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La Crosse 161 kV Capacitor Addition Northern MAPP Subregional Planning Group April 3, 2007 Daniel Kline.

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Presentation on theme: "La Crosse 161 kV Capacitor Addition Northern MAPP Subregional Planning Group April 3, 2007 Daniel Kline."— Presentation transcript:

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2 La Crosse 161 kV Capacitor Addition Northern MAPP Subregional Planning Group April 3, 2007 Daniel Kline

3 3 Outline  Area System Deficiencies  Planned Project  Next Steps

4 4 Area System Deficiencies  Summer 2008, at least 50 MVAR of capacitors are needed at La Crosse with Genoa 3 offline, French Island offline, and Alma – Marshland out  Must sustain 0.95 pu voltage at French Island 69 kV bus  French Island startup issues  In 2011, necessary capacitance increases to 110 MVAR

5 5 Area System Deficiencies  Capacitance also needed at Monroe County Substation  Outage of La Crosse – Monroe County 161 kV line causes low voltage at Monroe County in 2011.

6 6 Planned Project  Install two 60 MVAR capacitor banks at La Crosse Substation  Temporary solution until CapX line is in service  Will provide reliable source of power  Decrease reliance upon area 161 kV lines  Considering placing one of the banks at Monroe County Substation  161 kV tie strong enough to supply enough support to French Island  Would support Monroe County in case of outage of La Crosse – Monroe County 161 kV line

7 Wisconsin Study Update Eau Claire and New Richmond Northern MAPP Subregional Planning Group April 3, 2007 Daniel Kline

8 8 Outline  New Richmond Area  Various Load Serving Problems  Update on Progress Since Last Presentation  Eau Claire Area  Various Load Serving Problems  Update on Progress Since Last Presentation  Next Steps  Questions

9 New Richmond Area

10 10 Description of Area  Located in Western Wisconsin  St. Croix County  Just across Minnesota border, near I-94  Area fed by 161 kV sources and 69 kV subtransmission  Load belonging to NSPW and DPC  Lines belonging to NSPW and DPC

11 11 Description of Area  Two distinct load-serving areas  New Richmond  Somerset, Osceola  Load Growth:  Total load growth of over 30 MVA in 8 year period from 2008 to 2016  Bedroom communities for Twin Cities growth Load Area New Richmond45.4 MW53.1 MW63.7 MW DPC N MW52.0 MW63.1 MW Total91.4 MW105.1 MW126.8 MW

12 12 Sand Lake St. Croix Falls Apple River Bear Trap Griffin St. Clear Lake Lk. Camelia New Richmond Houlton Farmington Osceola Willow River Roberts Kinnickinnic Troy Rush River Pine Lake Crystal Cave Area System Deficiencies  New Richmond Voltage  Osceola Voltage  Autonomy of 69 kV lines from Pine Lake  Chisago – Apple River Construction

13 13 Description of Area

14 14 Description of Problems  Low voltage at New Richmond during outage of Pine Lake – New Richmond 69 kV line  Low voltage at Osceola during outage of Osceola – Osceola Tap 69 kV line  Overload of River Falls 115/69 kV transformer during outage of Osceola – Osceola Tap 69 kV line  Overload of Pine Lake 161/115 kV transformer during outage of King – Willow River 115 kV line  Normal Overload of Pine Lake – Rush River 69 kV line

15 15 Description of Problems  High load growth throughout area  Installation of Chisago Line Project will require extended outage of Osceola – Osceola Tap 69 kV line  No room for expansion at New Richmond Substation  No room for expansion at Rush River Substation

16 16 Project Plan  Multiple Independent Projects to work together  10 MVAR Cap Bank at New Richmond – Under Construction  Three Lakes Substation – June 2009  5.4 MVAR Cap Bank at Osceola – June 2009  Relocate Rush River Substation and cut over to 161 kV – June 2009  Rebuild Osceola to Sand Lake 69 kV Line – June 2009  Construct Somerset Sub – June 2010  Construct Stanton Sub – December 31, 2010  Construct Somerset to Stanton 69 kV Line – May 31, 2011  Complete installation of Chisago Line Project – May 31, 2011  Construct Poplar Lake Sub & 161/69 kV Transformer – May 31, 2011

