Cranberry Creek Facilities Study - BC Hydro - Transmission
Cranberry Creek Facilities Study - BC Hydro - Transmission
Cranberry Creek Facilities Study - BC Hydro - Transmission
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XXXXCRANBERRY CREEK POWER PROJECTINTERCONNECTION FACILITIES STUDYREPORT NO. SPA 2007-018F30-MAR-2007REVISION 0
<strong>Cranberry</strong> <strong>Creek</strong> Power ProjectInterconnection <strong>Facilities</strong> <strong>Study</strong> SPA 2007-018FCRANBERRY CREEK POWER PROJECT(T31)INTERCONNECTION FACILITIES STUDYTABLE OF CONTENTSDisclaimer ..................................................................................................................................... iiExecutive Summary ..................................................................................................................... iii1.0 Introduction .......................................................................................................................11.1 Terms of Reference.....................................................................................................12.0 System Studies .................................................................................................................22.1 Faults Levels ...............................................................................................................33.0 Description of Interconnection <strong>Facilities</strong>............................................................................33.1 Direct Assignments .....................................................................................................43.2 Network Upgrades.......................................................................................................54.0 Implementation and Schedule...........................................................................................55.0 Cost Estimate for <strong>Facilities</strong>................................................................................................55.1 Items Included in the Cost Estimate............................................................................65.2 Items Excluded from the Cost Estimate ......................................................................65.3 Conditional Items for the Cost Estimate ......................................................................65.4 Disclaimer....................................................................................................................7Appendix A: DocumentationIFS - R0 © British Columbia <strong>Transmission</strong> Corporation, 2007. All rights reserved. i
<strong>Cranberry</strong> <strong>Creek</strong> Power ProjectInterconnection <strong>Facilities</strong> <strong>Study</strong> SPA 2007-018FDISCLAIMERScope and LimitationsThis report was prepared by <strong>BC</strong>TC solely for the purposes described in this report and is basedon information available to <strong>BC</strong>TC as of the date of this report. Accordingly, this report is suitableonly for such purposes and is subject to any changes arising after the date of this report.Unless otherwise expressly agreed to by <strong>BC</strong>TC, <strong>BC</strong>TC does not represent or warrant theaccuracy, completeness or usefulness of this report or any information contained in this reportfor use or consideration by any third party, nor does <strong>BC</strong>TC accept any liability out of reliance bya third party on this report, or any information contained in this report, or for any errors oromissions in this report. Any use or reliance by third parties is at their own risk.CopyrightCopyright and all other intellectual property rights are expressly reserved to <strong>BC</strong>TC. Without priorwritten approval of <strong>BC</strong>TC, no part of this report shall be reproduced or distributed in any manneror form whatsoever.IFS - R0 © British Columbia <strong>Transmission</strong> Corporation, 2007. All rights reserved. ii
<strong>Cranberry</strong> <strong>Creek</strong> Power ProjectInterconnection <strong>Facilities</strong> <strong>Study</strong> SPA 2007-018FEXECUTIVE SUMMARYThis report contains a description and associated costs for the <strong>BC</strong>TC facilities that arenecessary so that XXXX’s proposed <strong>Cranberry</strong> <strong>Creek</strong> Power Project (CRA) can be connected tothe <strong>Transmission</strong> System. The scope of this CRA project covers the addition of a 3.3 MW unit tothe South <strong>Cranberry</strong> Energy Project that is being developed by the same company. <strong>BC</strong>TC hascompleted the Interconnection Impact <strong>Study</strong> of the South <strong>Cranberry</strong> Energy Project.The new unit will connect to the South <strong>Cranberry</strong> Energy Project 69/4.2 kV station transformerrated at 14 MVA. Power from this new third unit will be transferred