InnPower Corporation Master System Plan

Transcription

1 InnPower Corporation METSCO Project January 29, 2018 Prepared By: Daryn Thompson P.Eng. COPYRIGHT InnPower Corporation ALL RIGHTS RESERVED This report may not be reproduced or copied, in whole or in part, in any printed, mechanical, electronic film, or other distribution and storage without written permission of InnPower Corporation.

2 DISCLAIMER This report was prepared by METSCO Energy Solutions Inc. (METSCO) for the sole benefit of InnPower Corporation - (the Client), in accordance with the terms of METSCO proposal and the Client s Purchase Order. Neither the Client nor METSCO, nor any other person acting on their behalf makes any warranty, expressed or implied, or assumes any legal responsibility for the accuracy of any information or for the completeness or usefulness of any apparatus, product or process disclosed, or accept liability for the use, or damages resulting from the use, thereof. Neither do they represent that their use would not infringe upon privately owned rights. Furthermore, the Client and METSCO HEREBY DISCLAIM ANY AND ALL WARRANTIES, EXPRESSED OR IMPLIED, INCLUDING THE WARRANTIES OF MERCHANTABILITY AND FITNESS FOR A PARTICULAR PURPOSE, WHETHER ARISING BY LAW, CUSTOM, OR CONDUCT, WITH RESPECT TO ANY OF THE INFORMATION CONTAINED IN THIS REPORT. In no event shall the Client or METSCO be liable for incidental or consequential damages because of use or any information contained in this report. METSCO Energy Solution Inc., 2018.

3 Contents 1 Executive Summery Definitions Planning Philosophy and Assumptions... 9 Load Forecast... 9 ICI land load calculation:... 9 Assumptions... 9 Level 1:... 9 Level 2: Existing System kv System kv North-East System Stroud DS Growth Environment at InnPower (Innisfil and Barrie) Overall System Reconfiguration Plan Level 1 System Plan Level 2 System Plan Budget Cost Assumptions, (Unit Costs) Transformer and Distribution Station per Unit Cost and HV overhead lines per Unit Cost are presented in Table 7 and Table 8 respectively Station construction Cost Feeders Construction Cost Project Cost System Options DS Single or Double Transformers TS Size and Location Version Date: March-12-18

4 Build-Out Cost Sharing and Load pays for Growth Philosophy Employment Lands Details, of projects and drawings Appendix... Error! Bookmark not defined. Version Date: March Page 4

5 1 Executive Summery This Plan is the interim status of a Master Planning project by InnPower Corporation in the Town of Innisfil and relating to the development activities projected over the next 30 or more years. While planning will ultimately cover the entire InnPower Service area, this plan is focussed on the areas of growth in the South Barrie Lands and the northern sections if Innisfil. InnPower has adopted a philosophy that Growth Pays for Growth which generally means that new developments will be responsible for the infrastructure to supply the new loads rather than burdening existing rater payers with the additional costs. The specifics of how these costs will be allocated are under review. The loads represented by this plan are significant and represent approximately 21,000 additional residential and small commercial customers for 74MVA of load, and 90MVA of Industrial/Commercial/Institutional(ICI) lands. An estimated $51.5 Million in new distribution and subtransmission assets will be needed to supply the new load including 50 km of overhead lines construction and 6 Distribution Stations (DSs). Approximately 87MVA of ICI load in an area known as the employment lands is under review for supply options by may include an additional 100MVA Transformer Station. The next level of planning will include details of Distribution and/or Transformer Stations as well routing of Distribution and Subtransmission feeders. Version Date: March Page 5