17 17 Planned Projects  Three Lakes Substation  Planned Somerset Substation  Stanton 69 kV Switching Station  Somerset to Stanton 69 kV Line Sand Lake St. Croix Falls Apple River Bear Trap Griffin St. Clear Lake Lk. Camelia New Richmond Houlton Farmington Osceola Willow River Roberts Kinnickinnic Troy Rush River Pine Lake Crystal Cave Somerset Substation Stanton Substation Three Lakes Substation

18 18 Where Are We Now?  Projects have been through internal review process  Budget process for is underway  Anticipate permitting and material procurement underway in 2008  First stages of completion in 2009, finishing in 2010

19 19 Next Steps  Coordination work for Wisconsin CPCN filing  External coordination for necessary interconnections  Working with DPC to determine ownership model for Poplar Lake Substation

20 Eau Claire Area

21 21 Description of Area  Located in West-Central Wisconsin  Eau Claire & Chippewa Counties  About an hour east of Twin Cities on I-94  Area fed by 345 and 161 kV sources and 69 kV transmission  Load belonging to NSPW and DPC  Lines belonging to NSPW and DPC

22 22 Description of Area  Two distinct load-serving areas  Eau Claire  Chippewa Falls  Load Growth:  Total load growth of over 50 MVA in 8 year period from 2008 to 2016 Load Area Chippewa Falls84.9 MW88.2 MW91.5 MW94.9 MW98.2 MW Eau Claire232.0 MW240.6 MW250.1 MW259.5 MW269.3 MW Total316.9 MW328.8 MW341.6 MW354.4 MW367.5 MW

23 23 Description of Area Eau Claire Wheaton Jeffers Road DPC Elk Mound Seven Mile Hydro Lane Wissota

24 24 Description of Area

25 25 Description of Problems  Eau Claire transmission system is designed to rely upon Eau Claire 69 kV bus  Eau Claire 161/69 kV transformers are heavily loaded and cannot endure loss of parallel bank  Eau Claire substation is crowded and not enough space exists to increase the size of the existing 161/69 kV banks  Increasing size of banks would require moving to non-standard bank sizes

26 26 Description of Problems  During peak load conditions, 69 kV system to north overloads  DPC system served out of Seven Mile overloads for various contingencies  High load growth throughout area  Interconnection requests at Hallie Substation requrie auto-transfer scheme to be turned off  Area transmission system highly susceptible to fluctuations in Chippewa River generation

27 27 Final Recommendation  Re-terminate Wheaton to Presto Tap 161 kV line at Eau Claire Substation  Replace existing Eau Claire – Hydro Lane 69 kV double-circuit line with single-circuit 161 kV line  Construct 161/69 kV substation (50 th Avenue Substation) where double-circuit 69 kV line intersects Hydro Lane – Red Cedar 161 kV line  Construct single circuit 161 kV line from Eau Claire to 50 th Avenue Substation  Convert Hallie Substation to 161 kV operation  Construct second circuit from Wheaton Tap to Wheaton to avoid parallel three-terminal lines

28 28 Near-Term Plans  Eau Claire – Hydro Lane Conversion  DPC East Hallie Eau Claire Wheaton Jeffers Road DPC Elk Mound Seven Mile Hydro Lane Wissota

29 29 Where Are We Now?  Projects have been through internal review process  Budget process for is underway  Anticipate permitting and material procurement underway in 2008  First stages of completion in 2009, final project completion in 2011

30 30 Next Steps  Coordination work for Wisconsin CPCN filing  Working with DPC on long-term plan for Eau Claire Area – to begin summer 2007  Potential for one or two new 161/69 kV substations in Eau Claire area to provide additional voltage support and off-loading of Eau Claire Substation 69 kV bus

31 31 Initial Ideas  Options investigated with and without Chisago project  Necessity of Poplar Lake Substation and 161/69 kV transformer investigated

32 Questions?


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