to the <strong>Transmission</strong> Systemon the same line serving the two-unit South <strong>Cranberry</strong> Energy Project.The Point of Interconnection (POI) will be a tap on the 60L219 transmission circuit between theWalter Hardman (WHN) and Pingston (PIN) Generating Stations.The maximum power to be injected into the <strong>Transmission</strong> System is 3.3 MW (“FacilityInterconnection Capacity”).This report addresses the interconnection only and any use of firm or non-firm transmissioncapacity will require further analysis specific to the transmission service that may be requested.The P50 cost estimate, with an accuracy of -10%, +20%, is summarized in the following tableand includes direct costs, contingency, inflation, overhead and interest during construction (onthe Network Upgrade portion):Direct Assignments (DA)Network Upgrade (NU)Total$111.5k$44.5k$156.0k (+ GST)The interconnection of the <strong>Cranberry</strong> <strong>Creek</strong> Power Project to the <strong>Transmission</strong> System does notprovide XXXX with any rights to transmit or deliver electricity beyond the Point ofInterconnection.IFS - R0 © British Columbia <strong>Transmission</strong> Corporation, 2007. All rights reserved. iii
<strong>Cranberry</strong> <strong>Creek</strong> Power ProjectInterconnection <strong>Facilities</strong> <strong>Study</strong> SPA 2007-018F1.0 INTRODUCTIONXXXX (“IPP”) is proposing the <strong>Cranberry</strong> <strong>Creek</strong> Power Project (CRA) which is the addition of athird generating unit to their South <strong>Cranberry</strong> Energy Project. The proposed new generating unitwill have a rated capacity of 3.3 MW. The new generator will have a 3.7 MVA rating with apower factor of 0.9 (lagging).The new unit will connect to the South <strong>Cranberry</strong> Energy Project 69/4.2 kV station transformerrated at 14 MVA. Power from this new third unit will be transferred to the <strong>Transmission</strong> Systemon the same line serving the two-unit South <strong>Cranberry</strong> Energy Project.The Point of Interconnection (POI) will be a tap on the 60L219 transmission circuit between theWalter Hardman (WHN) and Pingston (PIN) Generating Stations. The distance between the POIand the WHN substation is approximately 5.2 km and will be the only connection to thegenerating plant.The vast area network is a radial system with an existing small local load. Most of the powergenerated by the IPPs in the area will be transferred by 66 kV line via the IllecillewaetSubstation (ILL) to the <strong>Transmission</strong> System. At present, there is only one ILL 66/230 kVtransformer to transfer the power generated and this system configuration will not be changed inview of the existing IPP connections in the area.The maximum power to be injected into the <strong>Transmission</strong> System is 3.3 MW (“FacilityInterconnection Capacity”).This report contains a description and associated costs for the <strong>BC</strong>TC facilities that arenecessary so that the <strong>Transmission</strong> System can accommodate the <strong>Cranberry</strong> <strong>Creek</strong> PowerProject.This report addresses the interconnection only and any use of firm or non-firm transmissioncapacity will require further analysis specific to the transmission service that may be requested.The interconnection of the Generator System to the <strong>Transmission</strong> System does not provide theGenerator with any rights to transmit or deliver electricity beyond the Point of Interconnection.1.1 Terms of ReferenceOn 12-Sep-2006, the “IPP” executed an Interconnection Impact <strong>Study</strong> and <strong>Facilities</strong> <strong>Study</strong>Agreement (“Agreement”) with <strong>BC</strong>TC.This report documents the Interconnection <strong>Facilities</strong> <strong>Study</strong> portion of the work described in theAgreement. The studies are based on the technical submission of the “IPP” attached inAppendix A of the Agreement.The Interconnection Impact <strong>Study</strong> is presented in a separate report (SPA 2007-018M).The Project Interconnection Requirements (PIR) are presented in Schedule A of the <strong>Facilities</strong>and Interconnection Agreements.IFS - R0 © British Columbia <strong>Transmission</strong> Corporation, 2007. All rights reserved. 1