6 2 Definitions The following terms are referenced in this document Town of Innisfil: South Barrie Lands: includes the communities of Stroud, Alcona, Lefroy, Churchill, Cookstown, Gilford, Sandy Cove, and Big Bay Point. are those lands within the former boundaries of the Town of Innisfil of approximately 2,300 hectares granted the City of Barrie of land for development by The Barrie-Innisfil Boundary Adjustment Act, This land falls within InnPower s service territory. InnPower: InnPower Service Territory: is the Local Distribution Company (LDC) running the "wires" business in the Town of Innisfil & South Barrie, which distributes electricity to the homes, businesses and industries. Encompasses the lands of South Barrie and all of the Town of Innisfil, InnPower s service territory is depicted in Figure 1 Salem Land: Area shown in Figure 6 Hewitt Land: Area shown in Figure 5 Friday Harbour: Area shown in Figure 4 Residential Unit: Typically, a Single family dwelling or townhouse unit or condominium. Commercial Land: 77 VA/m 2 ICI (Industrial, Commercial and Institutional) Lands Transformer Station (TS) Distribution Station (DS) 61 VA/m 2 Transmission Grid connected substation, typically larger than 50MVA. In Ontario TS s can be owned by the LDC or Transmission Company. (Hydro One in this area) Subtransmission connected substation, typically 5 to 20MVA. DS s are owned by the Local Distribution Company (InnPower in this area) Version Date: March Page 6

7 InnPower Corporation Figure 1- InnPower s Service Territory Version Date: March Page 7

8 Figure 2- Map of Barrie/Innisfil Sub-region Version Date: March Page 8

9 3 Planning Philosophy and Assumptions Load Forecast Residential kw/unit ICI land load calculation: ICI Land Loads (calculated for each parcel): [ICI Land - Heritage Area] x 60% (coverage) x 61VA/m 2 +20% Contingency Example: County of Simcoe 29: ICI Land Size: ha Heritage Area: ICI Land Size x 0.5= ha Size of Parcel: ICI Land Size - Heritage Area = ha = m 2 60% of the Parcel= m 2 Loads: [ m 2 x 61 VA/m 2 = VA= 6.91 MVA] + 20% Contingency= 8.29 MVA Commercial growth assuming 77 VA/m 2 Industrial growth assuming 61 VA/m 2 Assumptions Level 1: Small Commercial units are fed from 27.6 kv feeders. ICI loads in Salem Land and Hewitt Land are fed from 44 kv. The limit to transfer a commercial load to 44 kv feeders is 1 MVA ICI Lands are estimated at MVA in addition to the Salem Land loads. Level 2: Maximum two 44 kv lines are considered on each pole. Generally, two 44 kv lines are considered on each road. 44kV line capacity is good for 440A, Max 33MVA At least 1 tie point is considered between feeders from Barrie TS and Alliston TS. Proposed twin TX for Bob Deugo (10 MVA) is connected to 9M1. Each transformer is 10 MVA and stations are either double or single transformer kv feeder capacity is 5MVA. Each 27.6 kv feeder is backed up. N-1 Contingency means loss of one DS transformer in the network. The 27.6 kv feeders external to the development areas are included in length calculations. Feeders inside subdivisions are the responsibility of the developer directly. A new Transmission Station with capacity of 100 MVA is considered to accommodate ICI Land loads. (note this could be entirely external to this cost sharing arrangement) Version Date: March Page 9

