Edgar Filing: CLECO POWER LLC

clecocorp200910k.htm

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

__________________

FORM 10-K

[X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended December 31, 2009

[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

__________________

Commission file number 1-15759

CLECO CORPORATION

(Exact name of registrant as specified in its charter)


Louisiana (State or other jurisdiction of incorporation or organization)	72-1445282 (I.R.S. Employer Identification No.)

2030 Donahue Ferry Road, Pineville, Louisiana (Address of principal executive offices)	71360-5226 (Zip Code)

Registrant’s telephone number, including area code: (318) 484-7400

Securities registered pursuant to Section 12(b) of the Act:


Title of each class		Name of each exchange on which registered
Common Stock, $1.00 par value, and associated rights to purchase Preferred Stock		New York Stock Exchange

Securities registered pursuant to Section 12(g) of the Act:

Title of each class
4.50% Cumulative Preferred Stock, $100 Par Value

__________________

Commission file number 1-05663

CLECO POWER LLC

(Exact name of registrant as specified in its charter)


Louisiana (State or other jurisdiction of incorporation or organization)		72-0244480 (I.R.S. Employer Identification No.)

2030 Donahue Ferry Road, Pineville, Louisiana (Address of principal executive offices)		71360-5226 (Zip Code)

Registrant’s telephone number, including area code: (318) 484-7400

Securities registered pursuant to Section 12(b) of the Act:


Title of each class			Name of each exchange on which registered
6.50% Senior Notes due 2035			New York Stock Exchange

Securities registered pursuant to Section 12(g) of the Act:

Title of each class
Membership Interests

Cleco Power LLC, a wholly owned subsidiary of Cleco Corporation, meets the conditions set forth in General Instruction (I)(1)(a) and (b) of Form 10-K and is therefore filing this Form 10-K with the reduced disclosure format.

Indicate by check mark if Cleco Corporation is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes x No ¨

Indicate by check mark if Cleco Power LLC is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes ¨ No x

Indicate by check mark if the Registrants are not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes ¨ No x

Indicate by check mark whether the Registrants: (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the Registrants were required to file such reports) and (2) have been subject to such filing requirements for the past 90 days. Yes x No ¨

Indicate by check mark whether the Registrants have submitted electronically and posted on their corporate website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the Registrants were required to submit and post such files). Yes ¨ No ¨

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of each of the Registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. ¨

Indicate by check mark whether Cleco Corporation is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one): Large accelerated filer x Accelerated filer ¨ Non-accelerated filer ¨ (Do not check if a smaller reporting company) Smaller reporting company ¨

Indicate by check mark whether Cleco Power LLC is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See definitions of “large accelerated filer,” accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one): Large accelerated filer ¨ Accelerated filer ¨ Non-accelerated filer x (Do not check if a smaller reporting company) Smaller reporting company ¨

Indicate by check mark whether the Registrants are shell companies (as defined in Rule 12b-2 of the Exchange Act) Yes ¨ No x

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

(Continuation of cover page)

The aggregate market value of the Cleco Corporation voting stock held by non-affiliates was $1,320,856,355 as of the last business day of Cleco Corporation’s most recently completed second fiscal quarter, based on a price of $22.42 per common share, the closing price of Cleco Corporation’s common stock as reported on the New York Stock Exchange on such date. Cleco Corporation’s Cumulative Preferred Stock is not listed on any national securities exchange, nor are prices for the Cumulative Preferred Stock quoted on any national automated quotation system; therefore, its market value is not readily determinable and is not included in the foregoing amount.

As of February 1, 2010, there were 60,503,781 outstanding shares of Cleco Corporation’s Common Stock, par value $1.00 per share. As of February 1, 2010, all of Cleco Power’s Membership Interests were owned by Cleco Corporation.

DOCUMENTS INCORPORATED BY REFERENCE

Portions of Cleco Corporation’s definitive Proxy Statement relating to its Annual Meeting of Shareholders to be held on April 30, 2010, are incorporated by reference into Part III herein.

This combined Form 10-K is separately filed by Cleco Corporation and Cleco Power. Information in this filing relating to Cleco Power is filed by Cleco Corporation and separately by Cleco Power on its own behalf. Cleco Power makes no representation as to information relating to Cleco Corporation (except as it may relate to Cleco Power) or any other affiliate or subsidiary of Cleco Corporation.

This report should be read in its entirety as it pertains to each respective Registrant. The Notes to the Financial Statements for the Registrants and certain other sections of this report are combined.

TABLE OF CONTENTS

			PAGE
GLOSSARY OF TERMS			3
CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS			5

PART I
ITEM 1.	Business
	General	7
	Operations	7
	Regulatory Matters, Industry Developments, and Franchises	12
	Environmental Matters	14
ITEM 1A.	Risk Factors	19
ITEM 1B.	Unresolved Staff Comments	25
ITEM 2.	Properties	25
ITEM 3.	Legal Proceedings	26
ITEM 4.	Submission of Matters to a Vote of Security Holders	26
	Board of Directors of Cleco	27
	Executive Officers of Cleco	28

PART II
ITEM 5.	Market for Registrants’ Common Equity, Related Stockholder Matters and Cleco Corporation’s Purchases of Equity Securities	30
ITEM 6.	Selected Financial Data	31
ITEM 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	32
ITEM 7A.	Quantitative and Qualitative Disclosures About Market Risk	62
ITEM 8.	Financial Statements and Supplementary Data	65
ITEM 9.	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	124
ITEM 9A.	Controls and Procedures	124
ITEM 9B.	Other Information	125

PART III
ITEM 10.	Directors, Executive Officers and Corporate Governance of the Registrants	126
ITEM 11.	Executive Compensation	126
ITEM 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	127
ITEM 13.	Certain Relationships and Related Transactions, and Director Independence	127
ITEM 14.	Principal Accountant Fees and Services	127

PART IV
ITEM 15.	Exhibits and Financial Statement Schedules	128
	Signatures	154

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

GLOSSARY OF TERMS

References in this filing, including all items in Parts I, II, III, and IV, to “Cleco” mean Cleco Corporation and its subsidiaries, including Cleco Power, and references to “Cleco Power” mean Cleco Power LLC, unless the context clearly indicates otherwise. Additional abbreviations or acronyms used in this filing, including all items in Parts I, II, III, and IV are defined below:

ABBREVIATION OR ACRONYM	DEFINITION
401(k) Plan	Cleco Power 401(k) Savings and Investment Plan
Acadia	Acadia Power Partners, LLC and its combined-cycle, natural gas-fired power plant near Eunice, Louisiana, 50% owned by APH and 50% owned by Cajun. Prior to September 13, 2007, Acadia was 50% owned by APH and 50% owned by Calpine Acadia Holdings, LLC.
Acadiana Load Pocket	An area in south central Louisiana that has experienced transmission constraints caused by local load and lack of generation. Transmission within the Acadiana Load Pocket is owned by several entities, including Cleco Power.
Accounting Codification	FASB Accounting Standards CodificationTM the source of authoritative U.S. GAAP recognized by the FASB to be applied by nongovernmental entities.
AFUDC	Allowance for Funds Used During Construction
Amended EPC Contract	Amended and Restated EPC Contract between Cleco Power and Shaw, executed on May 12, 2006, for engineering, procurement, and construction of Rodemacher Unit 3, as amended by Amendment No. 1 thereto effective March 9, 2007, Amendment No. 2 thereto dated as of July 2, 2008, Amendment No. 3 thereto dated as of July 22, 2009, and Amendment No. 4 thereto dated October 19, 2009.
Amended Lignite Mining Agreement	Amended and restated lignite mining agreement effective December 29, 2009
APH	Acadia Power Holdings LLC, a wholly owned subsidiary of Midstream
ARO	Asset Retirement Obligation
Attala	Attala Transmission LLC, a wholly owned subsidiary of Cleco Corporation. Prior to February 1, 2007, Attala was a wholly owned subsidiary of Midstream.
Bear Energy	BE Louisiana LLC, an indirect wholly owned subsidiary of JPMorgan Chase & Co. In September 2008, BE Louisiana LLC was merged into JPMVEC.
Bidding Procedures Order	Bidding Procedures Order, in connection with the sale of CAH’s interest in Acadia, approved by the Calpine Debtors Bankruptcy Court by order dated May 9, 2007
CAA	Clean Air Act
CAH	Calpine Acadia Holdings, LLC
CAH Assets	CAH’s interest in Acadia and certain related assets
Cajun	Cajun Gas Energy L.L.C.
Calpine	Calpine Corporation
Calpine Debtors	Calpine, CES, and certain other Calpine subsidiaries
Calpine Debtors Bankruptcy Court	U.S. Bankruptcy Court for the Southern District of New York
Calpine Tolling Agreements	Capacity Sale and Tolling Agreements between Acadia and CES which were suspended in March 2006
CCN	Certificate of Public Convenience and Necessity
CES	Calpine Energy Services, L.P.
Claims Settlement Agreement	Claims Settlement Agreement, dated April 23, 2007, by and among Calpine, CAH, CES, Acadia, and APH
CLE Intrastate	CLE Intrastate Pipeline Company LLC, a wholly owned subsidiary of Midstream
Cleco Energy	Cleco Energy LLC, a wholly owned subsidiary of Midstream
Cleco Innovations LLC	A wholly owned subsidiary of Cleco Corporation
Cleco Katrina/Rita	Cleco Katrina/Rita Hurricane Recovery Funding LLC, a wholly owned subsidiary of Cleco Power
CO2	Carbon dioxide
Compliance Plan	The one-year plan included in the Stipulation and Consent Agreement (Docket No. IN07-28-00), effective June 12, 2007
Consent Agreement	Stipulation and Consent Agreement, dated as of July 25, 2003, between Cleco and the FERC Staff
DHLC	Dolet Hills Lignite Company, LLC, a wholly owned subsidiary of SWEPCO
Diversified Lands	Diversified Lands LLC, a wholly owned subsidiary of Cleco Innovations LLC
DOE	United States Department of Energy
Entergy	Entergy Corporation
Entergy Gulf States	Entergy Gulf States Louisiana, L.L.C., formerly Entergy Gulf States, Inc.
Entergy Louisiana	Entergy Louisiana, LLC
Entergy Mississippi	Entergy Mississippi, Inc.
Entergy Services	Entergy Services, Inc., as agent for Entergy Louisiana and Entergy Gulf States
EPA	United States Environmental Protection Agency
EPC	Engineering, Procurement, and Construction
ERO	Electric Reliability Organization
ESOP	Cleco Corporation Employee Stock Ownership Plan
ESPP	Cleco Corporation Employee Stock Purchase Plan
Evangeline	Cleco Evangeline LLC, a wholly owned subsidiary of Midstream, and its combined-cycle, natural gas-fired power plant located in Evangeline Parish, Louisiana
Evangeline 2010 Tolling Agreement	Capacity Sale and Tolling Agreement between Evangeline and JPMVEC, which was executed in February 2010.
Evangeline Restructuring Agreement	Purchase, Sale and Restructuring Agreement entered into on February 22, 2010, by Evangeline and JPMVEC.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

