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8-K - FORM 8-K - WESTAR ENERGY INC /KSd8k.htm
UBS Electric Power Conference 
March 3 & 4, 2010
Dallas, TX
Exhibit 99.1


2
Forward Looking Disclosures
The
following
presentation
contains
some
“forward-looking
statements”
with
respect to Westar Energy, Inc.’s (“Westar”) future plans, expectations and goals,
including management’s expectations with respect to future operating results
and dividend growth.  The Private Securities Litigation Reform Act of 1995 has
established that these statements qualify for safe harbors from liability.
Although
we
believe
that
the
expectations
and
goals
reflected
in
such
forward-
looking
statements are based on reasonable assumptions, all forward-looking
statements involve risk and uncertainty.  Therefore, actual results could vary
materially
from
what
we
expect.
Please
review
our
Annual
Report
Form
10-K
for the year ended December 31, 2009 for important risk factors that could
cause results to differ materially from those in any such forward-looking
statements.  Any forward-looking statement speaks only as of the date such
statement was made, and we do not undertake any obligation to update any
forward-looking statement to reflect events or circumstances after the date on
which such statement was made except as required by applicable laws or
regulations.


3
Recent Events
Ironwood  wind site acquired
Abbreviated rate case approved
Proposed settlement of EPA litigation
2010 transmission revenue update
2010 earnings guidance
New KCC commissioner appointed


4
Ironwood Wind Site
Acquired development rights for wind site
Preserves option of ownership or power purchase
Build out for own use
Allow 3
rd
party to develop, and WR acquires power via PPA
Site located near Spearville, KS
Contracts with landowners cover more than 18,600 acres
Able to support 500 MW of wind


5
Abbreviated Rate Case Approved
Filed abbreviated rate case June 2009
Address remaining Emporia and wind investments
Investment of
$97 million plus D&A and O&M
Stipulation and Agreement filed Dec. 1, 2009
Recommended $17.1 million annual revenue increase
Propose new rates reflect consolidated rates for most tariffs
New base rates approved January 2010
Implemented $17.1 million increase effective February


6
Proposed Settlement of EPA Litigation
Agreement with EPA to resolve New Source Review allegations at
the Jeffrey Energy Center
Install SCR on one unit by 2014
Lower plant-wide NOx emission limit established
Simpler plant modifications planned to achieve emissions target
If plant unable to meet emission target by 2012, then a second
SCR will be installed
Settlement awaiting the approval of federal court


7
2010 Transmission Revenue Update
October 2009 filed updated transmission formula rate
Resulted in
$16 million increase in revenue requirement
New transmission rates effective January 1, 2010
Component applicable to wholesale and other transmission
customers
$10 million
Companion retail component of transmission revenue
Filed updated Transmission Delivery Charge with KCC in February
Request $6.4 million revenue increase
Anticipate tariff update to be approved by mid-March


8
2010 Earnings Guidance of $1.65 to $1.80
No change in business strategy or direction
No change in regulatory principles or methods
Expected price adjustments:
Abbreviated rate case
Tracking adjustments
Weather
adjusted
retail
sales
grow
2%
O&M/SG&A increases 2-3%
Depreciation
increases
$20
million
AFUDC
equity
decreases
$4
million
COLI
proceeds
$11
million
Interest
charges
increases
$10
-
$15
million
Effective
tax
rate
of
29%
-
31%


9
Kansas Corporation Commission
Chairman Tom Wright reappointed to four-year term
Has served since 2007
New commissioner appointed
Ward Lloyd
25 years of public service
Served 8 years in Kansas House of Representatives
Served on House Utilities Committee among other committees


10
Introduction


11
Committed to being a pure-play, vertically integrated utility
Rate regulated based on cost of service
Key operational facts
About 7,100 MW of available generation  (48% coal, 8% nuclear, 40% gas, 4% wind)
7,800 miles of transmission
685,000 customers
Kansas’
Largest
Electric
Provider