10 4 Existing System InnPower serves approximately 16,000 customers within a service area of 292 square kilometres. The Customer base is heavily skewed to Residential with some small Commercial. The InnPower 2015 System Peak occurred in the Winter at 52MW. InnPower receives its power from 44 kv subtransmission feeders, which deliver power to the twelve (12) distribution substations ( DS ) and large 44 kv customers. The 44 kv feeders are owned by InnPower within its service territory, except for the portions that feed Cookstown West DS and Thornton DS. The 44 kv feeders egress from three transformer stations ( TS ) owned by Hydro One Networks Inc. ( HONI ). Alliston TS and Everett TS step power down from 230 kv to 44 kv, while Barrie TS steps power down from 115 kv to 44 kv and is fed from kv autotransformers at Essa TS. There are three (3) DS owned by InnPower that step power down from 44 kv to 27.6/16.0 kv: Bob Deugo DS, Brian Wilson DS (which has two transformers that can be tied together), and the newly constructed Belle Ewart DS. The other nine (9) DS within InnPower s service territory step power down from 44 kv to 8.32/4.81 kv. Of these, seven (7) are owned by InnPower and two (2), Cookstown West DS and Thornton DS, are owned by HONI. InnPower s distribution system can be divided into five (5) clusters based on geography and connectivity. The 27.6 kv system includes Bob Deugo DS, Brian Wilson T1 and T2, and Belle Ewart DS. The 8.32 kv south-east system includes Innisfil DS, Lefroy DS, and Cedar Point DS. The 8.32 kv north-east system includes Leonard s Beach DS, Lefroy DS, and Big Bay Point DS. The 8.32 kv west system includes Cookstown West DS and Thornton DS. Finally, Stroud DS is analyzed on its own since it is far from the other clusters. Each of the clusters were analyzed based on the load forecast up to The cluster approach to capacity planning allows transformers to be loaded to 66% in the case of a three (3) transformer network, or 75% and 80% in the cases of four (4) and five (5) transformer networks, respectively. Traditional back to back station arrangements allow for only 50% loading of a transformer. The N-1 Contingency for a cluster of stations is determined by removing the largest transformer from the cluster and analyzing the cluster s ability to support the peak load with the remaining transformers. When the total load exceeds the N-1 Contingency there is a need for additional transformer capacity and when the load exceeds 80% of the N-1 Contingency there is a need to plan for additional transformer capacity. Feeders should be loaded up to a maximum of 50% of their recloser capacity in order to back up one another. For the purposes of this study the following clusters are considered: 27.6 kv System Stroud DS 8.32 kv North East System 27.6 kv System The 27.6 kv system includes Bob Deugo DS, Brian Wilson T1 and T2, and Belle Ewart DS. Each of these transformers except for Belle Ewart DS are forecast to reach 80% of their nominal rating in Version Date: March Page 10

11 The system is able to withstand an N-1 Contingency due to the extra capacity provided by Belle Ewart DS; however, in the current feeder configuration, Belle Ewart DS does not tie to Brian Wilson F1 or Brian Wilson F4. Brian Wilson F1 and Brian Wilson F3 both exceed 50% of their recloser ratings. A load transfer from Brian Wilson F3 to Brian Wilson F4 would be feasible but not necessary, since Brian Wilson F3 is backed up by Belle Ewart F2, which has a recloser setting of 350 A. Brian Wilson F1 is located away from the other 27.6 kv feeders, which would make any load transfer impractical kv North-East System The 8.32 kv north-east system includes Leonard s Beach DS, Lefroy DS, and Big Bay Point DS. In addition, Sandy Cove F1 can either tie to Stroud F2 or Stroud F3, of which Stroud F2 is the lighter loaded feeder. Big Bay Point DS is forecast to reach 80% of its nominal rating in 2016 and to exceed 100% of its nominal rating in This indicates additional transformer capacity is needed in the north-east in Five (5) additional feeders are required to distribute the load to the feeders nominal ratings, but this could be reduced to four (4) feeders if some load were transferred onto Stroud F2 (however, that would introduce new problems by making it more difficult to back up Stroud DS in case of a loss of a transformer). Note that two (2) feeders at 27.6 kv would be able to replace five (5) feeders at 8.32 kv. Stroud DS Stroud DS is analyzed on its own since it is far from the other clusters. Stroud F1 can tie to Lefroy F2, but Lefroy F2 already has over 3% voltage drop at maximum load. Stroud F2 and Stroud F3 can both tie to Sandy Cove F1, but Sandy Cove F1 is too heavily loaded to back up Stroud. There are difficulties backing up Stroud DS in case of a loss of transformer. Stroud DS can be backed up by tying Stroud F1 to Lefroy F2 (but this is a long 8.32 kv circuit and some load may need to be moved from Lefroy DS also) and moving load from Sandy Cove F1 onto Big Bay Point F2 to tie with Stroud F2 and F3. Stroud F1 is forecast to reach 75% of its recloser setting in 2019, but this load should be transferred onto a new substation constructed in the north-east of Innisfil. A feeder tie between Stroud F1 and Stroud F2 would allow Stroud F2 to back up Stroud F1 when the load is forecast to be high in 2018 and 2019 Version Date: March Page 11