ABBREVIATION OR ACRONYM	DEFINITION
Evangeline Tolling Agreement	Capacity Sale and Tolling Agreement between Evangeline and BE Louisiana LLC (as successor to Williams Power Company, Inc. (formerly known as Williams Energy Marketing & Trading Company)) which was set to expire in 2020 and was terminated in February 2010. In September 2008, BE Louisiana LLC was merged into JPMVEC.
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
GAAP	Generally Accepted Accounting Principles in the United States
GDP-IPD	Gross Domestic Product – Implicit Price Deflator
Generation Services	Cleco Generation Services LLC, a wholly owned subsidiary of Midstream
GO Zone	Gulf Opportunity Zone Act of 2005 (Public Law 109-135)
ICT	Independent Coordinator of Transmission
Interconnection Agreement	One of two Interconnection Agreement and Real Estate Agreements, one between Attala and Entergy Mississippi, and the other between Perryville and Entergy Louisiana
IRP	Integrated Resource Planning
IRS	Internal Revenue Service
JPMVEC	J.P. Morgan Ventures Energy Corporation. In September 2008, BE Louisiana LLC was merged into JPMVEC.
kWh	Kilowatt-hour(s) as applicable
LDEQ	Louisiana Department of Environmental Quality
LIBOR	London Inter-Bank Offer Rate
Lignite Mining Agreement	Dolet Hills Mine Lignite Mining Agreement, dated as of May 31, 2001
LPSC	Louisiana Public Service Commission
LTICP	Cleco Corporation Long-Term Incentive Compensation Plan
Midstream	Cleco Midstream Resources LLC, a wholly owned subsidiary of Cleco Corporation
MMBtu	Million British thermal units
Moody’s	Moody’s Investors Service
MW	Megawatt(s) as applicable
MWh	Megawatt-hour(s) as applicable
NAC	North American Coal Corporation
NERC	North American Electric Reliability Corporation
NOx	Nitrogen oxides
OCI	Other Comprehensive Income
Oxbow	Oxbow Lignite Company, LLC, 50% owned by Cleco Power and 50% owned by SWEPCO
PCAOB	Public Company Accounting Oversight Board
PCB	Polychlorinated biphenyl
PEH	Perryville Energy Holdings LLC, a wholly owned subsidiary of Midstream.
Perryville	Perryville Energy Partners, L.L.C., a wholly owned subsidiary of Cleco Corporation. Prior to February 1, 2007, Perryville was a wholly owned subsidiary of Perryville Energy Holdings LLC, a wholly owned subsidiary of Midstream.
Perryville and PEH Bankruptcy Court	U.S. Bankruptcy Court for the Western District of Louisiana, Alexandria Division
Power Purchase Agreement	Power Purchase Agreement, dated as of January 28, 2004, between Perryville and Entergy Services
PRP	Potentially responsible party
Registrant(s)	Cleco Corporation and Cleco Power
RFP	Request for Proposal
Rodemacher Unit 3	A 600-MW solid-fuel generating unit at Cleco Power’s Rodemacher plant site in Boyce, Louisiana that commenced commercial operations on February 12, 2010.
RSP	Rate Stabilization Plan
RTO	Regional Transmission Organization
Sale Agreement	Purchase and Sale Agreement, dated as of January 28, 2004, between Perryville and Entergy Louisiana
SEC	Securities and Exchange Commission
SERP	Cleco Corporation Supplemental Executive Retirement Plan
Shaw	Shaw Contractors, Inc., a subsidiary of The Shaw Group Inc.
SO2	Sulfur dioxide
SPP	Southwest Power Pool
Support Group	Cleco Support Group LLC, a wholly owned subsidiary of Cleco Corporation
SWEPCO	Southwestern Electric Power Company, a wholly owned subsidiary of American Electric Power Company, Inc.
Teche	Teche Electric Cooperative, Inc.
The Bear Stearns Companies Inc.	The parent company of Bear, Stearns & Co. Inc.
VaR	Value-at-risk
Williams	Williams Power Company, Inc.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

This Annual Report on Form 10-K includes “forward-looking statements” about future events, circumstances, and results. All statements other than statements of historical fact included in this Annual Report are forward-looking statements, including, without limitation, statements regarding the construction and cost of Rodemacher Unit 3; JPMVEC’s performance under the Evangeline 2010 Tolling Agreement; future capital expenditures; projections; business strategies; goals; competitive strengths; market and industry developments; development and operation of facilities; future environmental regulations and remediation liabilities; and the anticipated outcome of various regulatory and legal proceedings. Although the Registrants believe that the expectations reflected in such forward-looking statements are reasonable, such forward-looking statements are based on numerous assumptions (some of which may prove to be incorrect) and are subject to risks and uncertainties that could cause the actual results to differ materially from the Registrants’ expectations. In addition to any assumptions and other factors referred to specifically in connection with these forward-looking statements, the following list identifies some of the factors that could cause the Registrants’ actual results to differ materially from those contemplated in any of the Registrants’ forward-looking statements:

Factors affecting utility operations, such as unusual weather conditions or other natural phenomena; catastrophic weather-related damage (such as hurricanes and other storms); unscheduled generation outages; unanticipated maintenance or repairs; unanticipated changes to fuel costs; cost of and reliance on natural gas as a component of Cleco’s generation fuel mix and their impact on competition and franchises, fuel supply costs or availability constraints due to higher demand, shortages, transportation problems or other developments; decreased customer load; environmental incidents; environmental compliance costs; or power transmission system constraints;

§	Cleco Corporation’s holding company structure and its dependence on the earnings, dividends, or distributions from its subsidiaries to meet its debt obligations and pay dividends on its common stock;

§	Cleco Power’s ability to construct, operate, and maintain, within its projected costs, Rodemacher Unit 3, in addition to any other self-build projects identified in future IRP and RFP processes;

§	Dependence of Cleco Power for energy from sources other than its facilities and the uncertainty of future short-term sources of such additional energy;

§	Nonperformance by and creditworthiness of counterparties under tolling, power purchase, and energy service agreements, or the restructuring of those agreements, including possible termination;

Regulatory factors such as changes in rate-setting policies, recovery of investments made under traditional regulation, recovery of storm restoration costs, the frequency and timing of rate increases or decreases, the results of periodic NERC audits and fuel audits, the results of IRP and RFP processes, the formation of ICTs, and the compliance with the ERO reliability standards for bulk power systems by Cleco Power, Acadia, and Evangeline;

§	Financial or regulatory accounting principles or policies imposed by FASB, the SEC, the PCAOB, FERC, the LPSC or similar entities with regulatory or accounting oversight;

§	Economic conditions, including the ability of customers to continue paying for utility bills, related growth and/or down-sizing of businesses in Cleco’s service area, monetary fluctuations, changes in commodity prices, and inflation rates;

§	The current global economic downturn and U.S. recession;

§	Credit ratings of Cleco Corporation and Cleco Power;

§	Ability to remain in compliance with debt covenants;

§	Changing market conditions and a variety of other factors associated with physical energy, financial transactions, and energy service activities, including, but not limited to, price, basis, credit, liquidity, volatility, capacity, transmission, interest rates, and warranty risks;

§	Impact of the imposition of energy efficiency requirements;

§	Reliability of Rodemacher Unit 3 during its first year of commercial operations;

§	Acts of terrorism;

§	Availability or cost of capital resulting from changes in Cleco’s business or financial condition, interest rates or market perceptions of the electric utility industry and energy-related industries;

§	Uncertain tax positions;

§	Employee work force factors, including work stoppages and changes in key executives;

Legal, environmental, and regulatory delays and other obstacles associated with mergers, acquisitions, reorganizations, investments in joint ventures, or other capital projects, including Rodemacher Unit 3, the joint project to upgrade the Acadiana Load Pocket transmission system, Entergy Louisiana’s acquisition of the remaining 50%, a 580-MW unit, at the Acadia Power Station, and the Teche blackstart project;

§	Costs and other effects of legal and administrative proceedings, settlements, investigations, claims and other matters;

§	Changes in federal, state, or local laws, and changes in tax laws or rates, regulating policies or environmental laws and regulations;

§	Ability of Cleco Power to recover, from its retail customers, the costs of compliance with environmental laws and regulations; and

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

§	Ability of the Dolet Hills lignite reserve to provide sufficient fuel to the Dolet Hills Power Station until at least 2026.

For additional discussion of these factors and other factors that could cause actual results to differ materially from those contemplated in the Registrants’ forward-looking statements, see Item 1A, “Risk Factors” and Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Cleco Power — Significant Factors Affecting Cleco Power” and “— Midstream — Significant Factors Affecting Midstream,” in this Annual Report.

All subsequent written and oral forward-looking statements attributable to the Registrants or persons acting on their behalf are expressly qualified in their entirety by the factors identified above.

The Registrants undertake no obligation to update any forward-looking statements, whether as a result of changes in actual results, changes in assumptions, or other factors affecting such statements.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

PART I

ITEM 1. BUSINESS

GENERAL

Cleco Corporation was incorporated on October 30, 1998, under the laws of the State of Louisiana. Cleco Corporation is a public utility holding company which holds investments in several subsidiaries, including Cleco Power and Midstream, which are its operating business segments. Cleco Corporation, subject to certain limited exceptions, is exempt from regulation as a public utility holding company pursuant to provisions of the Public Utility Holding Company Act of 2005.

Cleco Power’s predecessor was incorporated on January 2, 1935, under the laws of the State of Louisiana. Cleco Power was organized on December 12, 2000. Cleco Power is an electric utility engaged principally in the generation, transmission, distribution and sale of electricity within Louisiana. Cleco Power is regulated by the LPSC and FERC, along with other governmental authorities, which determine the rates Cleco Power can charge its customers. Cleco Power serves approximately 277,000 customers in 107 communities in central and southeastern Louisiana. Cleco Power’s operations are described below in the consolidated description of Cleco’s business segments.

Midstream, organized effective September 1, 1998, under the laws of the State of Louisiana, is a merchant energy subsidiary that owns and operates a merchant power plant (Evangeline). At December 31, 2009, Midstream also owned a 50 percent interest in a merchant power plant (Acadia) and operated the plant on behalf of its partner. During 2009, Cleco Power and Entergy Louisiana executed definitive agreements whereby Cleco Power and Entergy Louisiana would each purchase one 580-MW unit of the Acadia Power Station. The transaction with Cleco Power was completed in February 2010 and the transaction with Entergy Louisiana is expected to be completed in late 2010 or early 2011. For additional information, see Part II, Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 15 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Acadia Transactions” and Note 23 — “Subsequent Events — Acadia Transaction.”

