatextension of a 230 kV transmission linewould be required to provide service tothe facility.

It is anticipated that the project couldoccur within the next five years, but theproject is not currently in SaskPower’sfive-year capital plan.

APPENDIX ANERC Planning Standards

NERC Planning StandardsI. System Adequacy and Security A. Transmission Systems

Table I. Transmission Systems Standards Normal and Contingency Conditions

Contingencies System Limits or ImpactsCategory

Initiating Event(s) and Contingency Component(s)Components

Out of ServiceThermalLimits

VoltageLimits

SystemStable

Loss of Demand orCurtailed Firm Transfers

Cascadingc

Outages

A - NoContingencies

All Facilities in Service None Normal Normal Yes No No

Single Line Ground (SLG) or 3-Phase (3Ø) Fault, with Normal Clearing:1. Generator2. Transmission Circuit3. Transformer

Loss of a Component without a Fault.

SingleSingleSingleSingle

ApplicableRating

a

(A/R)A/RA/RA/R

ApplicableRating

a (A/R)

A/RA/RA/R

YesYesYesYes

No b

No b

No b

No b

NoNoNoNo

B - Event resultingin the loss of a singlecomponent.

Single Pole Block, Normal Clearing:4. Single Pole (dc) Line Single A/R A/R Yes No

b No

SLG Fault, with Normal Clearing:1. Bus Section2. Breaker (failure or internal fault)

MultipleMultiple

A/RA/R

A/RA/R

YesYes

Plannedd

Plannedd

NoNo

SLG or 3Ø Fault, with Normal Clearing, Manual System Adjustments,followed by another SLG or 3Ø Fault, with Normal Clearing:

3. Category B (B1, B2, B3, or B4) contingency, manual systemadjustments, followed by another Category B (B1, B2, B3, or B4)contingency

Multiple A/R A/R Yes Plannedd No

Bipolar Block, with Normal Clearing:4. Bipolar (dc) Line

Fault (non 3Ø), with Normal Clearing:5. Double Circuit Towerline

MultipleMultiple

A/RA/R

A/RA/R

YesYes

Plannedd

Plannedd

NoNo

C - Event(s)resulting in the lossof two or more(multiple)components.

SLG Fault, with Delayed Clearing:6. Generator 8. Transformer7. Transmission Circuit 9. Bus Section

MultipleMultiple

A/RA/R

A/RA/R

YesYes

Plannedd

Plannedd

NoNo

10

-Y

EA

RT

RA

NS

MIS

SIO

ND

EV

EL

OP

EM

EN

TP

LA

N37

10

-Y

EA

RT

RA

NS

MIS

SIO

ND

EV

EL

OP

ME

NT

PL

AN

38

NERC Planning StandardsI. System Adequacy and Security A. Transmission Systems

D e - Extreme eventresulting in two ormore (multiple)components removedor cascading out ofservice

3Ø Fault, with Delayed Clearing (stuck breaker or protection system failure):1. Generator 3. Transformer2. Transmission Circuit 4. Bus Section

3Ø Fault, with Normal Clearing:5. Breaker (failure or internal fault)

Other:6. Loss of towerline with three or more circuits7. All transmission lines on a common right-of way8. Loss of a substation (one voltage level plus transformers)9. Loss of a switching station (one voltage level plus transformers)

10. Loss of a all generating units at a station 11. Loss of a large load or major load center 12. Failure of a fully redundant special protection system (or remedial

action scheme) to operate when required 13. Operation, partial operation, or misoperation of a fully redundant

special protection system (or remedial action scheme) for an event orcondition for which it was not intended to operate

14. Impact of severe power swings or oscillations from disturbances inanother Regional Council.

Evaluate for risks and consequences.

• May involve substantial loss of customer demand and generation in a widespread areaor areas.

• Portions or all of the interconnected systems may or may not achieve a new, stableoperating point.

• Evaluation of these events may require joint studies with neighboring systems.• Document measures or procedures to mitigate the extent and effects of such events.• Mitigation or elimination of the risks and consequences of these events shall be at the

discretion of the entities responsible for the reliability of the interconnectedtransmission systems.