12
In Our Favor
Coal
77%
Gas
7%
Wind
1.0%
Uranium
15%
0.0¢
1.0¢
2.0¢
3.0¢
4.0¢
5.0¢
6.0¢
7.0¢
8.0¢
9.0¢
10.0¢
Westar Energy
Kansas City Power and Light
(KS)
Empire District Electric (KS)
National
Average
6.9¢
7.8¢
8.5¢
$48.52
$16.79
$4.87
Uranium
Coal
Gas
Low Rates
Industrial
27%
Other
0.5%
Residential
34%
Commercial
38%
Diverse Retail Sales
High Quality, Diverse Generating Fleet
(TTM 12/31/09)
Ave. Fuel Cost
$17.18/MWh
0
100
200
300
400
500
600
700
800
900
1,000
2010
2011
2015
2019
0
100
200
300
400
500
600
700
800
900
1,000
2010
2011
2015
2019
Potential to renew
Potential to recapture
Wholesale Sales
Contract Portfolio
921
Source: Edison Electric Institute 06/30/2009


13
Major Industrial Sectors
36%
18%
17%
16%
13%
Chemical & oil
Food
processing
Aerospace
Consumer
manufacturing
Other
Commercial
38%
Residential
34%
Other
0.5%
Industrial
29%
Significant Industrial Sectors
Based on MWh sales


14
2009 Industrial Energy Sales
0
200
400
600
800
1,000
1,200
1,400
1,600
1,800
Q1
Q2
Q3
Q4
2009
2008
Budget
Down 11% from 2008
Hard hit sectors include chemical, aerospace and construction
Seeing positive trends in petroleum refining and animal science
(13.8%) to ‘08
(11.0%) to Bud
(9.5%) to ‘08
(10.9%) to Bud
(12.1%) to ‘08
(14.6%) to Bud
(7.5%) to ‘08
(12.3%) to Bud


15
2009 Residential and Commercial Energy
Sales
Residential down 1.4% from ‘08
Customer growth in line with historical
growth and budget
Prior to cool summer average use per
customer was ahead of plan and
equal to 2008 
Clearly the most weather sensitive
group
Commercial down 1.7% from ‘08
Customer growth in line with plan
Stability from state government,
military and higher education
Second most weather-sensitive group
0
500
1,000
1,500
2,000
2,500
Q1
Q2
Q3
Q4
(4.5%) to ‘08
4.8% to Bud
0
500
1,000
1,500
2,000
2,500
Q1
Q2
Q3
Q4
6.9% to ‘08
2.6% to Bud
(7.8%) to ‘08
(16.3%) to Bud
(3.2%) to ‘08
(2.2%) to Bud
0.8% to ‘08
1.1% to Bud
(2.7%) to ‘08
(12.5%) to Bud
2009
2008
Budget
2.7% to ‘08
1.5% to Bud
(1.9%) to ‘08
(0.4%) to Bud


16
Strategic Approach
Place a high value on flexibility
Create and preserve options and off ramps
e.g., CapEx plans with built-in flexibility—both to timing and approach
Avoid over committing to any single supply strategy
Leverage actions and strategies around unique attributes
Invest according to strengths, even if differently than the pack
Seek collaborative and constructive approaches to regulation
More predictability--less volatility
Ultimately lower prices for customers


17
Outlook for 2010


18
Service Territory Economy
Diverse customer base
Military
State government
Higher education
Manufacturing
Oil and gas
Agriculture and food processing
Chemicals
Kansas economy has slowed,
resulting primarily in weaker industrial
sales
However:
Receivables in arrears remain at about the
same level as last year
Kansas foreclosures about 1/3 of national
rate
State unemployment improving
2009 Unemployment
3%
4%
5%
6%
7%
8%
9%
10%
11%
Jan
Feb
Mar
Apr
May
Jun
Jul
Aug
Sep
Oct
Nov
Dec
Kansas
U. S.