12 5 Growth Environment at InnPower (Innisfil and Barrie) Load growth is the most prominent capital investment driver over the forecast period of this DSP. Following the Oak Ridges Moraine Protection Act, 2001, property developers have acquired parcels of land within the Town of Innisfil for the purpose of development. The projected population and employment growth within the Town of Innisfil vary between the official plans of the Town of Innisfil, the County of Simcoe, and the Province of Ontario; but all agree that the growth will be significant. A population increase of approximately 70% to 100% is expected from 2011 to The following major development plans will impact the InnPower System. 1. South Barrie 41,000 residents 2. Friday Harbour: 1,600 customers. 3. Five (5) commercial development sites located close to the Innisfil Beach Road interchange of Highway Lefroy area approximately 2,300 new customers. 5. Sleeping Lion (currently being built) estimated 5,000 residents around the existing Alcona area. Using growth projections from all available sources, the following comprises the parameters for long range growth projections: Town of Innisfil population in 2031: 56,000. South Barrie population in 2031: 40,788. Friday Harbour development: 1,600 units and commercial load. Version Date: March Page 12

13 6 Overall System Reconfiguration Plan The hand-off letter that resulted from the IRRP regarding the near-term wires solutions was provided to HONI by the IESO on 7 December 2015 and is attached as Appendix D. The recommendations of the hand-off letter are: to rebuild Barrie TS and the E3/4B transmission line and to upgrade the voltage of these facilities from 115 kv to 230 kv; to upgrade the transformers at Barrie TS from 55/92 MVA units to 75/125 MVA units; and to retire the two 230/115 kv autotransformers at Essa TS (T1 and T2). The Working Group for the Barrier/Innisfil sub-region is continuing to work on the development medium and long-term plans for the sub-region. These include: constructing a new TS (InnPower TS); constructing a new 230kV transmission line from Barrie TS to the InnPower TS site; implementing a Distribution Network egressing from InnPower TS; and Proposing a 44 kv solution for the load growth in South Barrie. The Working Group has identified South Barrie as a key load growth point. This area is serviced by both InnPower and PowerStream. The near-term solution would address the infrastructure requirements within the current DSP period; however, as the medium and long term plans consider the construction of new TS, Distribution Network, and transmission lines within InnPower s service territory the outcome of these plans would potentially play a major role in the DSP submitted by InnPower in the future. From 2019 to 2021, a 44 kv pole line rebuild and replacement project has been planned on 5 th Side Road between 5 th Line and IBR. This project will replace the old small conductor infrastructure and have an additional 44 kv circuit on to accommodate the new Alliston 9M6 feeder scheduled to reach InnPower within the next ten (10) years for load growth. In the near term a single 44kV feeder has been committed from the Barrie TS. Level 1 System Plan The figure below shows the InnPower Service area and highlights the lands under review in this study. Version Date: March Page 13

14 Figure 3- Level 1 System Plan Table 1 presents the load forecast for development lands in Annex land and Friday Harbour. Table 1- Development Lands Loads Forecast Version Date: March Page 14

15 Development Total Loads Annex Land and Friday Harbour Residential Units Loads MVA Units Small Commercial Commercial ICI 27.6 kv Feeders 44 kv Feeders Loads MVA Units/Parcels Loads MVA Salem Land (Parcels) Hewitt Land Friday Harbour Total The number of residential and commercial units and their estimated loads in each development are shown in Figure 4, Figure 5 and, Figure 6. Figure 4- Friday Harbour Version Date: March Page 15