At December 31, 2009, Cleco had 1,305 employees. Cleco’s mailing address is P.O. Box 5000, Pineville, Louisiana 71361-5000, and its telephone number is (318) 484-7400. Cleco’s homepage on the Internet is located at http://www.cleco.com. Cleco Corporation’s and Cleco Power’s Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and other filings with the SEC are available, free of charge, through Cleco’s website after those reports or filings are filed electronically with or furnished to the SEC. Cleco’s filings also can be obtained at the SEC’s Public Reference Room at 100 F Street, NE, Room 1580, Washington, DC 20549. Information on the operation of the Public Reference Room may be obtained by calling the SEC at 1-800-SEC-0330. Cleco’s electronically filed reports also can be obtained on the SEC’s Internet site located at http://www.sec.gov. Cleco’s corporate governance guidelines, code of business conduct, ethics and business standards, and the charters of its board of directors’ audit, compensation, executive, finance, nominating/governance and qualified legal compliance committees are available on its website and available in print to any shareholder upon request. Information on Cleco’s website or any other website is not incorporated by reference into this Report and does not constitute a part of this Report.

At December 31, 2009, Cleco Power had 1,015 employees. Cleco Power’s mailing address is P.O. Box 5000, Pineville, Louisiana, 71361-5000, and its telephone number is (318) 484-7400.

Cleco Power meets the conditions specified in General Instructions I(1)(a) and (b) to Form 10-K and therefore is permitted to use the reduced disclosure format for wholly owned subsidiaries of reporting companies. Accordingly, Cleco Power has omitted from this Report the information called for by Item 4 (Submission of Matters to a Vote of Security Holders) of Part I of Form 10-K; the following Part II items of Form 10-K: Item 6 (Selected Financial Data) and Item 7 (Management’s Discussion and Analysis of Financial Condition and Results of Operations); and the following Part III items of Form 10-K: Item 10 (Directors, Executive Officers, and Corporate Governance of the Registrants), Item 11 (Executive Compensation), Item 12 (Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters), and Item 13 (Certain Relationships and Related Transactions, and Director Independence).

OPERATIONS

Cleco Power

Segment Financial Information

Summary financial results of the Cleco Power segment for years 2009, 2008, and 2007 are presented below.

(THOUSANDS)	2009		2008		2007
Revenue
Electric operations	$	808,646	$	1,032,970	$	988,193
Other operations		33,558		36,675		35,176
Affiliate revenue		23		29		42
Intercompany revenue		1,372		2,008		2,008
Operating revenue, net	$	843,599	$	1,071,682	$	1,025,419
Depreciation expense	$	77,064	$	76,420	$	78,522
Interest charges	$	58,562	$	47,283	$	29,565
Interest income	$	1,449	$	3,943	$	5,422
Federal and state income taxes	$	15,297	$	27,956	$	29,613
Segment profit	$	111,166	$	113,832	$	84,673
Additions to long-lived assets	$	235,385	$	321,407	$	492,445
Equity investment in investees	$	12,873	$	-	$	-
Segment assets	$	3,363,962	$	3,041,597	$	2,306,482

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

For additional information on Cleco Power’s results of operations, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Results of Operations — Cleco Power’s Results of Operations.”

Certain Factors Affecting Cleco Power

As an electric utility, Cleco Power is affected, to varying degrees, by a number of factors influencing the electric utility industry in general. These factors include, among others, fluctuations in the price of fuel, an increasingly competitive business environment, the cost of compliance with environmental and reliability regulations, conditions in the credit markets and global economy, changes in the federal and state regulation of generation, transmission, and the sale of electricity, and the increasing uncertainty of future federal regulatory and environmental policies. For a discussion of various regulatory changes and competitive forces affecting Cleco Power and other electric utilities, see “— Regulatory Matters, Industry Developments, and Franchises” and Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Market Restructuring.” For a discussion of risk factors affecting Cleco Power’s business, see Item 1A, “Risk Factors — Global Economic Downturn,” “— Future Electricity Sales,” “— Fuel Cost Audits,” “— Hedging and Risk Management Activities,” “— Transmission Constraints,” “— Commodity Prices,” “— Cleco Power Generation Facilities,” “— ERO,” “— Environmental Compliance,” “— Regulatory Compliance,” “— Weather Sensitivity,” “— Retail Electric Service,” “— Wholesale Electric Service,” “— Cleco Credit Ratings,” “— Interest Rate Swap,” and “ — Cleco Power’s Rates.”

Power Generation

Cleco Power operates and either owns or has an ownership interest in three steam electric generating stations and one gas turbine. As of December 31, 2009, Cleco Power’s aggregate net electric generating capacity was 1,318 MW. This amount reflects the maximum production capacity these units can sustain over a specified period of time. The following table sets forth certain information with respect to Cleco Power’s generating facilities:

GENERATING STATION	GENERATING UNIT #	YEAR OF INITIAL OPERATION	NAME PLATE CAPACITY (MW)	NET CAPACITY (MW)(1)	TYPE OF FUEL USED FOR GENERATION(2)
Franklin Gas Turbine		1973	7	8	natural gas
Teche Power Station	1	1953	23	19	natural gas
	2	1956	48	34	natural gas
	3	1971	359	331	natural gas/oil
Rodemacher Power Station	1	1975	440	435	natural gas/oil
	2	1982	157(3)	155	coal/natural gas
Dolet Hills Power Station		1986	325(4)	336	lignite/natural gas
Total generating capability			1,359	1,318

(1) Based on capacity testing of the generating units performed between June and September 2007.

(2) When oil is used on a standby basis, capacity may be reduced.

(3) Represents Cleco Power’s 30% ownership interest in the capacity of Rodemacher Unit 2, a 523-MW generating unit.

(4) Represents Cleco Power’s 50% ownership interest in the capacity of Dolet Hills, a 650-MW generating unit.

The following table sets forth the amounts of power generated by Cleco Power for the years indicated.

PERIOD	THOUSAND MWh	PERCENT OF TOTAL ENERGY REQUIREMENTS
2009	4,943	46.4
2008	4,747	44.3
2007	4,504	42.0
2006	4,691	44.0
2005	5,284	51.2

In May 2006, Cleco Power began construction of Rodemacher Unit 3, a 600-MW solid-fuel power plant at its Rodemacher facility. The unit commenced commercial operations on February 12, 2010. Rodemacher Unit 3 is capable of burning various solid fuels, but initially will primarily burn petroleum coke produced by several refineries throughout the Gulf Coast region. The total capital cost of the project, including AFUDC, Amended EPC Contract costs, and other development expenses, is approximately $1.0 billion. For additional information on Rodemacher Unit 3, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Liquidity and Capital Resources — Regulatory Matters — Rodemacher Unit 3.”

Fuel and Purchased Power

Changes in fuel and purchased power expenses reflect fluctuations in types and pricing of fuel used for electric generation, fuel handling costs, availability of economical power for purchase, and deferral of expenses for recovery from customers through the fuel adjustment clause in subsequent months. For a discussion of certain risks associated with changes in fuel costs and their impact on utility customers, see Item 1A, “Risk Factors — Fuel Cost Audits” and “— Transmission Constraints.”

The following table sets forth the percentages of power generated from various fuels at Cleco Power’s electric generating plants, the cost of fuel used per MWh attributable to each such fuel, and the weighted average fuel cost per MWh. The percent of generation from each fuel source as shown in the table is expected to change as a result of the startup of Rodemacher Unit 3. Rodemacher Unit 3 is capable of burning various solid fuels, but initially will primarily burn petroleum coke. Rodemacher Unit 3 is expected to diversify and help stabilize Cleco Power’s fuel costs, given the availability and projected pricing of petroleum coke. The generation from petroleum coke in the following table represents power produced during testing of Rodemacher Unit 3.

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CLECO POWER	2009 FORM 10-K

			LIGNITE				COAL				NATURAL GAS				FUEL OIL				PETROLEUM COKE		WEIGHTED
YEAR	COST PER MWh		PERCENT OF GENERATION		COST PER MWh		PERCENT OF GENERATION		COST PER MWh		PERCENT OF GENERATION		COST PER MWh		PERCENT OF GENERATION		COST PER MWh		PERCENT OF GENERATION		AVERAGE COST PER MWh
2009	$	26.04		45.1	$	27.10		21.5	$	105.22		33.1	$	-		-	$	34.64		0.3	$	52.49
2008	$	24.09		51.3	$	27.50		18.4	$	108.48		30.3	$	-		-	$	-		-	$	50.27
2007	$	19.80		42.2	$	26.07		24.8	$	129.80		33.0	$	-		-	$	-		-	$	57.65
2006	$	18.20		50.0	$	22.81		20.8	$	125.07		29.1	$	107.65		0.1	$	-		-	$	50.32
2005	$	17.44		45.7	$	19.44		20.6	$	85.72		27.3	$	83.08		6.4	$	-		-	$	40.79

Power Purchases

When the market price of power is more economical than self-generation of power or when Cleco Power needs power to supplement its own electric generation, and when transmission capacity is available, Cleco Power purchases power from energy marketing companies or neighboring utilities. These purchases are made from the wholesale power market in the form of generation capacity and/or energy. During 2009, portions of Cleco Power’s capacity and power purchases were made at contract prices, and the remainder was made at prevailing market prices.

The following table sets forth the average cost and amounts of power purchased by Cleco Power on the wholesale market.

PERIOD	COST PER MWh		THOUSAND MWh		PERCENT OF TOTAL ENERGY REQUIREMENTS
2009	$	34.57		5,712		53.6
2008	$	73.72		5,959		55.7
2007	$	58.08		6,221		58.0
2006	$	59.50		5,968		56.0
2005	$	69.84		5,028		48.8

During 2009, 53.6% of Cleco Power’s energy requirements were met with purchased power, down from 55.7% in 2008. The primary factor causing the decrease was the increased generation from Cleco Power’s own facilities as a result of increased power transmission system constraints. The lower cost per MWh of purchased power was primarily due to lower natural gas prices. Cleco Power expects the volume of purchased power to decrease in future periods as a result of the acquisition of 50% of the Acadia Power Station, or one of its two 580-MW units, and the completion of Rodemacher Unit 3. For information on Cleco Power’s ability to pass on to its customers substantially all of its fuel and purchased power expenses, see “— Regulatory Matters, Industry Developments, and Franchises — Rates.”