19
Annualized Rate & Revenue Changes
Actual and Estimated
2009
2010
(Estimated)
2011
(Estimated)
Base rates
$130 million
Feb 3
$
17
million
late Jan
FERC transmission
$
4 million
Jan 1
$
10
million
Jan 1
$
6
million
Jan 1
State TDC
(transmission)
$
32 million
March 13
$
6
million
March
$
28
million
March
ECRR
$
32 million
June 1
$
15
million
June 1
$
18
million
June 1


20
Managing O&M and SG&A
O&M / SG&A increased at CAGR of 4% over last four years
Have reduced impact to by almost half by managing increases with
revenue offsets and deferred accounting treatment:
SPP transmission expense largely offset with transmission revenue
Amortization of deferred storm expenses included in rates
Additional O&M for new generation included in abbreviated rate case
Deferred accounting for increased pension expenses
Adjusted
CAGR 2.2%
$525
$575
$625
$675
$725
2005
2006
2007
2008
2009
2010 Est.


21
Current Capital Expenditure Forecast 2010 -
2012
Actual
Forecast
Forecast
Forecast
Forecast
2009
2010
2011
2012
2010-2012
Method of Cost Recovery
Generation
  Replacements and other
103.9
$    
99.9
$      
106.2
$   
126.6
$   
332.7
$   
General Rate Case (GRC)
  Additional Generation
     Emporia Energy Center
4.4
          
-
          
-
          
-
          
-
         
Predetermination/CWIP/ARC*
     Wind Energy
69.5
        
-
          
-
          
-
          
-
         
Predetermination/CWIP/ARC*
     Turbine upgrade - Wolf Creek
12.2
        
12.3
        
10.1
        
-
          
22.4
       
GRC
  Environmental
85.2
        
181.2
      
350.1
      
414.7
      
946.0
     
Environmental Cost Recovery Rider
Nuclear Fuel
19.8
        
36.1
        
26.7
        
26.1
        
88.9
       
Fuel adjustment clause
Transmission
156.6
      
203.6
      
167.8
      
175.1
      
546.5
     
FERC formula rate/TDC
Distribution
  New customers, replacements & other
92.7
        
102.3
      
114.6
      
118.6
      
335.5
     
GRC
  AMI / Smart grid
-
          
8.9
          
9.2
          
12.3
        
30.4
       
GRC
Other
11.5
        
20.3
        
16.0
        
25.3
        
61.6
       
GRC
Total
555.6
$    
664.6
$   
800.7
$   
898.7
$   
2,364.0
$
*Abbreviated rate case


22
Approximate Rate Base
$ 516
$ 470
Transmission rate base
$ 4,330
$ 4,103
Total
(Dollars in millions)
KCC Jurisdiction
100
-
Incentive rate base
(1)
$ 416
$ 470
Standard rate base
FERC Transmission
$ 3,814
$ 3,633
Estimated retail rate base
324
240
Incremental environmental
$ 3,490
$ 3,393
Standard rate base
Estimated
Dec. 31, 2009
Estimated
Dec. 31, 2008
(1) Incentive ROE of 12.3% on equity portion


23
Projected
Rate
Base
2009
2014
(in
billions)
$3.2
$3.4
$3.4
$3.5
$3.7
$3.9
2009
2010
2011
2012
2013
2014
Base
Renewable
Environmental
Transmission
$6.6
$6.3
$5.8
$5.2
$4.7
$4.3


24
Transmission


25
345kV Transmission System Additions
Wichita –
Salina
Segment 1 Wichita-Hutchinson
Completed December 2008
Investment
$100
million
Segment 2 Hutchinson-Salina
Under
construction
target
completion latter half 2010
Investment
$100
million
Rose Hill –
Oklahoma
Construction to follow the
Hutchinson-Salina line
Target completion mid year 2012
Investment
$90
million


26
Southwest Power Pool RTO
New Mexico
Oklahoma
Louisiana
Texas
Nebraska
Kansas
Arkansas
Missouri


27
Prairie Wind Transmission, LLC
Joint venture formed between Westar Energy and Electric
Transmission America
Venture to develop 765 kV transmission in Kansas
50% Westar / 50% ETA
ETA is joint venture between AEP Transmission Holding Company and
MEHC America
Transco,
LLC
(wholly-owned
subsidiary
of
MidAmerican
Energy
Holdings
Company)
Prairie Wind
Transmission, LLC
Westar 50%
Electric Transmission
America 50%
AEP 50%
MidAmerican 50%