<strong>Cranberry</strong> <strong>Creek</strong> Power ProjectInterconnection <strong>Facilities</strong> <strong>Study</strong> SPA 2007-018F1.1.1 Facility DesignationsThe following designations are used throughout this Interconnection <strong>Facilities</strong> <strong>Study</strong>:FacilityXXXX<strong>BC</strong> <strong>Hydro</strong><strong>BC</strong> <strong>Transmission</strong> Corporation<strong>Cranberry</strong> <strong>Creek</strong> Power ProjectIllecillewaet SubstationPingston Generating StationSouthern Interior Control CentreSystem Control CentreWalter Hardman Generating StationDesignation“IPP” or Generator<strong>BC</strong>H<strong>BC</strong>TCCRAILLPINSICSCCWHN1.1.2 AssumptionsThe following assumptions have been made in the preparation of this Interconnection <strong>Facilities</strong><strong>Study</strong> Report:• <strong>BC</strong>TC is the interconnecting operating authority.• There is only one transformer at the Illecillewaet substation (ILL 66/230 kV) to transfer thepower generated by the Pingston IPP, Walter Hardman and South <strong>Cranberry</strong> Energy Projectgenerating facilities to the main system along the 2L253 230 kV bus. This systemconfiguration will not be changed with the addition of this <strong>Cranberry</strong> <strong>Creek</strong> Power Project.• The South <strong>Cranberry</strong> Energy Project and all inter-connection, protection and associatedtelecommunications facilities will be in-service before the addition of the new 3.7 MVAgenerator unit.• The Hauer <strong>Creek</strong> IPP is in-service and a new data concentrator at SIC is in place before theaddition of the <strong>Cranberry</strong> <strong>Creek</strong> Power Project.• Telus service is not available at the CRA facility location.2.0 SYSTEM STUDIESPower flow, short circuit, analytical, transient stability, protection, control, andtelecommunications studies were performed to identify any <strong>Transmission</strong> System limitations andrequirements for interconnecting the “IPP” together with any associated Direct Assignment (DA)<strong>Facilities</strong> and Network Upgrades (NU).For details, refer to the Interconnection Impact <strong>Study</strong> – Report No. SPA 2007-018M.IFS - R0 © British Columbia <strong>Transmission</strong> Corporation, 2007. All rights reserved. 2
<strong>Cranberry</strong> <strong>Creek</strong> Power ProjectInterconnection <strong>Facilities</strong> <strong>Study</strong> SPA 2007-018F2.1 Faults LevelsThe present minimum and maximum fault levels at the POI (±20% accuracy), expressed asThevenin Impedances, are:Present Minimum Fault Levels (excluding contribution from the IPP)Fault Type Thevenin Impedance Units AssumptionsZ + = R + + jX + Z1 = 2.59 + j18.32 ohmsZ 0 = R 0 + jX 0 Z0 = 2.26 + j26.27 ohmsPingston IPP out of servicePresent Maximum Fault Levels (excluding contribution from the IPP)Fault Type Thevenin Impedance Units AssumptionsZ + = R + + jX + Z1 = 1.53 + j12.51 ohmsZ 0 = R 0 + jX 0 Z0 = 1.89 + j18.85 ohmsNormal system; CRA out of serviceThe present minimum and maximum fault levels have been provided for the purposes ofdetermining those relay settings that may require it. These fault levels reflect the system modelas it is presently. It does not include other IPPs under the current call or any future IPPs or largemotor loads.Ultimate Fault Levels (excluding contribution from the IPP)Fault Type Fault Level Units3-phase 1500 MVASingle line to ground 15 kA rms sym.The ultimate fault level may be used for basic station design such as bus strength, ground grid,and for any major equipment that the owner does not want to replace when the present faultlevel increases to the ultimate. No planned data exists for increasing this ultimate fault level.3.0 DESCRIPTION OF INTERCONNECTION FACILITIESThe interconnection facilities identified have been categorized as Direct Assignments (DA) orNetwork Upgrades (NU).DA facilities are those facilities or portions of facilities that are constructed by <strong>BC</strong>TC for the soleuse or sole benefit of the “IPP”. A test for a DA facility is any facility that will become a strandedasset if the “IPP” cancels their Interconnection and <strong>Facilities</strong> Agreements.NU facilities are for those modifications or additions to the transmission related facilities that areintegrated with and support <strong>BC</strong>TC’s over all <strong>Transmission</strong> System. The facilities are for thegeneral benefit of all ratepayers.IFS - R0 © British Columbia <strong>Transmission</strong> Corporation, 2007. All rights reserved. 3
<strong>Cranberry</strong> <strong>Creek</strong> Power ProjectInterconnection <strong>Facilities</strong> <strong>Study</strong> SPA 2007-018F3.1 Direct Assignments3.1.1 System Studies<strong>BC</strong>TC will provide <strong>Transmission</strong> Operational studies as a result of the interconnection of CRA.<strong>BC</strong>TC will perform studies as required to confirm that no poorly damped oscillations have beeninduced by the final exciter control scheme.3.1.2 Field CoordinatorField Coordinator duties associated with the commissioning of CRA to the <strong>Transmission</strong> Systemin accordance with System Operating Order 1T-35 will be provided. Refer to Section 13.1 of<strong>BC</strong>TC’s “69 kV to 500 kV Interconnection Requirements for Power Generators," datedDec-2006 for details.3.1.3 Illecillewaet Substation (ILL)3.1.3.1 StationNo station DA facilities or work are required.3.1.3.2 ProtectionReview and revise as necessary, 60L219 line and entrance protection settings anddocumentation.3.1.3.3 ControlNo control DA facilities or work are required.3.1.3.4 Control CentreNo control centre DA work is required.3.1.3.5 TelecommunicationsNo telecommunications DA work is required.3.1.3.6 <strong>Transmission</strong> LineNo transmission line DA facilities or work are required.3.1.4 Control CentresThe following work associated with the addition of CRA will be required at SCC and SIC:IFS - R0 © British Columbia <strong>Transmission</strong> Corporation, 2007. All rights reserved. 4