During 2009, Cleco Power obtained approximately 40.4% of its annual capacity from short- and long-term power purchase agreements. One agreement was with Bear Energy for 500 MW of annual capacity and energy which expired at the end of 2009. The second agreement was with NRG Power Marketing, Inc. (NRG). The term of this agreement was April through October 2009 during which Cleco Power purchased 200 MW from June through September and 50 MW during the remainder of the term. A third capacity and energy agreement with Acadia was for 235 MW for the term of March through September 2009. Cleco Power also has a long-term contract, which expires in April 2018, for the purchase of 20 MW of power from the Sabine River Authority, which operates a hydroelectric generating plant. In addition, Cleco Power has a wholesale power contract with the city of Natchitoches, which provided 41 MW of capacity in 2009. The contract was scheduled to expire in December 2009. However, the expiration date has been extended by three months to facilitate negotiations for a long-term contract.

Beginning in January 2010, Acadia began serving Cleco Power under a tolling agreement covering 50% of the Acadia Power Station. In February 2010, the transaction between Cleco Power and Acadia was completed and Cleco Power now owns and operates the unit at Acadia. Cleco expects to meet its native load demand in 2010 with Cleco Power’s own generation capacity, the acquisition of 580 MW from the Acadia plant, and the completion of Rodemacher Unit 3.

Because of its location on the transmission grid, Cleco Power relies on two main suppliers of electric transmission when accessing external power markets. At times, constraints limit the amount of purchased power these transmission providers can deliver into Cleco Power’s service territory. Cleco Power’s power contracts, as well as spot market power purchases, may be affected by these transmission constraints. For information on the Acadiana Load Pocket project and how transmission constraints in this area are expected to be reduced, see Part II, Item 7A, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Regulatory Matters — Acadiana Load Pocket.”

Coal and Lignite Supply

Cleco Power uses coal for generation at Rodemacher Unit 2. In 2007, Cleco Power entered into agreements with Rio Tinto Energy America and Peabody Energy which will provide the majority of coal needs through 2014. The coal supply agreements are fixed-priced for each year of the contract and together provide for the full requirements to support Cleco Power’s minimum planned dispatch of Rodemacher Unit 2 (4 million tons total over the 7-year period). To the extent that the actual dispatch of the unit exceeds the planned dispatch, Cleco Power expects to make additional spot purchases to maintain inventory within targeted levels. The volume commitment was designed to reasonably assure that excess inventory will not accumulate during the term of the agreement. With respect to transportation of coal, Cleco Power has a three-year agreement with Union Pacific Railroad Company (UP) for transportation of coal from Wyoming’s Powder River Basin to Rodemacher Unit 2 through 2011. Cleco Power leases approximately 241 railcars to transport its coal under two long-term leases. One of the railcar leases expires in March 2017, and the other expires in March 2021.

Cleco Power uses lignite for generation at the Dolet Hills Power Station. Cleco Power and SWEPCO, each a 50% owner of Dolet Hills, have acquired an undivided 50% interest

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CLECO POWER	2009 FORM 10-K

in the other’s leased and owned lignite reserves within the Dolet Hills mine in northwestern Louisiana. In May 2001, Cleco Power and SWEPCO entered into a long-term agreement with DHLC for the mining and delivery of such lignite reserves. These reserves are expected to provide a substantial portion of the Dolet Hills’ unit’s fuel requirements throughout the life of the contract with DHLC. The term of this contract runs until all economically mineable lignite has been mined, which is currently estimated to be around 2016.

Additionally, Cleco Power and SWEPCO had entered into an agreement which was set to expire on December 31, 2010 with the Red River Mining Company to purchase lignite. Cleco Power’s and SWEPCO’s minimum annual purchase requirement of lignite under this agreement was 550,000 tons. However, on December 29, 2009, Cleco Power and SWEPCO acquired all interests in the Red River mine, and have merged its operations with the Dolet Hills mine. The Lignite Mining Agreement with DHLC has been amended to extend its services to cover operations in both mining areas. Among other things, the terms of this acquisition provided for the transfer of the reserves formerly held by the Red River Mining Company to Oxbow which is owned 50% by Cleco Power and 50% by SWEPCO. It is estimated that Oxbow holds approximately 100 million tons of recoverable lignite reserves which together with the Dolet Hills mine are expected to be sufficient to fuel the Dolet Hills Power Station until at least 2026. Cleco Power’s investment in the acquisition was $12.9 million. For information regarding deferred mining costs and obligations associated with the DHLC mining agreement see, Part II, Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 3 — Regulatory Assets and Liabilities — Deferred Mining Costs” and Note 15 — “Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Off-Balance Sheet Commitments and Disclosures about Guarantees.”

The continuous supply of coal and lignite may be subject to interruption due to adverse weather conditions or other factors that may disrupt mining operations or transportation to the plant site. At December 31, 2009, Cleco Power’s coal inventory at Rodemacher Unit 2 was approximately 290,000 tons (about a 132-day supply), and Cleco Power’s lignite inventory at Dolet Hills was approximately 155,000 tons (about a 26-day supply).

Natural Gas Supply

During 2009, Cleco Power purchased a total of 19,614,753 MMBtu of natural gas for the generation of electricity. The annual and average per-day quantities of gas purchased by Cleco Power from each supplier are shown in the table below.

NATURAL GAS SUPPLIER	2009 PURCHASES (MMBtu)	AVERAGE AMOUNT PURCHASED PER DAY (MMBtu)	PERCENT OF TOTAL NATURAL GAS USED
Tenaska Marketing Ventures	1,988,906	5,400	10.1%
Noble Gas	1,985,119	5,400	10.1%
BP Energy	1,835,270	5,000	9.4%
Eagle Energy Partners	1,709,576	4,600	8.7%
Gavilon, LLC	1,618,303	4,400	8.3%
Pacific Summit Energy	1,530,700	4,200	7.8%
Others	8,946,879	25,000	45.6%
Total	19,614,753	54,000	100.0%

Cleco Power owns the natural gas pipelines and interconnections at its Rodemacher and Teche power stations. This allows it to access various natural gas supply markets, which helps to maintain a more economical fuel supply for Cleco Power’s customers.

Natural gas was available without interruption throughout 2009. Cleco Power expects to continue to meet its natural gas requirements with purchases on the spot market through daily, monthly, and seasonal contracts with various natural gas suppliers. However, future supplies to Cleco Power remain vulnerable to disruptions due to weather events and transportation delays. Large industrial users of natural gas, including electric utilities, generally have low priority among gas users in the event pipeline suppliers are forced to curtail deliveries due to inadequate supplies. As a result, prices may increase rapidly in response to temporary supply interruptions. Although prices may increase rapidly, Cleco Power enters into economic hedge positions to mitigate the volatility in fuel costs as encouraged by an LPSC order. For additional information on these economic hedge positions, see Item 1A, “Risk Factors — Hedging and Risk Management Activities” and Part II, Item 7A, “Quantitative and Qualitative Disclosures about Market Risk — Commodity Price Risks.” Currently, Cleco Power anticipates that its diverse supply options and alternative fuel capability, combined with its solid-fuel generation resources, are adequate to meet its fuel needs during any temporary interruption of natural gas supplies.

Fuel Oil Supply

Cleco Power stores fuel oil as an alternative fuel source at its Rodemacher and Teche power stations. The Rodemacher Power Station has storage capacity for an approximate 95-day supply, and the Teche power station has storage capacity for an approximate 28-day supply. However, in accordance with Cleco Power’s current fuel oil inventory practices, Cleco Power had approximately an 89-day supply of fuel oil stored at its Rodemacher facility and a 16-day supply at its Teche facility at December 31, 2009. During 2009, no fuel oil was purchased or burned.

Sales

Cleco Power’s 2009 and 2008 system peak demands, which occurred on July 2, 2009, and July 28, 2008, were 2,242 MW and 2,113 MW, respectively. Sales and system peak demand are affected by weather and are typically highest during the summer air-conditioning season. In 2009 and 2008, Cleco Power experienced above-normal summer weather and mild

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CLECO POWER	2009 FORM 10-K

winters. For information on the effects of future energy sales on Cleco Power’s financial condition, results of operations, and cash flows, see Item 1A, “Risk Factors — Weather Sensitivity” and “— Future Electricity Sales.” For information on the financial effects of seasonal demand on Cleco Power’s quarterly operating results, see Part II, Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 22 — Miscellaneous Financial Information (Unaudited).”

Capacity margin is the net capacity resources (either owned or purchased) less native load demand divided by net capacity resources. Each year, members of the SPP submit forecasted native load demand and the forecasted mix of net capacity resources to meet this demand. During 2009, Cleco Power’s capacity margin was 11.7%, which is below the SPP’s capacity benchmark of 12.0%, primarily due to higher than expected native load demand. Cleco Power’s capacity margin was 12.8% in 2008. Cleco Power expects to meet the SPP’s capacity benchmark of 12.0% with the addition of 580 MW from the Acadia plant and 600 MW from Rodemacher Unit 3.

Midstream

Summary financial results of the Midstream segment for 2009, 2008, and 2007 are presented below.

(THOUSANDS)	2009			2008			2007
Revenue
Other operations	$	1		$	1		$	16
Affiliate revenue		8,748			7,920			5,050
Operating revenue, net	$	8,749		$	7,921		$	5,066
Depreciation expense	$	177		$	307		$	306
Interest charges	$	7,408		$	6,978		$	19,053
Interest income	$	-		$	-		$	1,047
Equity (loss) income from investees	$	(19,339	)	$	(7,037	)	$	91,581
Federal and state income tax (benefit) expense	$	(11,027	)	$	(7,182	)	$	36,585
Segment (loss) profit	$	(17,730	)	$	(10,017	)	$	59,317
Additions to long-lived assets	$	55		$	64		$	10
Equity investment in investees	$	223,652		$	234,273		$	249,758
Total segment assets	$	270,713		$	250,882		$	265,918

As of December 31, 2009, Midstream wholly and directly owned four active limited liability companies that operated mainly in Louisiana.

§	Evangeline, which owns and operates a combined-cycle natural gas-fired power plant.

§	APH, which owned 50% of Acadia, a combined-cycle natural gas-fired power plant.

§	Generation Services, which offers power station operations and maintenance services. Its customers are Evangeline and Acadia.

§	CLE Intrastate, which owns a natural gas interconnection that allows Evangeline to access the natural gas supply market.

The following table sets forth certain information with respect to Midstream’s operating generating facilities.

GENERATING STATION	GENERATING UNIT #	COMMENCEMENT OF COMMERCIAL OPERATION	NAME PLATE CAPACITY (MW)	NET CAPACITY (MW)	TYPE OF FUEL USED FOR GENERATION
Evangeline	6	2000	264	258(1)	natural gas
	7	2000	511	497(1)	natural gas
Acadia	1	2002	290(2)	290(3)	natural gas
	2	2002	290(2)	291(4)	natural gas
Total capacity			1,355	1,336
(1) Based on capacity testing of generating units performed in June 2009. (2) Represents APH’s 50% ownership interest in the capacity of Acadia. (3) Based on capacity testing of generating unit performed in August 2009. (4) Based on capacity testing of generating unit performed in September 2009.