28
Prairie Wind Transmission, LLC
Received FERC incentives
Abandonment costs
Recovery of pre-commercial development costs
CWIP recovery in rate base
Use of hypothetical capital structure of 50% debt and 50% equity
Allowed ROE of 12.8%
KCC
Approved Stipulation resolved dispute regarding construction of line
Routing and siting of line to follow SPP regional plans
Southwest Power Pool
Development of regional cost allocation tariff for “highway”
projects
under way


29
Prairie Wind Transmission LLC Part of the
Conceptual SPP EHV Overlay Plan
From the 2008 SPP Transmission Expansion Plan


30
Kansas EHV Agreement


31
Next Steps and Tentative Schedule
Inclusion in SPP regional plans
Region-wide rate authority
Obtain siting authority from KCC
Engineer and design
Acquire right-of-way
Construct


32
Financial Overview/Profile


33
Capitalization and Liquidity
Target
50/50
capital structure
Solid credit & liquidity position
Investment grade ratings
$730 million revolver
Minimal refunding obligations
No maturities until 2014
Dec 31, 2009
(millions)
Long-term, net
$2,492
Preferred
21
Common
2,245
Total Capitalization
$4,758
Debt
52%
Equity
47%
Preferred
<1%
Secured
Unsecured
Outlook
Moody's
(1)
Baa1
Baa3
Stable
Fitch Ratings
BBB+
BBB
Stable
Standard & Poor's
BBB
BBB-
Positive
(1)  Moody’s upgraded secured rating August 3, 2009


34
$0.92
$1.00
$1.08
$1.16
$1.20
$1.24
$0.75
$0.85
$0.95
$1.05
$1.15
$1.25
$1.35
2005
2006
2007
2008
2009
2010
Dividend
Long-standing dividend payout target of 60%-75% of earnings
Dividend payout 69%-75% based on 2010 guidance
Indicated
annual rate


35
Westar Remains Well-Positioned for Targeted
Shareholder Base
Stable, experienced utility management team
Thoughtful, flexible approach to capital planning and financing
Maintaining control of our business
Diverse customer base and stable service territory
Focus on containing risks and maintaining returns
Collaborative and constructive approach to regulation and
energy policy


Rates & Regulation
36


37
Regulatory Approach
A sound regulatory and energy policy platform
Stable, more predictable
Collaborative, constructive approach
Timely
Benefits for customers:
Minimize rate volatility
Time
Traditional GRC
Riders coupled with GRC
Ultimately,
lower rates


38
Methods of Cost Recovery for Westar
Smoothes period expenses for
extraordinary storm restoration costs
Traditionally deferred accounting
treatment as rate base
Extraordinary storm damages
6.
Smoothes period expenses in
excess of amount in base rates
Deferred as a regulatory asset for
subsequent recovery
Pension expenses
7.
Smoothes period expenses for
energy efficiency programs
Deferred as a regulatory asset for
subsequent recovery
Energy efficiency programs
8.
Allows timely recovery of actual
property tax costs in current rates
Annual adjustment to reflect current
property taxes
Property taxes
5.
Typical rate case reflects current
level of operating expenses and
most recent plant investment
Traditional rate case, but improved
through predetermination and CWIP
statutes
General capital investments
4.
Timely recovery of transmission
system operating and capital costs
FERC formula rate adjusts annually;
companion retail tariff to reflect
current revenue requirement
Transmission rate recovery
3.
Allows annual price adjustment to
reflect capital costs for investments
in emission controls
Environmental Cost Recovery Rider
adjusts annually
Environmental capital
2.
Adjusts prices for actual costs,
protecting both customers and
investors from mispricing
Quarterly adjustment based on
forecasted cost, with annual true-up
Fuel, purchased power and
environmental consumables
1.
Comment
Method of Recovery
Revenue Requirement