16 Figure 5- Hewitt Land Figure 6- Salem Land Version Date: March Page 16

17 Level 2 System Plan Figure 7 below shows the proposed system for Annex land and Friday Harbour. Figure 7- Level 2 System Planning Version Date: March Page 17

18 Five distribution stations that step power down from 44 kv to 27.6/16.0 kv are proposed to feed the residential loads and commercial load of Friday harbour. DS A, DS B, Salem land DS and, Friday Harbour DS have nominal capacity of 20 MVA and Hewitt Land Ds has nominal capacity of 10 MVA. Second transformer with capacity of 10 MVA is considered in Bob Deugo DS. A transformer station of 100 MVA capacity is proposed to feed the commercial and ICI lands loads. Table 2 lists the proposed substation transformers, their respective 44 kv feeder with their length. For each transformer, the rating is given as nominal. The feeders supplied by each transformer are listed. Table 2- Proposed Distribution Stations and Transformer Station 44 kv Line Avail Cap. MVA Length (km) Stations TX Size MVA Feeders 13MX Proposed DS A 13MY MZ M1 (Extension) Proposed Salem Land DS Proposed DS B Proposed Hewitt Land DS 10 Proposed Friday Harbour DS Bob Deugo 2nd TX 10 13MW Commercial Owned TX s Transformer Station (TS) Total Added Station Capacity 100 F1 F2 F3 F4 F1 F2 F3 F4 F1 F2 F3 F4 F1 F2 F1 F2 F3 F4 F1 F2 Version Date: March Page 18

19 The nominal ratings of the transformers are summed to get the total added station capacity. Also nominal ratings of 44 kv lines are summed to get the total available capacity. Commercial loads in Salem land and Hewitt land are MVA and 2.5 MVA respectively (Table 1). Generally, these loads are fed from 44 kv lines. Total load of which includes residential loads and commercial load in Friday Harbour are fed from 27.6 kv feeders. Table 3 and Table 4 present Utilization factor and N -1 utilization Factor for stations and 44 kv feeders respectively. The N -1 Contingency is determined by removing the largest transformer and analyzing the system to support the load with the remaining transformers. Equation 1 presents the equation for this calculation. N N 1 Contingency = kva N Max(kVA) (1) i=0 Total Loads on 27.6 kv Feeders MVA Table 3- Stations Utilization Factor Total Station Added Utilization Capacity MVA Factor N -1 Utilization Factor % 82% Table 4-44 kv Feeders Utilization Factor Total Added Capacity MVA Total Loads MVA Utilization Factor N -1 Utilization Factor % 88% Table 5 presents the 44 kv lines. For the proposed system, 44 kv line considered to be either Singlecircuit with distribution underbuild (SSU) or Double-circuit with distribution underbuild (DSU). Table 5-44kV Lines 44 kv Line SSU DSU Existing Total Length (km) 13MY MX MZ M M MW M M Total Length (km) Version Date: March Page 19

20 Table 6 presents the 27.6 kv feeders between proposed distribution stations. Table kv Feeders between Proposed DS's Circuit Length 27.6 kv Feeder Configuration (km) BD to DS A DS A to SL SL to DS B DS B to FH FH to HL SS - - DS F F SS - - DS F F SS - - DS F F SS F DS F SS - - DS F2 4.3 Version Date: March Page 20