Midstream competes against regional and national companies that own and operate merchant power stations.

Evangeline’s capacity is currently dedicated to one customer, JPMVEC. On February 22, 2010, Evangeline and JPMVEC terminated the existing Evangeline Tolling Agreement which was set to expire in 2020 and entered into the Evangeline 2010 Tolling Agreement, effective March 1, 2010. The new tolling agreement is an exclusive, market-based tolling agreement for Evangeline’s generating Units 6 and 7, expiring December 31, 2011, with an option for JPMVEC to extend the term of the agreement through December 31, 2012. The tolling agreement gives the tolling counterparty the right to own, dispatch, and market all of the electric generation capacity of the respective facility. Under a tolling agreement, the tolling counterparty is responsible for providing its own natural gas to the facility and pays a fixed fee and a variable fee for operating and maintaining the respective facility. JPMorgan Chase & Co. guaranteed JPMVEC’s obligations under the Evangeline Tolling Agreement and also is guaranteeing JPMVEC’s obligations under the Evangeline 2010 Tolling Agreement. For additional information on the Evangeline transactions, see Part II, Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 23 — Subsequent Events — Evangeline Transactions.”

During 2009, Acadia executed definitive agreements with both Cleco Power and Entergy Louisiana whereby Cleco Power and Entergy Louisiana would each purchase one 580-MW unit of the Acadia plant. In January 2010, Acadia began serving Cleco Power under a tolling agreement covering 50% of the Acadia Power Station. In February 2010, the Cleco Power transaction was completed and Cleco Power now owns one unit at Acadia and operates the Acadia Power Station. The transaction with Entergy Louisiana is expected to be completed in late 2010 or early 2011. Beginning in May 2010, Acadia will serve Entergy Louisiana under a tolling agreement covering 50% of the Acadia plant until the sale to Entergy Louisiana is completed. Until May 2010, this portion of Acadia’s output is being sold through an energy management services agreement with a third party marketer. For additional information on the above tolling agreements and related transactions, risks and uncertainties, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Results of Operations — Midstream —

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CLECO POWER	2009 FORM 10-K

Significant Factors Affecting Midstream — Earnings are primarily affected by the following factors.” For additional information on Acadia’s transactions with Cleco Power and Entergy Louisiana, the Calpine bankruptcy, and the suspension of the Calpine Tolling Agreements, see Part II, Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 15— Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Acadia Transactions,” Note 20 — “Calpine Bankruptcy Settlement,” and Note 23 — “Subsequent Events — Acadia Transaction.”

CLE Intrastate’s revenue is generated primarily from a monthly reservation fee paid by Evangeline for access to the Columbia Gulf interconnect and from a transportation fee that varies depending on the amount of gas transported through the interconnect for use by Evangeline.

At December 31, 2009, Midstream and its subsidiaries had 64 employees: 62 within Generation Services and 2 at Midstream.

For additional information on Midstream’s operations, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Results of Operations — Midstream.”

Customers

No single customer accounted for 10% or more of Cleco’s consolidated revenue or Cleco Power’s revenue in 2009, 2008, or 2007. For additional information regarding Cleco’s sales and revenue, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Results of Operations.”

Construction and Financing

For information on Cleco’s construction program, financing and related matters, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Cash Generation and Cash Requirements.”

REGULATORY MATTERS, INDUSTRY DEVELOPMENTS, AND FRANCHISES

Rates

Cleco Power’s electric operations are subject to the jurisdiction of the LPSC with respect to retail rates, standards of service, accounting and other matters. Cleco Power also is subject to the jurisdiction of FERC with respect to rates for wholesale service, accounting, interconnections with other utilities, and the transmission of power and reliability. Periodically, Cleco Power has sought and received from both the LPSC and FERC increases in base rates to cover increases in operating costs and costs associated with additions to generation, transmission, and distribution facilities.

Cleco Power’s electric rates include a fuel and purchased power cost adjustment clause that enables it to adjust rates for monthly fluctuations in the cost of fuel and purchased power. Revenue from certain off-system sales to other utilities and energy marketing companies is passed on to customers through a reduction in fuel cost adjustment billing factors. Recovery of fuel adjustment clause costs is subject to refund until monthly approval is received from the LPSC; however, all amounts are subject to a periodic fuel audit by the LPSC. The LPSC Fuel Adjustment Clause General Order issued November 6, 1997, in Docket No. U-21497 provides that an audit will be performed not less than every other year. Cleco Power currently has fuel adjustment clause filings for 2003 through 2008 subject to audit. In July 2006, the LPSC informed Cleco Power that it was planning to conduct a periodic fuel audit that included fuel adjustment clause filings for the period January 2003 through December 2004. In March 2009, the LPSC indicated its intent to proceed with the audit for the years 2003 through 2008. The total amount of fuel expenses included in the audit is approximately $3.2 billion. The audit is expected to proceed in the first quarter of 2010. Cleco Power could be required to make a substantial refund of previously recorded revenue as a result of these audits, and such refund could result in a material adverse effect on the Registrants’ results of operations, financial condition, and cash flows.

In July 2006, Cleco Power’s current RSP with the LPSC, which governs its retail regulatory return on equity, was extended with modifications to certain terms until the commercial operation date of Rodemacher Unit 3, which was on February 12, 2010. During 2006, the LPSC approved the recovery of a portion of the carrying costs of capital associated with the construction of Rodemacher Unit 3. Also during 2006, the LPSC approved an interim rate increase to recover storm restoration costs incurred by Cleco Power relating to Hurricanes Katrina and Rita. In March 2007, after completing a review of the restoration costs, Cleco Power and the LPSC Staff filed a settlement agreement allowing recovery of $158.0 million, essentially all of Cleco Power’s Hurricanes Katrina and Rita storm costs. The agreement also authorized the issuance of securitized bonds to finance the restoration costs. The collection of a special storm recovery charge from Cleco Power’s customers will securitize the bonds. The LPSC approved the settlement agreement and issued a securitization financing order in September 2007. In March 2008, the securitization financing was completed, collection of the interim surcharge ceased, and the right to bill and collect unamortized storm damage costs from customers was sold to Cleco Katrina/Rita, a special purpose, wholly owned subsidiary of Cleco Power.

In July 2009, the LPSC issued Docket No. U-29380 Subdocket A, which provides for an Environmental Adjustment Clause to recover certain costs of environmental compliance as an adder to the customers’ bills. The costs eligible for recovery are prudently incurred air emissions credits associated with complying with federal, state, and local air emission regulations that apply to the generation of electricity reduced by sale of such allowances. Also eligible for recovery are variable emission mitigation costs, which are the cost of reagents such as ammonia and limestone that are used to reduce air emissions. These variable emission mitigation costs were historically recovered through the Fuel Adjustment Clause.

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CLECO POWER	2009 FORM 10-K

For additional information on Cleco Power’s retail and wholesale rates, including Cleco Power’s RSP, see Item 1A, “Risk Factors — Fuel Cost Audits,” “— Retail Electric Service,” “— Wholesale Electric Service,” and “— Cleco Power’s Rates” and Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Regulatory Matters — Retail Rates of Cleco Power,” and — “Wholesale Rates of Cleco.”

Cleco Power’s Rate Case

In July 2008, Cleco Power filed a request with the LPSC for a new rate plan to increase its base rates for electricity. Cleco Power sought recovery of revenues sufficient to cover the addition of Rodemacher Unit 3 to its existing expense and rate base levels. Cleco Power and the LPSC Staff filed testimony in support of an uncontested stipulated settlement in September 2009.

In October 2009, the LPSC voted unanimously to approve the retail rate plan for Cleco Power. The retail rate plan became effective upon the commercial operation of Rodemacher Unit 3, which occurred on February 12, 2010.

The retail rate plan is expected to increase retail base revenues, in the first twelve months of Rodemacher Unit 3 commercial operations, by approximately $173.0 million with an anticipated net billing decrease for retail customers of approximately $40.0 million, or 5.0% (assuming a gas price of $5/MMBtu), including a reduction of approximately $97.0 million resulting from the cessation of the collection and the refund of Rodemacher Unit 3 construction financing based on a five-year crediting period. The retail rate plan also provides for the recovery of other costs including costs associated with damage caused by Hurricanes Gustav and Ike.

The retail rate plan includes a Formula Rate Plan (FRP) that has a target return on equity of 10.7%, including returning to retail customers 60.0% of retail earnings between 11.3% and 12.3% and all retail earnings over 12.3%. The capital structure assumes an equity ratio of 51.0%. The FRP also has a mechanism allowing for recovery of future revenue requirements for the Acadiana Load Pocket transmission project and the acquisition of 50% of the Acadia Power Station, or one of its two 580-MW units. The retail rate plan allows Cleco Power to propose additional capital projects for inclusion in the FRP to the LPSC during the FRP’s initial four-year term.

Franchises

Cleco Power operates under nonexclusive franchise rights granted by governmental units, such as municipalities and parishes (counties), and enforced by state regulation. These franchises are for fixed terms, which may vary from 10 years to 50 years or more. In the past, Cleco Power has been substantially successful in the timely renewal of franchises as each neared the end of its term. Cleco Power’s next municipal franchise expires in 2011.

Renewed Franchises

Cleco Power renewed the following franchise agreements during 2009. No franchises were renewed in 2008.

DATE	CITY	TERM	NUMBER OF CUSTOMERS
January 2009	Coushatta	30 years	1,400
May 2009	Bunkie	27 years	2,200
May 2009	Abita Springs	25 years	710
July 2009	Simmesport	28 years	1,200
September 2009	Mansfield	30 years	2,700

Other Franchise Matters

In July 2009, the City of Opelousas notified Cleco Power that it would begin formally requesting proposals from other power companies to supply its electricity needs. The current agreement is set to expire in August 2011. In November 2009, the City of Opelousas received responses from power companies from which it solicited bids declining its request for proposals to provide power to the City. The Mayor formed a citizens committee to determine if the City of Opelousas should operate its power system or continue the operating and franchise agreement with Cleco Power. In December 2009, the City of Opelousas requested an extension under the operating and franchise agreement to perform the review. Cleco Power granted an extension until December 31, 2010. For the twelve-month period ended December 31, 2009, Cleco Power’s base revenue from the City of Opelousas was $8.2 million. Approximately 10,000 customers are located in the City of Opelousas. While the City of Opelousas owns a portion of the power system, Cleco Power has performed upgrades and expansions since May 1991, which was the inception of the operating and franchise agreement. If the operating and franchise agreement is not renewed by the City of Opelousas, the City of Opelousas will be liable to Cleco Power for the cost of the upgrades and expansions of approximately $9.0 million.

