1. CLECO TRANSMISSION RATE CASE

2. AGENDA Welcome and Introduction Purpose of Meeting Transmission System Update Formula Rate Overview Formula Rate Protocols Transmission Losses

3. WELCOME Meeting Logistics Standards of Conduct Reminder Presenter Introductions

4. BACKGROUND Current transmission rates ESIA Rates based on 1990 costs OATT Rates based on 1996 compliance filing Transmission rates recover operating costs of the transmission system and return on transmission investments Since 1989, transmission improvements have been made to maintain adequate and reliable service By managing costs and matching new investment to load growth Cleco has avoided requesting a change in transmission rates

5. TODAY’S OBJECTIVES Purpose of the Meeting Cleco will be requesting a change in wholesale transmission and distribution rates Want to engage and involve transmission customers and other stakeholders in the process Timeline By March 30, 2012 – transmission rate filing with FERC June 1, 2012 – proposed effective date of new rates using formula

6. OBJECTIVES Cleco will change from a Stated Rate to a Formula Rate for impacted customers. Cleco has and continues to have major investment s in the transmission system. The cost should be shared between retail and wholesale customers. Order 1000 may require Cleco to invest in upgrades on its system to support regional reliability, Cleco will need a method to share costs between wholesale and retail customers. Major changes to current methodology Cleco will start to invoice all customers using billing demand at coincident peak, unless there is a stated contract demand. All customers will be reflected at Points of Receipt. All rates are developed using the Points of Receipt. Network Service will no longer be billed on LRS, it will be a fixed rate for load at coincident peak. Distribution rate has changed. All “ratchet” demands will be replaced with Coincident peak billing. 6

7. TRANSMISSION SYSTEM UPDATE

8. TRANSMISSION SYSTEM How we plan the transmission system Where we spend money on transmission Significant transmission projects

9. HOW WE PLAN THE TRANSMISSION SYSTEM Annually, perform an assessment and plan looking out ten years, with emphasis on first three to five years Plan the system to meet NERC Reliability Standards as well as to meet Cleco planning guidelines Perform assessments and studies with other neighboring utilities.

10. ACADIANA LOAD POCKET UPDATE

11. WHERE WE SPEND MONEY ON TRANSMISSION Capacity-load growth driven Reliability and system integrity Upgrades of equipment to deal with performance issues, aging infrastructure, end of life issues Transmission service requests Meeting pending NERC reliability standards

12. ACADIANA LOAD POCKET (ALP) PROJECT To address Reliability and Economics Cleco Portion: $125 million 87% complete as of December 31, 2011 Anticipate 100% Complete by December 31, 2012

13. FORMULA RATE OVERVIEW

14. CHANGE IN COSTS Proposed revenue requirement based on 2010 costs = $33.1 million Primary driver of increase is higher investment in transmission plant: net plant grew from $152.4 million to $276.9 million Transmission plant increased approximately 182% over the last 21 years Transmission average peak demand has grown from 1,446 MW (1989) to 2,652 MW (2010)

15. STATED RATE VS FORMULA RATE A standard rate is a fixed charge set in a regulatory process through a rate case – The fixed rates do not change unless another rate case is filed A formula rate is a fixed method for calculating a rate based upon set inputs – The formula is the filed rate – not the results in any one year – The charges to customers update annually – Data input comes from public sources (Form 1) and company data – Recalculation of the charges is done pursuant to a set of protocols – Forecast elements are subject to true-up

16. DETERMINATION OF REVENUE REQUIREMENTS Basic calculation is return on rate base + operating expenses Rate base components: – Transmission plant balance less accumulated depreciation Excludes generator step-up transformers – Allocated general and intangible plant less accumulated depreciation – Accumulated deferred income taxes associated with items included in revenue requirements – Working capital – Other rate base adjustments necessary to reflect funds supplied by investors

17. DETERMINATION OF REVENUE REQUIREMENTS (CONTINUED) Return is determined by applying weighted average cost of capital percent to rate base – Cost of capital rate incorporates cost of debt and cost of equity (i.e., ROE) weighted in proportion to capital structure Operating expenses: – Depreciation expense for transmission plant and allocated general/intangible plant – O&M expense, including transmission O&M and allocated A&G expense – Allocated general tax expense: Property tax, payroll tax, other non-income taxes – Income taxes

18. DETERMINATION OF REVENUE REQUIREMENTS (CONTINUED) Revenue credits: Revenues received that offset costs included in revenue requirements, primarily non-firm and short-term firm revenues for transmission service, and lease payments associated with transmission facilities The load divisor used to develop the unit charges is stated at Points of Receipt (or system input), so all billing determinants will be the customers demands at the Points of Receipt. This does not change the Contract Demands or Reserved Capacity that may be stated at the Points of Delivery.