39
Retail Energy Cost Adjustment (RECA)
Provides timely price adjustments for fuel and purchased power
costs
Retail rates based on forecast of fuel and purchased power costs
and retail sales
Set quarterly
Difference between forecast and actual is accrued/deferred
Quarterly approach produces more stable prices
Annual settlement of accrued/deferred balance
RECA also used to rebate wholesale margins as a credit to retail
cost of service
Beginning March 2009, credits match actual results
Energy Marketing (i.e., non-asset) margins continue to be excluded from
rate setting


40
Environmental Cost Recovery Rider
Mechanics
ECRR adjusts retail rates annually to reflect capital costs for
emission controls
Investment at December 31 begins recovery in rates following June
Eliminates need to file a rate case to capture rate base additions
Return of
and on
capital that is in service December 31
Return on
capital not yet placed in service December 31 (i.e., CWIP)
ECRR speeds recovery of investments in emission control
equipment
Regulatory lag limited to months, rather than longer lag typically
associated with traditional rate case filings


41
Illustrative ECRR Mechanics
(1)
Illustration reflects only the projects publicly announced and assumes one-half of annual investment in service at year end
(2)
Illustration
uses
12%
pretax
return
and
4%
depreciation
recovery
(3)
Annual ECRR Tariff is effective June 1; assume Jan-May at prior year revenue requirement and Jun-Dec at new revenue requirement
Clean Air Investment (1)
2008
2009
2010
2011
2012
Year 1 Investment
238.4
$   
Year 2 Investment
85.2
$    
Year 3 Investment
181.2
$   
Year 4 Investment
350.1
$   
Year 5 Investment
414.7
$    
Environmental Investment
238.4
$   
323.6
$   
504.8
$   
854.9
$   
1,269.6
$  
Accumulated Depreciation Clean Air Investment
Depreciation on Year 1 Investment
4.8
$      
9.5
$      
9.5
$      
9.5
$      
9.5
$        
Depreciation on Year 2 Investment
1.7
3.4
3.4
3.4
Depreciation on Year 3 Investment
3.6
7.2
7.2
Depreciation on Year 4 Investment
7.0
14.0
Depreciation on Year 5 Investment
8.3
Annual Depreciation
4.8
$      
11.2
$    
16.6
$    
27.2
$    
42.5
$      
Total Accum
Depreciation for Environmental Investment
4.8
$      
16.0
$    
32.6
$    
59.8
$    
102.3
$    
Environmental Investment, net of Accum. Depreciation
233.6
$   
307.6
$   
472.2
$   
795.1
$   
1,167.3
$  
Return on
prior YE investment balance (2)
28.0
$    
36.9
$    
56.7
$    
95.4
$      
Return of
prior YE investments completed
4.8
11.2
16.6
27.2
Annual ECRR Revenue Requirement
32.8
$    
48.2
$    
73.2
$    
122.6
$    
Estimated calendar year revenue recognition (3)
19.1
$    
41.8
$    
49.1
$    
95.6
$      
Cumulative ECRR revenue recognition
19.1
$    
60.9
$    
110.0
$   
205.6
$    


42
Transmission Cost Recovery
FERC formula transmission rate
Changes in cost of service reflected in annual update of FERC tariff
Update posted each October using projected test year
Forecasted capital expenditures
Forecasted O&M
Tariff is based on year-end consolidated capital structure
FERC transmission changes effective January 1
Allowed ROE 11.3%
Annual true-up compares projected revenue requirement to actual, with
difference incorporated into next update
Incentives on Wichita to Salina transmission line
12.3% ROE is 100 basis points above base FERC-authorized ROE
Accelerated book depreciation of 15 vs. 45 years
Transmission Delivery Charge (TDC)
Retail rates adjusted to match changes to FERC tariff


43
Transmission Formula Rate Mechanics
Fixed formula with changing inputs
Updated annually using Form 1 data
Established protocols for updates
Uses projected test year
Rate base (based on 13 mo. Avg.)
O&M, depreciation and taxes
Cost of debt
Annual true-up
incorporated in subsequent year’s formula inputs
Establish
Proj. 2010
Rev.  Req.
Establish
Proj. 2011
Rev. Req.
Start of 2011
Rate Year
Start of 2010
Rate Year
FERC
Form 1
Released
True-up between ’09
Proj. Rev. Req. and
Actual Rev. Req.
Transmission Formula Rate Time Line