Footnotes to Table I.

a) Applicable rating (A/R) refers to the applicable normal and emergency facility thermal rating or system voltage limit as determined and consistently applied by the system or facility owner.

b) Planned or controlled interruption of generators or electric supply to radial customers or some local network customers, connected to or supplied by the faulted component or by the affected area,

may occur in certain areas without impacting the overall security of the interconnected transmission systems. To prepare for the next contingency, system adjustments are permitted, including

curtailments of contracted firm (non-recallable reserved) electric power transfers.

c) Cascading is the uncontrolled successive loss of system elements triggered by an incident at any location. Cascading results in widespread service interruption which cannot be restrained from

sequentially spreading beyond an area predetermined by appropriate studies.

d) Depending on system design and expected system impacts, the controlled interruption of electric supply to customers (load shedding), the planned removal from service of certain generators, or the

curtailment of contracted firm (non-recallable reserved) electric power transfers may be necessary to maintain the overall security of the interconnected transmission systems.

e) A number of extreme contingencies that are listed under Category D and judged to be critical by the transmission planning entity(ies) will be selected for evaluation. It is not expected that all

possible facility outages under each listed contingency of Category D will be evaluated.

1 0 - Y E A R T R A N S M I S S I O N D E V E L O P E M E N T P L A N39

APPENDIX BSummary of Capital Expenditures on Transmission System for 2002 to 2006

Appendix B (pg. 40-42) provides a listingof all the transmission projects that havebeen included in SaskPower’s five-yearcapital plan. The five-year spending planis updated quarterly. The plan shown hereas Appendix B was the most currentversion when this document was beingprepared. In the interest of keeping the listrelevant, not all transmission projects inSaskPower’s five-year capital plan arelisted in Appendix B. Projects that involvethe communications, protection or controlfacilities associated with SaskPower’stransmission system are not listed becausethey generally do not have any impact onthe public. Projects that have expendituresover the five year period that total lessthan $50,000 have also been deleted fromthe list in the interest of brevity.

Transmission Capital Projects2002 - 2006 Capital Plan

Project status: A - indicates that project has been internaly approved by SaskPower for construction

Project ID Project Title Project Driver 1 Project Budget Budget Budget Budget Budget BudgetStatus 2002 2003 2004 2005 2006 Totals

MEADOW LAKE AREA PROJECTSD428 ML3 72 KV LINE REBUILD - STAGE 2 Adequacy violation

due to load growthA $2,734,051 $0 $0 $0 $0 $2,734,051

D425 ML3 72 KV LINE REBUILD - STAGE 3 Adequacy violation due to load growth $3,049,000 $0 $0 $0 $0 $3,049,000

ML3 72 KV LINE REBUILD - STAGE 4 Adequacy violation due to load growth $0 $0 $500,000 $1,500,000 $3,500,000 $5,500,000

MEADOW LAKE 230 KV SWITCHING STATION Load growth - 1st contingency reliability $250,000 $4,750,000 $0 $0 $0 $5,000,000

T050 TOLKO OSB PLANT PRELIMINARY ROUTING New Customer Load A $130,000 $0 $0 $0 $0 $130,000

PRINCE ALBERT AREA PROJECTSD474 LINE - PA8 Rebuild - Stage 2 Adequacy violation

due to load growthA $65,000 $763,000 $0 $0 $0 $828,000

D474 SS - PA8 Rebuild - Stage 2 (Timber Cove) Adequacy violation due to load growth

A $400,000 $1,431,115 $0 $0 $0 $1,831,115

D474 CP&C - PA8 Rebuild Stage 2 Adequacy violation due to load growth

A $0 $801,000 $0 $0 $0 $801,000

D474 PA8 LINE REBUILD - STAGE 2 Adequacy violation due to load growth

A $465,000 $2,995,115 $0 $0 $0 $3,460,115

T164 PA8 REBUILD - STAGE 1 - Phase II Adequacy violation due to load growth

A $4,613,000 $300,000 $0 $0 $0 $4,913,000

PA8 REBUILD STAGE 3 Adequacy violation due to load growth $100,000 $2,700,000 $8,000,000 $0 $0 $10,800,000