Industry Developments

For information on industry developments, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Market Restructuring.”

Wholesale Electric Competition

For a discussion of wholesale electric competition, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Market Restructuring — Wholesale Electric Markets.”

Retail Electric Competition

For a discussion of retail electric competition, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Market Restructuring — Retail Electric Markets.”

Legislative and Regulatory Changes and Matters

Various federal and state legislative and regulatory bodies are considering a number of issues that could shape the future of the electric utility industry. Such issues include, among others:

§	regulation of previously deregulated retail electric markets;

§	the ability of electric utilities to recover stranded costs;

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CLECO POWER	2009 FORM 10-K

§	the role of electric utilities, independent power producers and competitive bidding in the purchase, construction and operation of new generating capacity;

§	the pricing of transmission service on an electric utility’s transmission system;

§	FERC’s assessment of market power and utilities’ ability to buy generation assets;

§	mandatory transmission reliability standards;

§	the authority of FERC to grant utilities the power of eminent domain;

§	increasing requirements for renewable energy sources;

§	comprehensive multi-emissions environmental legislation;

§	regulation of greenhouse gas emissions;

§	FERC’s increased ability to impose financial penalties; and

§	the American Recovery and Reinvestment Act of 2009.

The Registrants are unable, at this time, to predict the outcome of such issues or effects on their financial position, results of operations, or cash flows.

For information on certain regulatory matters and regulatory accounting affecting Cleco, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Regulatory Matters.”

ENVIRONMENTAL MATTERS

Environmental Quality

Cleco is subject to federal, state, and local laws and regulations governing the protection of the environment. Violations of these laws and regulations may result in substantial fines and penalties. Cleco has obtained the environmental permits necessary for its operations, and management believes Cleco is in compliance in all material respects with these permits, as well as all applicable environmental laws and regulations. Environmental requirements continue to increase as a result of new legislation, administrative actions, and judicial interpretations. Therefore, the future effects of existing and potential requirements are difficult to determine. Cleco Power may request recovery from its retail customers of its costs to comply with environmental laws and regulations. If revenue relief were to be approved by the LPSC, then Cleco Power’s retail rates could increase. If the LPSC were to deny Cleco Power’s request to recover all or part of its environmental compliance costs, such a decision could have a material adverse effect on the Registrants’ results of operations, financial condition, and cash flows. Cleco’s capital expenditures related to environmental compliance were $4.9 million during 2009 and are estimated to total $3.0 million in 2010. The following table lists capital expenditures for environmental matters by subsidiary.

SUBSIDIARY (THOUSANDS)	ENVIRONMENTAL CAPITAL EXPENDITURES FOR 2009			PROJECTED ENVIRONMENTAL CAPITAL EXPENDITURES FOR 2010
Cleco Power	$	3,905		$	1,745
Evangeline		920			1,183
Acadia		107	(1)		56	(2)
Total	$	4,932		$	2,984
(1) Represents APH’s 50% portion of Acadia (2) Represents APH’s remaining portion of Acadia subsequent to Cleco Power’s purchase of one 580-MW unit of Acadia

Projected environmental capital expenditures for 2010 are lower than 2009 environmental capital expenditures primarily due to a project that was completed in 2009 related to the EPA’s Spill Prevention Containment and Countermeasure rules and the installation of upgrades to the SO2 system at Cleco Power’s Dolet Hills Power Station that is expected to be completed during 2010.

Air Quality

The state of Louisiana regulates air emissions from each of Cleco’s generating units through the Air Quality regulations of the LDEQ. In addition, the LDEQ has been delegated authority over and implements certain programs established by the EPA. The LDEQ establishes standards of performance and requires permits for certain generating units in Louisiana. All of Cleco’s generating units are subject to these requirements.

The federal CAA established a regulatory program, known as the Acid Rain Program, to address the effects of acid rain and imposed restrictions on SO2 emissions from certain generating units. The federal CAA requires these generating stations to possess a regulatory “allowance” for each ton of SO2 emitted beginning in the year 2000. The EPA allocates a set number of allowances to each affected unit based on its historic emissions. As of December 31, 2009, Cleco Power and Midstream had sufficient allowances for 2009 operations and expect to have sufficient allowances for 2010 operations under the Acid Rain Program.

The Acid Rain Program also established emission rate limits on NOx emissions for electric generating units (EGUs). Cleco Power’s low NOx burner project was installed in 2006 to achieve compliance with the reduced acid rain permit limits for NOx at Dolet Hills. With its low NOx burner project completed, Rodemacher Unit 2 is able to achieve compliance with the Acid Rain NOx limits by a greater margin. Significant future reductions in NOx emissions limits may require additional capital improvements at one or both of the units.

NOx emissions from the Evangeline and Acadia generating units are within the units’ respective permitted limits, as these units use modern turbine and selective catalytic reduction technology that reduces NOx emissions to low levels.

On March 10, 2005, the Clean Air Interstate Rule (CAIR) was finalized by the EPA. CAIR covered the District of Columbia and 28 eastern states, including Louisiana, and provides a federal framework requiring states to reduce emissions of SO2 and NOx via a cap-and-trade emission reduction program. CAIR called for NOx reductions to begin in the year 2009 and SO2 reductions in 2010. Louisiana promulgated state regulations to incorporate these federal

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requirements. The federal rule has been heavily litigated by multiple parties in the case known as North Carolina vs. EPA. On July 11, 2008, the U.S. Court of Appeals for the D.C. Circuit vacated the CAIR rule in its entirety. Then, after rehearing the case, the D.C. Circuit Court on December 23, 2008 reinstated the CAIR rule and directed the EPA to conduct further proceedings consistent with the Court’s opinion in the case. The Court determined that, notwithstanding the flaws of CAIR, remanding it to the EPA without vacature was preferable in that it preserved the environmental benefits of the rule. As a result, CAIR went into effect in its entirety on January 1, 2009 and will remain in effect until the EPA re-writes the rule to address the flaws identified by the Court in the initial CAIR rule. The EPA does not have a specified timeframe to complete the new rule, however, Cleco expects the EPA to propose a replacement rule in early 2010 with a final rule completed in early 2011. At this time, Cleco cannot determine what the new rule requirements will entail, to what extent compliance costs would be increased, or what level of capital expenditures would be required to comply with the new rule. Cleco had previously evaluated potential compliance strategies to meet the emission reductions contemplated by the initial CAIR regulations. The installation of new low NOx burners and enhancements to the SO2 scrubber at Dolet Hills were expected to be an integral part of meeting the CAIR NOx and SO2 reduction provisions. Likewise, the installation of the new low NOx burners at Rodemacher Unit 2 in 2008 will help meet CAIR NOx reduction requirements. Cleco will rely on its previous compliance strategy to meet the current CAIR requirements and also may include additional emission controls, purchase of allowances, or fuel changes to enhance its compliance, if warranted.

On March 15, 2005, the EPA issued final rules regarding mercury emissions from electric utility boilers known as the federal Clean Air Mercury Rule (CAMR). CAMR established “standards of performance” limiting mercury emissions from new and existing coal-fired power plants and created a market-based cap-and-trade program. However, on February 8, 2008, the U.S. Court of Appeals for the D.C. Circuit in New Jersey v. EPA, vacated both the EPA’s rule delisting coal- and oil-fired EGUs from regulation under Section 112 of the CAA and the entire CAMR rule. Since the Supreme Court denied industry petitions to review the appeals court decision, CAMR is officially vacated. EGUs are subject to regulation under Section 112, which will require the EPA to promulgate maximum achievable control technology (MACT) standards for hazardous air pollutants for coal- and oil-fired EGUs.

The EPA is now moving forward to set MACT standards for these units which will require that: 1) new sources must adopt at minimum “the emission control that is achieved in practice by the best controlled similar source, as determined by the Administrator” and 2) existing sources must adopt emission controls equal to the “average emission limitation achieved by the best performing 12 percent of the existing source.” The EPA is requiring certain coal- and oil-fired facilities to perform stack testing to help determine what these emission rates will be for the best performing 12 percent of existing sources. The EPA has entered into a consent decree with various environmental groups which require them to promulgate proposed MACT standards for EGUs by March 2011 and final standards by November 2011. Typically, the EPA allows three years after promulgating a final rule for the regulations to become effective. These new standards will likely contain emission limits not only for mercury but for other hazardous air pollutants.

On January 7, 2009, the EPA issued guidance directing state permitting authorities to make case-by-case MACT determinations, consistent with the requirements of Section 112(g) of the CAA, for coal- and oil-fired EGUs that began actual construction or reconstruction between March 29, 2005 and March 14, 2008. Rodemacher Unit 3 is a unit that began construction between the dates in question, and was permitted as a “minor source” within the context of what constitutes hazardous air pollutants under Section 112(g) rules. Cleco does not believe that case-by-case MACT applies to Rodemacher Unit 3 and on March 18, 2009, Cleco received a letter from the LDEQ concurring with its position. The LDEQ is ultimately responsible for making a determination regarding the applicability of case-by-case MACT to Rodemacher Unit 3. As such, Dolet Hills and Rodemacher Units 2 and 3 should all be treated as existing units under the new MACT rules once they are finalized.

Congress continues to consider various climate related bills that require the reduction of greenhouse gases (GHG) by emission sources in the U.S. On June 26, 2009, the U.S. House of Representatives voted 219-212 to pass the American Clean Energy and Security Act of 2009 (ACES). The bill includes an economy-wide GHG cap-and-trade program that requires a reduction in GHG emissions from major U.S. sources of 17% by 2020 and 83% by 2050 compared to 2005 levels. The bill also imposes a renewable electricity standard for utilities of up to 20% by 2020, and addresses other issues such as energy efficiency, carbon capture and sequestration and performance standards for new coal units permitted after 2009. Under ACES, approximately 80% of emission allowances would be freely allocated during the early years of the cap-and-trade program. Over time, however, a greater percentage of allowances would be auctioned, eventually requiring full auctions after 2030. Members of the Senate are also considering climate change legislation. The Senate Environment and Public Works Committee passed the Kerry-Boxer bill out of committee in November 2009. This bill mirrors the ACES legislation passed by the House but has a stricter GHG reduction target by 2020. Each of the current bills being considered, if enacted, could potentially have a material adverse effect on the Registrants’ results of operations, financial condition, and cash flows. Similar material effects would also potentially be realized by other companies in the electric generating industry that rely heavily on fossil fuels to produce electricity. Moreover, it is unclear when, if ever, climate change legislation that includes a cap on greenhouse gas emissions will be enacted by the federal government, and if enacted, what the specific provisions of the legislation will be and when such provisions will take effect.