44
Statutes for Predetermination and CWIP
Predetermination
Utilities can obtain order establishing ratemaking principles that will
apply over the life of the asset
Construction Work in Progress (CWIP)
Utilities can include CWIP in rate cases


45
Pension Tracker
Defer on balance sheet differences between funding of GAAP
pension/OPEB expense and pension/OPEB currently authorized
in rates
Maintain minimum funding level equal to GAAP pension/OPEB
expense
Recover deferrals over period up to 5 years at time of future rate
case


46
Energy Efficiency Initiatives
Selected by DOE to begin negotiations for smart grid
implementation in Lawrence, Kansas
Installation of about 48,000 “smart”
meters
Total
project
cost
of
$40
million
Eligible for 50% match
To be implemented over 2 to 3 years
Regulatory orders may allow deferral of costs for energy efficiency
initiatives, such as
Smart thermostats
Customer educational programs
Demand response programs


47
Kansas’
Comprehensive
Energy
Bill
Passed
Renewable Portfolio Standard established
Installed capability standard in lieu of energy standard
10%
of
peak
load
by
2011,
15%
by
2016
and
20%
after
2020
Implies additional 150 to 200 MW for Westar
If generated in Kansas, treated at 110% of requirement
Limited net metering approved (up to 1% of peak demand)
Environmental predictability
Legislation precludes state air emission levels from being more
stringent than federal standards
Supplemental note to HB 2369: http://www.kslegislature.org/supplemental/2010/SN2369.pdf
Link to full text of bill: http://www.kslegislature.org/bills/2010/2369.pdf


48
Capital Structure for Ratemaking (Per Recent
Orders)
12.00%
8.50%
100.00%
8.77
5.29
10.40
50.83
Common
.04
.02
4.55
0.51
Preferred
3.19%
3.19%
6.55%
48.66%
Long-term debt
Pre-tax Weighted
Cost of Capital
Weighted Cost
of Capital
Cost of
Capital
Capitalization
Ratio
11.76%
8.18%
100.00%
8.99
5.43
11.30
48.07
Common
.04
.02
4.52
0.47
Preferred
2.73%
2.73%
5.30%
51.46%
Long-term debt
Pre-tax Weighted
Cost of Capital
Weighted Cost of
Capital
Cost of
Capital
Capitalization
Ratio
KCC
FERC Transmission
(1) Incentive ROE of 12.3% for applicable rate base
(1)


49
Background


50
Westar Energy Legal Structure
Kansas Gas and
Electric Company
Consolidated capital
structure is used for
ratemaking
(Rate regulated utility)
(Rate regulated utility)
Westar Energy, Inc.
Parent
Subsidiary
Combined company
does business under
the name “Westar
Energy”


51
Management and Organization Structure
Executive Management
President & CEO, Bill Moore
EVP & COO, Doug Sterbenz
EVP & CFO, Mark Ruelle
EVP, Public Affairs / Consumer
Services, Jim Ludwig
Officers average 23+ years
utility experience, largely with
Westar
Independent Board of Directors
Non-executive chairman
All directors other than CEO
are independent
Board of Directors       
Bill Moore
President and CEO
Mark Ruelle
Exec. VP, Chief
Financial Officer
Doug Sterbenz
Exec. VP, Chief
Operating Officer
Jim Ludwig
Exec. VP, Public
Affairs and
Consumer Services
Mike Lennen
VP, Regulatory
Affairs
Larry Irick
VP, General
Counsel and
Corp. Secretary
Greg Greenwood
VP, Generation
Construction
Tony Somma
Treasurer
Lee Wages
VP, Controller
Bruce Akin
VP, Operations
Strategy and
Support
Kelly
Harrison
VP,Transmission
Ops
&
Environmental
Services
Ken Johnson
VP, Generation
Caroline Williams
VP, Distribution
Power Delivery
Peggy Loyd
VP, Customer Care
Jeff Beasley
VP, Corporate
Compliance
and
Internal
Audit
Audit Committee