<strong>Cranberry</strong> <strong>Creek</strong> Power ProjectInterconnection <strong>Facilities</strong> <strong>Study</strong> SPA 2007-018F• SCC data base and display work and commissioning.• SIC display work and commissioning.• Configure Datalink at SCC and SIC.• Add a D20 port at SIC including interface to a new satellite communications processor.Details of the required CRA status and telemetry points are covered in the “ProjectInterconnection Requirements” report.3.2 Network Upgrades3.2.1 Control CentresThe following telecommunications facilities and work are required at SIC:• Provide and install a new Ethernet satellite communications processor at SIC to integratethe CRA SCADA.• Provide appropriate firewall and security configurations to connect the satellitecommunications processor to the satellite provider.4.0 IMPLEMENTATION AND SCHEDULEIf <strong>BC</strong>TC facilities work can proceed by 14-May-2007, <strong>BC</strong>TC will make reasonable efforts tocomplete the work and be ready for CRA synchronization and commissioning by 30-Jan-2009(the Energization Date).The implementation assumption used in the schedule development is that <strong>BC</strong>TC (and itscontractors) will perform all work associated with the protection, control centres andtelecommunications facilities.5.0 COST ESTIMATE FOR FACILITIESAll facilities identified for the connection have been categorized as either Direct Assignments(DA) or Network Upgrade (NU) facilities.DA costs are for those facilities or portions of facilities that are constructed by <strong>BC</strong>TC for the soleuse or sole benefit of the “IPP.” A test for a DA cost is any facility which will become a strandedasset if the “IPP” cancels the agreements.NU costs are for those modifications or additions to the transmission related facilities that areintegrated with and support <strong>BC</strong>TC’s over all <strong>Transmission</strong> System. The facilities are for thegeneral benefit of all ratepayers.The P50 cost estimate, with an accuracy of -10%, +20%, is summarized in the following tableand includes direct costs, contingency, inflation, overhead and interest during construction (onthe Network Upgrade portion).IFS - R0 © British Columbia <strong>Transmission</strong> Corporation, 2007. All rights reserved. 5
<strong>Cranberry</strong> <strong>Creek</strong> Power ProjectInterconnection <strong>Facilities</strong> <strong>Study</strong> SPA 2007-018FDA ($k)NU ($k)Project Management $23.1 $0.0Engineering $26.3 $16.4Procurement $2.3 $12.0Construction and Commissioning $19.8 $8.3Other Services $22.7 $0.0Contingency $14.1 $5.5Overhead $3.2 $1.3Interest During Construction $0.0 $1.0TOTAL $111.5 $44.55.1 Items Included in the Cost EstimateThe following items are included in the cost estimate:i. All salaries, wages, benefits, travel, subsistence and overhead costs for all <strong>BC</strong>TC personnelinvolved in designing, engineering, procuring, constructing, installing and commissioning theDA facilities and the NU facilities (the Work).ii. All amounts due to <strong>BC</strong>TC subcontractors carrying out any aspect of the Work.iii. The cost of all required material, supplies, equipment and tools.iv. Insurance costs and the costs of obtaining all required permits and tenure.5.2 Items Excluded from the Cost EstimateThe following items are not included in the cost estimate:i. Any costs associated with work for which the ”IPP” is responsible to complete, or arrange forits completion.ii. Any “loss of electricity” to other Load Customers that are interconnected to the <strong>Transmission</strong>System as a result of the possible line outages to interconnect.iii. The costs of revenue metering or other facilities and equipment <strong>BC</strong> <strong>Hydro</strong> may require the”IPP” to construct or install, or facilities that may be required in order to obtain servicesunder the Tariff.5.3 Conditional Items for the Cost EstimateThe cost estimate is conditional upon the following items:i. <strong>BC</strong>TC or <strong>BC</strong>TC’s contractors designing, engineering, procuring, constructing, installing andcommissioning the Work.ii. <strong>BC</strong>TC being given a reasonable period of time, as determined by <strong>BC</strong>TC acting reasonably,to complete the Work (the Construction Period).IFS - R0 © British Columbia <strong>Transmission</strong> Corporation, 2007. All rights reserved. 6