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In addition to Congress considering climate change legislation, the EPA has initiated actions toward regulating GHG under the existing CAA. In December 2009, the EPA promulgated its long-awaited endangerment finding. The Agency’s finding states that elevated atmospheric concentrations of six GHG, which include carbon dioxide, methane, nitrous oxide, hydrofluorocarbons, perfluorocarbons, and sulfur hexafluoride, are contributing to climate change. Although the endangerment finding technically is being made in the context of GHG emissions from new motor vehicles, the finding will trigger GHG regulation of a variety of mobile and stationary sources under the CAA. The first GHG regulation that the EPA will issue will be its light-duty motor vehicle GHG regulation, which Cleco expects will be issued by March 2010. This regulation is being issued jointly with the Department of Transportation and primarily requires improvements in fuel economy for automobiles and light duty trucks beginning in Model Year 2012. The EPA states that once the motor vehicle GHG regulations become effective, which Cleco expects to be in May or June of 2010, GHG will be considered regulated pollutants under the Prevention of Significant Deterioration (PSD) air quality permit program. As a result, new major stationary sources of GHG emissions, and modifications of existing major stationary sources that significantly increase their GHG emissions will be required to obtain a permit setting forth Best Available Control Technology (BACT) for those emissions. At this time, BACT has not been defined for these major stationary sources. Both the EPA and businesses in general have a high level of concern for how BACT will be determined and that a very large number of sources could be required to obtain PSD permits for their GHG emissions when GHG become regulated pollutants. As a result, to avoid grid-locking the PSD permit system, the Agency has proposed a “tailoring rule” designed to limit applicability of the PSD program to only the largest GHG emitters, at least for an initial five-year period. Under the tailoring rule, major sources to which PSD requirements for GHG would become applicable would be those that emit more than 25,000 tons per year of CO2 equivalent, and a significant increase of GHG emissions from a modification would be defined at a level between 10,000 and 25,000 tons per year. The tailoring rule would also set a 25,000-ton per year threshold under the Title V operating permit program. The legality of the tailoring rule has been questioned because the CAA explicitly defines the PSD major source threshold as 100 tons per year for sources in 28 industrial categories and 250 tons per year for sources in all other categories, and the Title V threshold at 100 tons per year. Regulations adopted by the EPA could potentially have a material adverse effect on the Registrants’ results of operations, financial condition, and cash flows. For example, Cleco may be required to obtain authorization for greenhouse gas emissions from all new and modified facilities in PSD and Title V permits, or upon renewal of such permits for existing facilities. Such facilities may be required to meet then-current BACT requirements, which could potentially have a material adverse effect on the Registrants’ results of operations, financial condition, and cash flows. However, at this time, due to several factors including the anticipated legal challenges to various EPA greenhouse gas rules, it is unclear when, if ever, such rules would be finalized and if finalized, when relevant rule provisions would become effective. Uncertainty as to whether EPA rules and/or federal legislation regulating greenhouse gases will become effective complicates Cleco’s decision-making process for modifying existing facilities or adding new power generating facilities.

The enactment of federal or state renewable portfolio standards (RPS) mandating the use of renewable and alternative fuel sources, such as wind, solar, biomass and geothermal, could result in certain changes in Cleco’s business or its competitive position. These changes could include costs for renewable energy credits, alternate compliance payments, or capital expenditures for renewable generation resources. RPS legislation has been enacted in many states and Congress could continue to pursue legislation to create a national RPS. States such as Louisiana that do not have RPS requirements could adopt such requirements in the future or be subject to federal RPS requirements. Cleco continues to evaluate the impacts of potential RPS legislation on its businesses based on the RPS programs in other states. Cleco will continue to monitor developments related to RPS at the federal and state levels.

On March 12, 2008, the EPA set new National Ambient Air Quality Standards (NAAQS) for Ozone; the new primary 8-hour ozone standard is set at 0.075 parts per million (ppm) and the new secondary standard at a form and level identical to the primary standard. The previous primary and secondary standards were each effectively set at 0.084 ppm. The previous standard was set in 1997 and Louisiana had five parishes in the Baton Rouge area that had not yet attained compliance with the standards. In March 2009, the LDEQ made its initial “non-attainment” designations to the EPA under the 2008 ozone standards. This designation added several parishes in Louisiana designated as “non-attainment” with the 2008 ozone NAAQS standards. Cleco has no generating facilities in any of the newly designated or existing non-attainment parishes. The state was to make the initial designations by June 2009, final designations by 2010 and by 2012-2013, promulgate regulations on how Louisiana would comply. However, on January 7, 2009, the EPA proposed to set the primary standard, which protects public health, at a level between 0.060 and 0.070 ppm measured over eight hours. The EPA is also proposing to set a separate secondary standard to protect the environment, especially plants and trees. The Agency is expected to issue a final decision on revising the standards by August 2010. Since NOx emissions are a precursor to ozone formation, existing fossil fuel-fired units located in or near these newly designated ozone non-attainment areas that do not currently utilize best available control technology could be targeted for installation of additional NOx emission controls.

In February 2005, Cleco Power received notices from the EPA requesting information relating to the Rodemacher and Dolet Hills Power Stations. The apparent purpose of the investigation is to determine whether Cleco Power has complied with New Source Review and New Source Performance

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Standards requirements under the CAA in connection with capital expenditures, modifications, or operational changes made at these facilities. Cleco Power has completed its response to the initial data request. It is unknown at this time whether the EPA will take further action as a result of the information provided by Cleco Power.

On March 19, 2008, Cleco Power received a consolidated compliance order and notice of potential penalty (CO/NOPP) from the LDEQ for alleged violations of the air quality rules at its Dolet Hills and Rodemacher Power Stations. For Dolet Hills, the CO/NOPP alleges that upon a file review conducted on or about February 26, 2008, the LDEQ found that Cleco Power was in violation of conditions in its Title V permit regarding compliance assurance tests to be conducted upon its continuous monitoring systems. Upon review of the LDEQ findings and the Part 75 regulations, Cleco Power contends that the actions taken were allowed under the Part 75 regulations, as well as the Title V permit. In regard to the Rodemacher Power Station alleged violations, the CO/NOPP states that a file review of the Rodemacher facility was conducted on or about September 14, 2007, and that upon the agency’s review of the Quarterly Stack Emissions Reports required under 40 CFR Part 60 submitted by Cleco Power, the LDEQ found that Rodemacher Unit 2 exceeded opacity limits at various times during the second, third and fourth quarters of 2007. On December 29, 2009, Cleco and the LDEQ entered into a settlement agreement whereby the parties agreed to settle the enforcement matter for approximately $23,000 and the matter is now closed.

On September 3, 2009, Dolet Hills Power Station received a notice from EPA Region 6, alleging that the facility may be in violation of the Accident Prevention requirements of Section 112 (r)(7) of the CAA and the Chemical Accident Prevention provisions in 40 CFR Part 68. The EPA claims that the facility may have been required to have a risk management plan (RMP) for the chemical anhydrous ammonia, which is used and stored on site. The EPA alleges that Dolet Hills exceeded the threshold quantity of 10,000 pounds of anhydrous ammonia in a single process, which triggers the requirement to have such a plan in place. The EPA made this claim after a review of their Central Data Exchange, which includes information submitted to the EPA in the Toxic Release Inventory. In the notice, the EPA has offered to settle the matter, which would include the payment of a non-negotiable penalty of $145,802 and the correction of the alleged deficiencies. Cleco Power contends that Dolet Hills employed administrative controls to limit the quantity of ammonia stored to less than 10,000 pounds which was sufficient to exempt the facility from the RMP program requirements. Cleco Power provided the EPA with documentation supporting its position, the EPA has determined that Cleco is in compliance and the matter is closed.

Water Quality

Cleco has received from the EPA and the LDEQ permits required under the federal Clean Water Act for waste water discharges from its five generating stations. Waste water discharge permits have fixed dates of expiration, and Cleco applies for renewal of these permits within the applicable time periods.

The LDEQ issued a Louisiana Pollutant Discharge Elimination System (LPDES) waste water permit renewal for Evangeline Power Station on June 22, 2006. This waste water permit contained certain additional Copper and Total Dissolved Solids (TDS) permit limitations that Cleco contended were beyond the legal authority of the LDEQ to include in the waste water permit. Cleco challenged these permit provisions by filing a de novo review judicial appeal on September 26, 2006, in district court in East Baton Rouge Parish, Louisiana. The appealed Copper and TDS permit limitations were stayed during litigation. The uncontested portions of the Evangeline waste water permit were effective January 1, 2007. During the litigation, Cleco and the LDEQ were actively engaged in settlement discussions regarding the appealed provisions of the waste water permit. In December 2008, Cleco filed an application with the LDEQ modifying its LPDES permit to incorporate new Copper and TDS discharge limitations that were agreed to by both parties. On August 27, 2009, the LDEQ issued a modified water permit with the agreed upon Copper and TDS limits which the facility expects to be able to meet. The effective date of the modified permit is October 1, 2009. The modified permit resolves the issues on appeal, and the matter is now closed.

On May 1, 2009, the Acadia Power Station became subject to certain daily maximum and monthly average discharge limitations for total sulfate under the terms of LPDES Water Discharge Permit No. LA0112836, issued by the LDEQ in April 2006. The facility was unable to achieve compliance with these discharge limitations and received a compliance order from the LDEQ on July 31, 2009 to address the total sulfate violations. In that compliance order, the LDEQ also noted violations of various daily maximum temperatures and whole effluent toxicity limits. The LDEQ also found that Acadia had previously corrected and resubmitted discharge monitoring reports for four months in 2007, which the LDEQ contends are not timely submittals. The LDEQ included these violations as well as the total sulfate violations in the compliance order. Acadia believes that the total sulfate limits in the LPDES permit were erroneously low and as such applied for a permit modification to increase the total sulfate limitations in the permit. Acadia has now received a modified water discharge permit from the LDEQ which contains increased total sulfate limitations that can be met by the facility. Acadia is operating in compliance with and under the terms of the modified LPDES permit and has requested that the LDEQ close the compliance order. However, the LDEQ does have the ability to seek enforcement action on the violations of the water discharge permit limits experienced prior to the receipt of the water discharge permit modification. For each of the violations described above, the LDEQ has the right to seek civil penalties. At this time, Acadia is unable to determine whether the LDEQ will pursue any civil penalties as part of this enforcement action or what the penalty amounts will be.