CHRISTOPHER LAKE SUBSTATION - CONVERSION TO 138 KV

Change in supply voltage $0 $1,400,000 $0 $0 $0 $1,400,000

SASKATOON AREA PROJECTST174A GENERATION CONNECTION - QUEEN ELIZABETH

UNIT 1 REPOWERING PROJECTNew generation connection

A $19,000 $0 $0 $0 $0 $19,000

T175A GENERATION CONNECTION - CORY COGENERATION PROJECT

New generation connection

A $5,110,855 $0 $0 $0 $0 $5,110,855

T176A QUEEN ELIZABETH SWITCHING STATION FACILITY UPGRADES

Replacement / Rebuild A $2,580,375 $1,664,996 $0 $0 $0 $4,245,371

T181-AB QE19 138 KV WEST SIDE LOOP PROJECT Adequacy violation due to load growth

A $42,000 $62,000 $100,000 $6,097,000 $1,217,000 $7,518,000

D464 Q3E - QUEEN ELIZABETH 72 LINE REBUILD - STAGE 1

Adequacy violation due to load growth

A $1,450,000 $0 $0 $0 $0 $1,450,000

CORY SUBSTATION TRANSFORMER CAPACITY INCREASE

Load growth - 1st contingency reliability $0 $0 $0 $805,000 $0 $805,000

D369 DUNDONALD SUBSTATION TRANSFORMER CAPACITY INCREASE

Load growth - 1st contingency reliability $0 $0 $0 $0 $578,000 $578,000

WILDWOOD SUBSTATION TRANSFORMER CAPACITY INCREASE

Load growth - 1st contingency reliability $0 $0 $712,000 $0 $0 $712,000

1 - Refer to sections 3 and 4 of the report for an explanation and discussion of the criteria which drives the need for new transmission facilities. 2002 -2006 Plan Page 1




T195 SASKATOON NORTH INDUSTRIAL SUBSTATION TRANSFORMER CAPACITY INCREASE

Load growth - 1st contingency reliability

A$150,000 $0 $0 $0 $0 $150,000

ENGEN 138-25 KV SUBSTATION TRANSFORMER CAPACITY INCREASE

Load growth - 1st contingency reliability $0 $0 $0 $0 $615,000 $615,000

REGINA AREA PROJECTSD317A REGINA POWERHOUSE SUBSTATION REBUILD Replacement / Rebuild A $2,710,111 $0 $0 $0 $0 $2,710,111

T042 FLEET STREET SWITCHING STATION - ADDITION OF SECOND 230-138kV TRANSFORMER

Load growth - 1st contingency reliability $2,080,000 $2,131,000 $0 $0 $0 $4,211,000

T157 REGINA SOUTH SWITCHING STATION - ADDITION OF THIRD 138-72kV TRANSFORMER


T105 REGINA - WASCANA SUBSTATION PROJECT Adequacy violation due to load growth

A $250,000 $1,478,000 $2,530,000 $0 $0 $4,258,000

T109 FLEET STREET SWITCHING STATION 138-25 kV TRANSFORMER ADDITION


$0 $0 $0 $0 $18,000 $18,000

OTHER PROJECTST191 SENLAC 138-25 KV SUBSTATION PROJECT Adequacy violation

due to load growthA $2,813,000 $0 $0 $0 $0 $2,813,000

T203A CANTUAR SUBSTATION PROJECT Replacement A $272,000 $0 $0 $0 $0 $272,000D305 DAVIDSON 72-25 kv SUBSTATION TRANSFORMER