19. FORMULA RATE Determination of revenue requirements is stated as a formula that uses cost inputs from FERC Form 1 and company records – The Form No. 1 (FN1), a detailed and audited publicly available source of data. – Workpapers provide additional detail or data required by the utility, FERC or intervenors – Detailed cost support attachment to allow more detailed functionalizations and allocations to better sync with ratemaking. The resulting revenue requirement is recomputed annually. The annual revenue requirement is divided by calendar year average transmission system peak demand for long- term firm service to determine the rate per MW. Revenue requirements and rates are billed initially using estimated annual revenue requirements and trued-up to actual revenue requirements when known.

20. FORMULA RATE Revenue requirement used for billing is for a projected test year A “true-up” calculation is done each year to compare the actual revenue requirement to the projected Any difference is an adjustment to the revenue requirement for the next projected period

21. ADVANTAGES OF FORMULA RATE Annual rate adjustment to reflect new investment, load growth, and usage credits Right to have data requests answered during the annual review period Review input Point out input errors Procedures to handle disputes are predetermined through the protocols Improve transparency by providing data, changes in accounting practices, and customer meetings Set forth annual update procedures, dates, timing, etc. How to handle data input or accounting errors Allow for customers to budget for upcoming rate changes

22. WHOLESALE DISTRIBUTION RATES Cleco will be submitting revised Wholesale Distribution Rates. The revenue requirement is calculated based on cost of non-secondary poles, towers, conductors and substation investments multiplied by the fixed charge rate. The rate is derived by dividing the revenue requirement by the 12 CP load on the distribution system.

23. FORMULA RATE PROTOCOLS

24. FORMULA RATE PROTOCOLS & TIMELINE ILLUSTRATION Cleco will implement a formula methodology to calculate its transmission service rates for Network Integration Transmission Service, Point-to-Point Transmission Service, and ESIA service The revenue requirements and rates will be recalculated annually using the approved formula and in accordance with the established formula protocols. The protocols are separated into the following categories: – Annual update process – Annual review procedures – Resolution of challenges

25. ANNUAL UPDATE PROCESS Each year the ATRR and the PTP transmission rates will be projected based on prior calendar year data. This represents the annual update for the upcoming rate year – The annual update will be posted to the OASIS website – An informational filing will be made with FERC – The date on which these events occur is the publication date The annual update will also include the true-up for the prior year ATRR – True-up amount (including interest) increases or decreases ATRR for upcoming billing period

26. PROPOSED ANNUAL REVIEW PROCEDURES Each annual update shall be subject to the annual review procedures Interested parties will have up to 105 days after the publication date to serve information requests to Cleco (i.e., Discovery Period) Cleco will respond to requests within 10 business days in most circumstances Any interested party will have up to 135 days after the publication date to review calculations and notify Cleco of any specific challenges Preliminary challenges will be posted to the OASIS website

27. RESOLUTION OF CHALLENGES For any preliminary challenges to the Annual Update not resolved, the interested party may make a formal challenge with FERC

28. TRANSMISSION LOSSES

29. SUMMARY OF LOSS FACTORS 29 Cleco evaluates system losses every two years based on the system configuration and loads in the odd years. The most recent completed study was for the year 2009. These loss factors were taken or developed from that study and used in the transmission rates to be filed. Energy Losses VoltageLossExpansion LevelFactor Transmission (≥ 69kV)0.01681.0171 Subtrans. (34.5 kV to < 69 kV)0.02901.0299 Primary (13.8 kV to < 34.5 kV)0.03881.0403 Demand Losses (Average 12 Coincident Peaks) VoltageLossExpansion LevelFactor Transmission (≥ 69kV)0.01701.0173 Subtrans. (34.5 kV to < 69 kV)0.03241.0335 Primary (13.8 kV to < 34.5 kV)0.04431.0463 Losses = Receipt x Loss Factor Receipt = Delivery x Expansion Factor

30. Questions and Discussion