21 7 Budget Cost Assumptions, (Unit Costs) Transformer and Distribution Station per Unit Cost and HV overhead lines per Unit Cost are presented in Table 7 and Table 8 respectively. Station construction Cost *Estimate Table 7- Distribution Station per Unit Cost Station Cost Station Size Per Unit Cost Distribution Station 10 MVA 44/27.6 kv DS $2.2 M Distribution Station 20 MVA 44/27.6 kv DS $3.5 M 44 kv line considered to be either Single-circuit with distribution underbuild (SSU) or Double-circuit with distribution underbuild (DSU). 44kV lines typically have 50 meters spans. Feeders Construction Cost Table 8-44 kv Lines with Distribution Underbuild per Unit Cost Cost Per km based on 50m Cost Per Unit Line Voltage spans Pole SSU Pole DSU SSU DSU 44 kv 27.6 kv Underbuild $ 25,300 $37,375 $531,300 $784,875 The length and cost of the high voltage lines are presented in Table 10. Project Cost Table 10 and Table 11 present the construction cost for distribution stations and HV overhead lines... Table 9- Distribution Station Construction Cost Distribution Station Cost Station Size Per Unit Cost Number of Stations Cost 10 MVA 44/27.6 kv DS $2.2 M 2 $4.4 M 20 MVA 44/27.6 kv DS $3.5 M 4 $14 M Total Cost $18.4 M Version Date: March Page 21

22 Line Voltage 44 kv 27.6 kv Underbuild Table kv Lines with Distribution Underbuild Cost Total Length (km) Cost (M) SSU DSU SSU DSU SS DS SS DS Cost $15.8 M $17.24 M $33.04 M Project cost estimation has been calculated and represented in Table 11. Table 11- Total Cost Item Cost Distribution Stations $18.4 M 44 kv with 27.6 kv Underbuild $33.04 M Total Cost $51.44 M Version Date: March Page 22

23 8 System Options. The following system options should be considered when level 3 project estimating takes place. As of the current level of planning it is assumed that these options will have a minor impact on costs. DS Single or Double Transformers. Some of the stations have been planned as single transformer 10MVA sites and others as double transformer 20MVA sites. It is expected that land purchases and designs will accommodate double transformers at all sites. The decision to use single or double transformers can have a small impact on 27.6kV feeder lengths and backup opportunities. TS Size and Location The existing Barrie TS is the logical source for the initial 44kV feeder supply however there is insufficient capacity for all of the development plans for this area. As the load forecast for the Employment lands is approximately the load of another entire TS, the plan calls for a new TS to service those lands. Practically speaking an entire TS is a lot of supply for a Commercial Industrial area and there may end up being spare capacity. In addition, nearby DS s are being planned to supply local residential loads. A reasonable planning alternative may be to build a DS using a mobile transformer until the need for a TS is established and the site is built. All loads can be transferred to the TS, and the mobile station relocated to meet needs in other areas. if and when the TS becomes fully loaded, a permanent DS can be located at the original site. Build-Out This document does not contemplate the timing of construction. A reasonable build out plan would be to construct DS s at near term useful locations and run 27.6 kv Feeders through the service area to supply loads. As the loads increase, additional DS s can be built along the feeder routing to provide additional supply points. Effectively, a pair of 10MVA DS s can be interconnected with 4-5MVA feeders tied together in a back to back arrangement. At any time a new DS can be located at approximately the tie point and with the establishment of new open points 4 feeders can become 8. Version Date: March Page 23

24 9 Cost Sharing and Load pays for Growth Philosophy InnPower s System Access Philosophy is that Growth Pays for Growth. The specific cost sharing arrangements for this development area are under review. For the purposes of discussion, a calculation has been created based on the ratios of loads and units. Cost Sharing Table 12 presents the cost sharing estimations. For cost sharing estimation, the total costs are divide by a ratio of the units and loads in each development. The number of units and the loads are the total of the residential and small commercial units in the development. It is recommended to use the loads ratio, due to inconsistency of the number of commercial units. Development Units Unit % Table 12 Cost Sharing of Developments Cost based on Units Ratio ($M) Load MVA Load % Cost based on Loads Ratio ($M) Salem Land % $ % $ Hewitt Land % $ % $ Friday Harbour % $ % $ 9.57 Total % $ % $ Employment Lands This plan presumes the Employment Lands are part of the development. However, the use of these lands is still unclear, and the loads are expected to be very large. It may be reasonable to extract the Employment lands as both a cost and participant in this study. Version Date: March Page 24

25 10 Details, of projects and drawings Level 3 Project Information to follow in future phases of project planning. Version Date: March Page 25