CAPACITY INCREASECustomer Driven Capacity $0 $629,000 $0 $0 $0 $629,000

D334 GLASLYN SUBSTATION REBUILD Replacement $281,000 $500,000 $0 $0 $0 $781,000D358 SHAUNAVON SUBSTATION TRANSFORMER

CAPACITY INCREASECustomer Driven Capacity $0 $0 $0 $0 $783,000 $783,000

T015 CODETTE SWITCHING STATION - ADDITION OF SECOND 230/72kV TFMR


SWIFT CURRENT 138-72 KV TRANSFORMER CHANGEOUT

Load growth - 1st contingency reliability $500,000 $0 $0 $0 $0 $500,000

T159 SWIFT CURRENT SWITCHING STATION - ADDITION OF 138-72kV TRANSFORMER

Load growth - 1st contingency reliability $0 $50,000 $4,952,000 $0 $0 $5,002,000

SWIFT CURRENT DISTRIBUTION SUSBSTATION REBUILD

Replacement / Rebuild $300,000 $1,000,000 $0 $0 $0 $1,300,000

T182 TANTALLON SWITCHING STATION - ADDITION OF 138-72kV TRANSFORMER CAPACITY

Load growth - 1st contingency reliability $0 $0 $4,582,000 $0 $0 $4,582,000

T197 CHAPLIN SWITCHING STATION - SECOND 138-72kV TRANSFORMER

Load growth - 1st contingency reliability $0 $0 $0 $2,323,000 $0 $2,323,000

L2E 138 KV LINE VOLTAGE REINFORCEMENT - HEARTS HILL CAPACITOR

Adequacy violation due to load growth $0 $0 $0 $0 $1,000,000 $1,000,000

MIDALE 72-25 KV SUBSTATION TRANSFORMER CAPACITY INCREASE.

Adequacy violation due to load growth $0 $800,000 $0 $0 $0 $800,000





Glaslyn Capacitor Move Reliability $100,000 $0 $0 $0 $0 $100,000FUTURE REPLACEMENT OF EXISTING WOOD DISTRIBUTION SUBSTATIONS DUE TO DETERIORATION

Replacement / Rebuild$0 $2,000,000 $2,000,000 $2,000,000 $2,000,000 $8,000,000

PONTRILAS DISTRIBUTION SUBSTATION REBUILD Replacement / Rebuild $0 $800,000 $0 $0 $0 $800,000

PELICAN NARROWS � DESCHAMBAULT LAKE AREA REINFORCEMENT

Adequacy violation due to load growth $2,440,000 $12,845,000 $0 $0 $0 $15,285,000

T299 NERC COMPLIANCE PHASE I & II - TRANSMISSION UPGRADES

Contingent project $2,000,000 $1,800,000 $0 $0 $0 $3,800,000

C686 NERC COMPLIANCE PHASE I & II - COMMUNICATION, PROTECTION AND CONTROL UPGRADES

Contingent project$100,000 $100,000 $100,000 $0 $0 $300,000

Apache Canada - Midale: 72 kV Service New customer load $1,365,000 $0 $0 $0 $1,365,000Wood Pole Life Extension Replacement / rebuild $10,000,000 $10,000,000 $10,000,000 $10,000,000 $10,000,000 $50,000,000

D313 NIPAWIN SUBSTATION REBUILD Replacement / rebuild A -$320,000 $0 $0 $0 $0 -$320,000

D318 RED JACKET SUBSTATION 72-25 KV TRANSFORMER CAPACITY INCREASE.


A $301,000 $0 $0 $0 $0 $301,000

D342A SUNBRIDGE WIND GENERATION PROJECT CONNECTION

New Generation A $455,000 $0 $0 $0 $0 $455,000

D344 PARKMAN 72 25 KV SUBSTATION Adequacy violation due to load growth

A $1,245,000 $0 $0 $0 $0 $1,245,000

D366 BALGONIE SUBSTATION TRANSFORMER CAPACITY INCREASE


A $10,000 $60,000 $0 $0 $0 $70,000

D380 MOOSE JAW 'A' SUBSTATION TRANSFORMER CAPACITY INCREASE


A$1,986,000 $0 $0 $0 $0 $1,986,000

T006 PEEBLES SWITCHING STATION 230-138 KV TRANSFORMER ADDITION


A$2,408,000 $0 $0 $0 $0 $2,408,000

T045 BEATTY SWITCHING STATION - ADDITION OF THIRD 230-138kV TRANSFORMER ADDITION


A$3,126,000 $0 $0 $0 $0 $3,126,000

T045 BOUNDARY DAM SWITCHING STATION - REPLACEMENT OF 901T 230-138 KV TRANSFORMER


A$1,684,000 $0 $0 $0 $0 $1,684,000


SaskPower 10-Year Transmission Development Plans3.amazonaws.com/zanran_storage/ · 10-YEAR...

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