La Crosse 161 kV
Capacitor Addition
Northern MAPP Subregional
Planning Group
April 3, 2007
Daniel Kline
Outline
Area System Deficiencies
Planned Project
Next Steps
3
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
4
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.
5
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
6
Wisconsin Study
Update
Eau Claire and New Richmond
Northern MAPP Subregional
Planning Group
April 3, 2007
Daniel Kline
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
8
New Richmond Area
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
10
Description of Area
Two distinct load-serving areas
 New Richmond
 Somerset, Osceola
Load Growth:
Load Area
2008
2011
2016
New Richmond
45.4 MW
53.1 MW
63.7 MW
DPC N-60
46.0 MW
52.0 MW
63.1 MW
Total
91.4 MW
105.1 MW
126.8 MW
Total load growth of over 30 MVA in 8 year period
from 2008 to 2016
Bedroom communities for Twin Cities growth
11
Area System Deficiencies
St. Croix Falls
Apple River
New Richmond
Sand Lake
Voltage
Osceola Voltage
Autonomy of 69
kV lines from
Pine Lake
Chisago –
Apple River
Construction
Lk. Camelia
Bear Trap
Griffin St.
Osceola
Farmington
Clear Lake
New Richmond
Houlton
Roberts
Willow River
Pine Lake
Kinnickinnic
Rush River
Troy
Crystal Cave
12
Description of Area
13
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
14
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
15
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 –
16
May 31, 2011
Planned Projects
St. Croix Falls
Apple River
Three Lakes
Substation
Planned Somerset
Substation
Stanton 69 kV
Switching Station
Somerset to
Stanton 69 kV
Line
Sand Lake
Lk. Camelia
Bear Trap
Griffin St.
Osceola
Farmington
Somerset
Substation
Clear Lake
Stanton
Substation
New Richmond
Three Lakes
Substation
Houlton
Roberts
Willow River
Pine Lake
Kinnickinnic
Rush River
Troy
Crystal Cave
17
Where Are We Now?
Projects have been through internal review
process
Budget process for 2008-2012 is underway
Anticipate permitting and material
procurement underway in 2008
First stages of completion in 2009,
finishing in 2010
18
Next Steps
Coordination work for Wisconsin CPCN
filing
External coordination for necessary
interconnections
Working with DPC to determine ownership
model for Poplar Lake Substation
19
Eau Claire Area
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
21
Description of Area
Two distinct load-serving areas
 Eau Claire
 Chippewa Falls
Load Growth:
Load Area
2008
2010
2012
2014
2016
Chippewa Falls
84.9 MW
88.2 MW
91.5 MW
94.9 MW
98.2 MW
Eau Claire
232.0 MW
240.6 MW
250.1 MW
259.5 MW
269.3 MW
Total
316.9 MW
328.8 MW
341.6 MW
354.4 MW
367.5 MW
Total load growth of over 50 MVA in 8 year period
from 2008 to 2016
22
Description of Area
Hydro Lane
Wissota
DPC
Elk Mound
Wheaton
Jeffers
Road
Eau Claire
Seven Mile
23
Description of Area
DPC Barron
To NSPW Jim Falls
NSPW Chippewa
Falls
NSPW Wissota
To NSPW Red
Cedar
DPC Elk Mound
NSPW Hydro Lane
To NSPW TCorners
NSPW Wheaton
To NSPW Red
Cedar
NSPW Hallie
NSPW Jeffers
Road
To Xcel Jim Falls
Presto
To NSPW King
To WPL Arpin
NSPW
Eau Claire
To DPC Alma
DPC Seymour
NSPW Truax
NSPW Dells
NSPW Madison
Street
NSPW Sterling
DPC Ludington
NSPW Otter Creek
NSPW US Rubber
NSPW
Seven
Mile
DPC Union
NSPW Shawtown
To NSPW Red
Wing
& DPC Alma
NSPW Ellis
DPC Elco
To NSPW Cotton
School
NSPW London
NSPW Tremval
DPC Brunswick
DPC Washington
DPC Equity
24
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
25
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
26
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 (50th 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 50th Avenue Substation
Convert Hallie Substation to 161 kV operation
Construct second circuit from Wheaton Tap to
Wheaton to avoid parallel three-terminal lines
27
Near-Term Plans
Hydro Lane
Wissota
Eau Claire –
Hydro Lane
Conversion
DPC East
Hallie
DPC
Elk Mound
Wheaton
Jeffers
Road
Eau Claire
Seven Mile
28
Where Are We Now?
Projects have been through internal review
process
Budget process for 2008-2012 is underway
Anticipate permitting and material
procurement underway in 2008
First stages of completion in 2009, final
project completion in 2011
29
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
30
Initial Ideas
Options investigated with and without
Chisago project
Necessity of Poplar Lake Substation and
161/69 kV transformer investigated
31
Questions?