<strong>Cranberry</strong> <strong>Creek</strong> Power ProjectInterconnection <strong>Facilities</strong> <strong>Study</strong> SPA 2007-018Fiii. The Construction Period ending no later than the Energization Date based on the ProjectApproval Date.iv. Any major transmission line work forming part of the Work being undertaken during thespring-fall to take advantage of the available construction season.v. The ”IPP” furnishing to <strong>BC</strong>TC all relevant drawings, specifications and other informationreasonably necessary for <strong>BC</strong>TC to carry out the Work, by such dates as <strong>BC</strong>TC mayreasonably require, as determined by <strong>BC</strong>TC acting reasonably.vi. <strong>BC</strong>TC being able to work continuously during the Construction Period on the Work withoutinterference or delay caused by the ”IPP” or third parties (including without limitation labourdisputes affecting <strong>BC</strong>TC’s contractors).vii. The ”IPP” commissioning and energizing their facilities by the Energization Date incompliance with the Project Interconnection Requirements and Good Utility Practice.5.4 DisclaimerThe cost estimate covers the estimated cost for the scope of work. The estimated costs reflectcurrent trends and conditions anticipated by <strong>BC</strong>TC over the period of time reflected in theestimate.The accuracy of the estimate is dependent upon many factors, one of which is the level ofproject definition. This characteristic is based upon percent complete of project definition androughly corresponds to the percentage of final engineering. The level of project definitiondefines the maturity or the extent and types of input information available to the estimatingprocess.Another factor affecting the estimate is the accuracy of the assumptions made and associatedrisks. These risks include, but are not limited to the following:i. Volatility of commodity prices.ii. Currency fluctuations.iii. Availability and cost of labour.iv. Opportunistic tender pricing.v. Environmental risks.vi. Timely supply of major equipment and materials.vii. First Nations agreement.viii. The risk of:a. incorrect assessment of the value of required property rights and acquisitions; andb. delays necessitated to, or inability to, obtain required regulatory approvals.As a consequence of these risks, actual cost and schedule may differ materially from thoseestimated.The “IPP” is cautioned that the foregoing factors and risks are not exhaustive. Furthermore, theassumptions used in preparation of the estimate were made based on engineering judgementas of the date of the estimate. <strong>BC</strong>TC does not have any obligation to update, or to revise, any ofthe assumptions used, whether as a result of new information, future events, or otherwise,except as may be specifically requested, in writing, by the “IPP”.IFS - R0 © British Columbia <strong>Transmission</strong> Corporation, 2007. All rights reserved. 7
<strong>Cranberry</strong> <strong>Creek</strong> Power ProjectInterconnection <strong>Facilities</strong> <strong>Study</strong> SPA 2007-018FThis estimate has been prepared strictly for the use of the “IPP”. <strong>BC</strong>TC shall not be liable for,and accepts no liability whatsoever, in respect of any claims that may arise as a result of theuse of the estimate, whether in whole or in part, by any person, firm or corporation other thanthe “IPP” whether or not any such person, firm or corporation is an affiliate, consultant or agentof the “IPP”.IFS - R0 © British Columbia <strong>Transmission</strong> Corporation, 2007. All rights reserved. 8
<strong>Cranberry</strong> <strong>Creek</strong> Power ProjectInterconnection <strong>Facilities</strong> <strong>Study</strong> SPA 2007-018FAPPENDIX ADOCUMENTATIONIFS - R0 © British Columbia <strong>Transmission</strong> Corporation, 2007. All rights reserved. A1
<strong>Cranberry</strong> <strong>Creek</strong> Power ProjectInterconnection <strong>Facilities</strong> <strong>Study</strong> SPA 2007-018FAPPENDIX ADOCUMENTATIONThe following documentation is part of the project proposal submitted by the “IPP”. Subsequentrevisions or new documents may supersede some of these documents. In such cases the latestissue is the governing document.DocumentGenerator Interconnection Equipment Statement (GES)Generator, Exciter, Governor/Turbine DataReferenceRev 2 – 22-Aug-2006(not dated)System Single Line Drawing 100-01Location Plan Figure 1, Rev 1Project Layout Figure 2, Rev 0CFT06 Deficiency ResponseElite Engineering letterdated 19-Oct-2006IFS - R0 © British Columbia <strong>Transmission</strong> Corporation, 2007. All rights reserved. A2
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