52
Wholesale Sales
Market-based sales (asset-based margins)
Opportunistic sales using as available
capacity
Real time up to 1 year
Margins reflected as credit to RECA
Tariff-based sales
Long-term agreements
Cost-based tariffs
Primarily with coops, municipals and participation
agreements with other utilities
Reflected as credit to base retail rates
Energy marketing (non-asset margins)
50% real-time to next day;
20% few
days to a few months
Energy transactions unrelated to our
generating assets
Market pricing
Financial and physical trading sourced
outside our control area
30%
Energy
management
managing
load and resources for others
Not reflected in rates


53
Westar’s Plants
Westar Energy
2008 Results
NERC
5-Year Average
Plant Performance
83.4%
82.2%
82.7%
89.3%
87.0%
90.1%
73.7%
73.7%
0%
20%
40%
60%
80%
100%
Coal Capacity
Factor
Wolf Creek
Capacity Factor
Coal Availability
Factor
Wolf Creek
Availability
Factor
Westar's
MW
Operator
Years Installed
Pulverized coal
Jeffrey Energy Center
1,991.0
Westar
1978, 1980, 1983
Lawrence Energy Center
529.0
Westar
1954, 1960, 1971
Tecumseh Energy Center
202.0
Westar
1957, 1962
LaCygne
Station
709.0
KCPL
1973, 1977
Nuclear
Wolf Creek
545.0
WCNOC (1)
1985
Gas steam turbine
Gordon Evans Energy Center
537.0
Westar
1961, 1967
Hutchinson Energy Center
162.0
Westar
1965
Murray Gill Energy Center
293.0
Westar
1952, 1954, 1956, 1959
Neosho Energy Center
67.0
Westar
1954
Gas combustion turbine
Abilene Energy Center
64.0
Westar
1973
Gordon Evans Energy Center
295.0
Westar
2000, 2001
Hutchinson Energy Center
230.0
Westar
1974, 1975
Spring Creek Energy Center
278.0
Westar
2001
Tecumseh Energy Center
37.0
Westar
1972
Emporia Energy Center
663.0
Westar
2008, 2009
Gas combined cycle
State Line
199.0
EDE Co.
2001
Diesel
Gordon Evans Energy Center
3.0
Westar
1969
Hutchinson Energy Center
3.0
Westar
1983
Wind
Meridian Way
96.0
Horizon (2)
2008
Central Plains
99.0
Westar
2009
Flat Ridge
100.0
Westar (3)
2009
Available generation
At Dec. 31, 2009
7,102.0
(1)
Wolf Creek Nuclear Operating Company is a company formed specifically to operate Wolf Creek
for its owners.  WCNOC is governed by a board of directors consisting of the CEO of WCNOC
and senior executives of the plant owners.
(2)
100% of generation purchased under Power Purchase Agreement (PPA)
(3)
50% owned and 50% of generation purchased under PPA from BP Alternative Energy


54
Westar-operated plant supply (80%)
JEC supply under contract through 2020 (10+ million tons/year)
70% has no market openers
30% reopened on price every 5 years
Next re-pricing will occur in 2013
All volumes have cost escalators
Rail contract through 2013
LEC/TEC supply under contract until 2010 (3.5 million tons/year)
100% at fixed price or capped through 2012
Additional supply being negotiated for future years
Rail contract through 2013
Co-owned plant supply managed by GXP (20%)
LAC supply (3 million tons/year)
Coal Supply


55
Wolf Creek Generating Station
Commercial operation in September 1985
1166 MW Westinghouse PWR
Co-owners
Westar Energy –
47% (548 MW)
Great Plains Energy –
47%
KEPCo –
6%
Operated by Wolf Creek Nuclear Operating Corporation
Separate and dedicated operating company
Owned and governed by plant’s co-owners
Current operating license until 2045
Received 20-year license extension in November 2008
Operates on 18-month refuel cycle
No refuel and maintenance outage planned for 2010


56
Future Wind Resources
Kansas
statute
requires
additional
150
-
200
MW
by
end
of
2011
Currently in discussions with short list of providers
Expect to firm up plans by year end
Can include either PPAs, ownership or both