1. Southwest Power Pool ITP-20 Generating Resources May 25, 2010

2. February 10, 2010B&V - 2 Agenda Study Purpose and Scope Study Approach Resources Considered Base Case Results Questions

3. February 10, 2010B&V - 3 Study Purpose and Work Scope Phase I. Develop resource plans for each of four future scenarios, as defined by the SPP System Planning Committee, to be used in the ITP Year 20 EHV analysis. The resources will be selected using an optimal generation expansion model, Strategist, configured to provide resource planning solutions on a regional basis. The resource list will be generic prototype generators representing available future resources. Phase II. Spatially located the new resources within SPP with the aid of GIS databases showing locations of transmission lines, natural gas pipelines, railroads, waterways, substations, etc. Phase III. The new generators will be entered into a PowerBase database and connected to buses in the transmission system. The information entered into the PowerBase will be used by SPP in future studies.

4. February 10, 2010B&V - 4 Study Approach

5. February 10, 2010B&V - 5 Review of Study Approach  Used Powerbase data model provided by SPP.  Developed capital cost and performance estimates for future candidate units.  Developed Annual Levelized Fixed Charge Rates to apply to capital cost estimated to account for financing costs, insurance, taxes, etc  Updated data model based on feedback from stakeholders.  Developed renewable energy build-out scenario.  SPP footprint divided into two areas due to model limits.  Developed least cost generation expansion using Ventyx Strategist.

6. February 10, 2010B&V - 6 Topology Review SPP footprint broken down into two sub-regions because of Strategist dimension limits. Initial attempt was to model the entire SPP in one model with 2 zones. But, encountered Strategist dimension limit. SPP footprint modeled using two separate Strategist models for 2 sub-regions: SPP North (SPPN) and SPP South (SPPS) Approximate dividing line – Kansas-Oklahoma State line 200 MW of capacity flow from SPPS to SPPN was allowed until SPPS was not excess on capacity to meet their own load and reserve requirements.

7. February 10, 2010B&V - 7 SPP North (SPPN) Control Areas Greater Missouri Operations Company. Independence Power and Light Kansas City BPU KCP&L Westar Energy Sunflower Electric Power Corp. Lincoln Electric System NPPD OPPD City Utilities of Springfield, MO Empire District Electric Company. MKE MWE

8. February 10, 2010B&V - 8 SPP South (SPPS) Control Areas AEP West OG&E Western Farmers Electric Co-operative Southwestern Public Service Company Central Louisiana Electric Company City of Lafayette Louisiana Energy and Power Authority GRDA Southwestern Power Administration

9. February 10, 2010B&V - 9 Economic Inputs – Development of Fixed Charge Rate  Used a proprietary Black & Veatch model for development of FCR  Fixed Charge Rate (FCR) is used to estimate the annual capital carrying cost for new plants and for new capital improvements done on existing plants.  A levelized fixed charge rate is a single, uniform rate that is applied to a unit’s total installed capital cost to yield the revenue requirements needed to recover cost on a present value basis. FCR varies depending upon various economic and financial assumptions.  Black & Veatch model develops different FCR for IOU, and Municipal and Cooperative (M&C) utilities.  Blended FCR calculated for SPP to account for different types of LSE in SPP. Assumed an 80/20 mix of generating resources additions by IOUs/M&C.  Technology dependent unit lives were assumed for FCR calculations: peaking (20 years), combined cycle (25 years), coal/nuclear (30 Years), and wind (5 year tax life, assumes not M&C financed).

10. February 10, 2010B&V - 10 Fixed Charge Rate Assumptions for IOU Assumptions for Municipalities and Cooperatives D/E ratio of 55:45 7 percent cost of debt and 12 percent cost of equity 39 percent effective tax rate and 0.5 percent adder for insurance and property taxes 20 tax life 20 year FCR – 13.83 % 25 year FCR – 12.74 % Fully debt financed and tax exempted 5.5 percent bond financing rate 0.5 percent adder for insurance and property taxes 20 year debt life FCR – 8.87 % 25 year debt life FCR – 7.96 % Blended 20 year FCR and 25 year book life FCRs for SPP is 12.84% and 11.79% respectively.

11. February 10, 2010B&V - 11 Additional FCR Calculations  Calculated a single FCR for renewable resources assuming 5 year tax life and 20 year book life.  Assumed all investors are taxable due to preferential depreciation status  11.53%  Calculated a blended FCR for coal and nuclear resources assuming 20 year tax life and 30 year book life.  11.51% TechnologyTax Life (years) Book Life (years) Blended FCR (%) Combustion Turbine 20 12.84 Combined Cycle 202511.79 Coal and Nuclear 203011.51 Wind52011.53 (not blended)

12. February 10, 2010B&V - 12 Generating Resources Considered

13. February 10, 2010B&V - 13 Cost & Operating Assumptions for Conventional Alternatives

14. February 10, 2010B&V - 14 Different Conventional Prototypes Modeled in Strategist 2x1 Generic Combined Cycle with maximum capacity of about 600 MW 800 MW Supercritical Pulverized Coal Unit without CCS 1100 MW Nuclear Unit Baseload Resources Generic frame CT with maximum capacity of about 200 MW Peaking Resources In addition, wind resources for meeting RPS requirements were added.

15. February 10, 2010B&V - 15 Addition of Wind Resources Wind Resource addition based on the Futures for Integrated Transmission Planning Process year 20 Assessment, Revision 3. Business as Usual (Base case) wind additions assumes no RES requirements (as per Appendix 1 of the aforementioned document) 42,000 GWh of renewable generation is achieved by 2020 for the whole SPP area At 40 percent capacity factor, this equates to about 11.9 GW of nameplate capacity Capacity value (Firm Capacity) of wind resources is assumed to be 5 percent of the name plate capacity. Wind resources capital cost assumed to be $2,150/kw (2010 dollars) Operating costs of wind resources assumed to be $51/kw-year. All new wind resources to meet RPS are expected to be online by 2020.

16. February 10, 2010B&V - 16 Wind Resources (Total New plus Existing) by Year

17. February 10, 2010B&V - 17 Other Key Assumptions Model run for 20 years (2011-2030, inclusive) No potential CO 2 taxes considered for the base case Coal PRB price forecast – No change to Ventyx forecast. NG price forecast – HH forecast from Ventyx. Basis differentials updated base on SPP stakeholder feedback. Uranium prices – Ventyx forecast updated based on stakeholder feedback. Units are allowed to be added in intervals of 2/3 years, with the intervals increasing from 2 years to 4 years as we move further out into the study period. 200 MW of capacity is allowed to flow from SPPS to SPPN from 2010- 2022 as SPPS has excess capacity at this time.

18. February 10, 2010B&V - 18 EWITS and WWSIS data Mesoscale modeled data Modeled years are 2004, 2005, 2006 Used year 2005 profile because that year was judged as the best representative year. 10 minute data translated into 8760 hourly observations Information presented in capacity factor (%) units Profiles scaled accordingly to incorporate additional capacity factor information from actual project data Wind Profile Data Collection Methodology

19. February 10, 2010B&V - 19 Base Case Results

20. February 10, 2010B&V - 20 Reserve Margin with No New Units – NPPN (Preliminary)

21. February 10, 2010B&V - 21 Reserve Margin with No New Units – SPPN (Preliminary)

22. February 10, 2010B&V - 22 Reserve Margin with No New Units – Whole SPP (Preliminary)

23. February 10, 2010B&V - 23 Expansion Plan – NPPN (Preliminary)

24. February 10, 2010B&V - 24 Expansion Plan – SPPN (Preliminary)

25. February 10, 2010B&V - 25 CO2 Emissions Intensity – SPPN and SSPP (Preliminary)

26. February 10, 2010B&V - 26 Reserve Margin with New Units – (Preliminary)

27. February 10, 2010B&V - 27 Base Case Results Observations SPP North requires capacity additions early: 2014 SPP South requires capacity late: 2024 As wind resources are added in SPPN between 2013-2020, new baseload resources not justified. Lower capital cost intermediate and peaking units are added in this period. Baseload resources are added in SPPN after 2020 when energy needs increase but additional wind resources are not added in the model. SPP South needs intermediate and new baseload resources for the base case in the later half of the study period. As no carbon legislation is assumed in the base case, coal units are selected in the later half of the study.