In 2004, the EPA promulgated Phase II of Section 316(b) of the Clean Water Act which regulates potential adverse

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environmental impacts to all aquatic species due to water intake structures. These regulations establish requirements applicable to the location, design, construction, and capacity of cooling water intake structures. This section of the rule is applicable to Cleco’s Teche and Evangeline Power Stations. The 2004 rule was immediately challenged by a coalition of environmental groups and six states. In 2007, the U.S. Court of Appeals for the Second Circuit ruled that some of the provisions of the rule were unlawful and remanded the rule to the EPA for re-consideration. Most importantly, the Court concluded that the approach used by the EPA to eliminate closed cycle cooling as the best technology available for minimizing adverse environmental impacts for cooling water intake structures was not clear and potentially based on unlawful consideration of the closed cycle cooling costs relative to its benefits. Industry appealed the Second Circuit decision on whether the EPA could consider technology costs relative to its benefits to the U.S. Supreme Court and in April 2009 the U.S. Supreme Court overturned the lower court’s ruling and ruled that the EPA does have the discretion to consider costs relative to benefits in developing cooling water intake structure regulations under this rule. The decision gives the EPA the option to retain substantial features of its July 2004 “Phase II” final rule, which set reasonable national performance standards for existing electric generating facilities, while also allowing variances based on cost-benefit considerations. The EPA has indicated that it plans to propose a revised Phase II rule by late 2010 and a final rule some time in 2012. Until the EPA promulgates a replacement Phase II rule, the EPA has indicated that it will ask permit writers to use “Best Professional Judgment” in evaluating permit renewals until a new 316(b) rule is promulgated. At this time, it is uncertain which technology option, if any, will be required to be installed on Cleco’s intake structures and the associated costs of those modifications.

Solid Waste Disposal

The Solid Waste Division of the LDEQ has adopted a permitting system for the management and disposal of solid waste generated by power stations. Cleco has received all required permits from the LDEQ for the on-site disposal of solid waste from its generating stations. Cleco has renewed the solid waste permits for the existing Rodemacher and Dolet Hills solid waste units and is in the process of upgrading them according to the current Solid Waste Regulations and permit requirements. These upgrades are not expected to result in substantial costs.

A catastrophic event involving coal ash at the Tennessee Valley Authority’s coal ash management impoundment in Kingston, Tennessee has prompted closer scrutiny by the EPA of coal ash management facilities at coal-fired power plants across the country. Cleco Power, like most utilities with coal-fired units, received a formal request, to which it has fully responded, for information under Section 104(e) of the Comprehensive Environmental Response, Compensation, and Liability Act (RCRA) regarding the safety and structural integrity of its coal ash management units. After reviewing the data collected, the EPA has indicated its preference to listing coal combustion by-products, including fly ash, bottom ash, boiler slag, and flue gas desulfurization solids (including synthetic gypsum), as RCRA Subtitle C hazardous wastes. Regulating coal ash as a Subtitle C hazardous waste could have significant impacts on Cleco’s coal ash management units at its Rodemacher and Dolet Hills Power Stations. Cleco expects the EPA to propose new coal ash management rules in early 2010. Due to the uncertainty of the content of the proposed rule, Cleco cannot quantify or estimate the cost impacts such a rule might have on its operations. However, any new, stricter requirements imposed on coal ash and associated management units by the EPA as a result of this new rule could significantly increase the cost of operating existing units or require them to be upgraded. These proposed rules could also thwart the beneficial reuse of the material that Cleco currently enjoys. At this time, management is unable to determine whether the costs associated with potential stricter requirements will have a material adverse effect on the Registrants’ results of operations, financial condition, and cash flows.

Hazardous Waste Generation

Cleco produces certain wastes that are classified as hazardous at its five generating stations and at other locations. Cleco does not treat, store long-term, or dispose of these wastes on-site; therefore, no permits are required. All hazardous wastes produced by Cleco are properly disposed of at federally permitted hazardous waste disposal sites.

Toxic Substances Control Act (TSCA)

The TSCA directs the EPA to regulate the marketing, disposal, manufacturing, processing, distribution in commerce, and use of PCBs. Cleco may continue to operate equipment containing PCBs under the TSCA. Once the equipment reaches the end of its usefulness, the EPA regulates handling and disposal of the equipment and fluids containing PCBs. Within these regulations, the handling and disposal is allowed only through the EPA approved and permitted facilities. Cleco properly disposes its PCB waste material at TSCA permitted disposal facilities.

Toxics Release Inventory (TRI)

The TRI requires an annual report from industrial facilities on about 650 substances that the facilities release into air, water, and land. The TRI ranks companies based on how much of a particular substance they release on a state and parish (county) level. Annual reports are due to the EPA on July 1 following the reporting year-end. Cleco has submitted required TRI reports on its activities, and the TRI rankings are available to the public. The rankings do not result in any federal or state penalties.

Electric and Magnetic Fields (EMFs)

The possibility that exposure to EMFs emanating from electric power lines, household appliances, and other electric devices may result in adverse health effects or damage to the environment has been a subject of some public attention. Cleco

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Power funds scientific research on EMFs through various organizations. To date, there are no definitive results, but research is continuing. Lawsuits alleging that the presence of electric power transmission and distribution lines has an adverse effect on health and/or property values have arisen in several states. Cleco Power is not a party in any lawsuits related to EMFs.

Other

In October 2007, Cleco received a Special Notice for Remedial Investigation and Feasibility Study from the EPA. The special notice requested that Cleco Corporation and Cleco Power, along with many other listed PRPs, enter into negotiations with the EPA for the performance of a Remedial Investigation and Feasibility Study at an area known as the Devil’s Swamp Lake just northwest of Baton Rouge, Louisiana. The EPA has identified Cleco as one of many companies sending PCB wastes for disposal to the site. The Devil’s Swamp Lake site has been proposed to be added to the National Priorities List (NPL) based on the release of PCBs to fisheries and wetlands located on the site. The EPA has yet to make a final determination on whether to add Devil’s Swamp Lake to the NPL. The EPA and a number of PRPs met in January 2008 for an organizational meeting to discuss the background of the site. The PRPs began discussing a potential proposal to the EPA in February 2008. Negotiations among the PRPs and the EPA are ongoing in regard to the remedial investigation and feasibility study at the Devil’s Swamp site, with little progress having been made since the January 2008 meeting. The PRPs alleged to have disposed PCBs at the site have proposed a tentative cost-sharing formula with the facility owner to fund the remedial investigation. The response to the proposal has been pending for months. Since this investigation is in the preliminary stages, management is unable to determine whether the costs associated with possible remediation of the facility site will have a material adverse effect on the Registrants’ results of operations, financial condition, and cash flows.

ITEM 1A. RISK FACTORS

The following risk factors could have a material adverse effect on results and cause results to differ materially from those expressed in any forward-looking statements made by, or on behalf of, the Registrants.

Global Economic Downturn

The global economic downturn may negatively impact Cleco’s business and financial condition.

The current economic downturn may have an impact on Cleco’s business and financial condition. Cleco’s ability to access the capital markets may be severely restricted at a time when Cleco would like, or need, to do so, which could have a material adverse impact on its ability to fund capital expenditures or debt service, or on Cleco’s flexibility to react to changing economic and business conditions. If Cleco Corporation’s or Cleco Power’s credit ratings were to be downgraded by Moody’s or by Standard & Poor’s, Cleco Corporation or Cleco Power, as the case may be, would be required to pay additional fees and higher interest rates under its bank credit and other debt agreements. Cleco’s pension plan portfolio has experienced significant volatility due to market conditions and may experience material losses in the future. The losses, in conjunction with plan funding requirements, could result in required pension plan contributions significantly higher and earlier than previously anticipated, which could have a material adverse impact on Cleco’s results of operations, financial condition, and cash flows. Further, the current economic downturn could have a material adverse impact on Cleco’s lenders or its customers, causing them to fail to meet their obligations to Cleco or to delay payment of such obligations. Additionally, the current economic downturn could lead to reduced electricity usage, which could have a material adverse impact on the Registrants’ results of operations and financial condition.

Future Electricity Sales

Cleco Power’s future electricity sales and corresponding base revenue and cash flows could be adversely affected by general economic conditions.

General market conditions can negatively impact the businesses of Cleco Power’s industrial customers, resulting in decreased power purchases and lower base revenue. The current U. S. recession has led to reduced power usage by Cleco Power’s industrial customers. Industrial kWh sales in 2009 were down 23% from 2008 levels. Lower sales to industrial customers were largely the result of decreased production at one of Cleco Power’s large industrial customers and a large customer beginning to cogenerate a portion of its electricity requirements. Cleco Power’s largest industrial customers, specifically those who manufacture wood and paper products (who generated $21.7 million in base revenue in 2009), have experienced a downturn in their respective markets. The paper industry has been vulnerable in recent years due to decreasing demand for the product, and the downturn in residential home construction has also caused a significant reduction in the demand and prices for lumber and other wood products. Reduced production or the shut down of any of these customers’ facilities could substantially reduce Cleco Power’s base revenue. For example, in 2009 a paper manufacturer announced the closing of a plant in Cleco Power’s service territory, which is expected to decrease 2010 base revenue by $2.3 million from 2009 levels.

Future electricity sales could be impacted by industrial customers switching to alternative sources of energy, including on-site power generation, and retail customers consuming

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less electricity due to increased conservation efforts or increased electric usage efficiency.

Fuel Cost Audits

The LPSC conducts fuel audits that could result in Cleco Power making substantial refunds of previously recorded revenue.

Generally, fuel and purchased power expenses are recovered through the LPSC-established fuel adjustment clause, which enables Cleco Power to pass on to its customers substantially all such charges. Recovery of fuel adjustment clause costs is subject to a periodic fuel audit by the LPSC. The LPSC Fuel Adjustment Clause General Order issued November 6, 1997, in Docket No. U-21497 provides that an audit will be performed not less than every other year.

Cleco Power currently has fuel adjustment clause filings for 2003 through 2008 subject to audit. In July 2006, the LPSC informed Cleco Power that it was planning to conduct a periodic fuel audit that included fuel adjustment clause filings for January 2003 through December 2004. In March 2009, the LPSC indicated its intent to proceed with the audit for the years 2003 through 2008. The total amount of fuel expenses included in the audit is approximately $3.2 billion. The audit is expected to proceed in the first quarter of 2010. Cleco Power could be required to make a substantial refund of previously recorded revenue as a result of these audits, and such refund could result in a material adverse effect on the Registrants’ results of operations, financial condition, and cash flows. The most recent audit completed by the LPSC covered 2001 and 2002 and resulted in a refund of $16.0 million to Cleco Power’s retail customers in the first quarter of 2005.

Hedging and Risk Management Activities

Cleco Power is subject to market risk associated with economic hedges relating to open natural gas contracts. Cleco has risk management policies which cannot eliminate all risk involved in its energy commodity activities.

Cleco Power utilizes economic hedges to mitigate the risks associated with a fixed-price wholesale power contract that is not included in the fuel adjustment clause. Any realized gain or loss attributable to these hedges is recorded on the income statement as a component of operating revenue, net. Accordingly, changes in the market value of these hedging arrangements caused by natural gas price volatility will impact the Registrants’ results of operations, financial condition, and cash flows.

Cleco Power also has entered into economic hedge positions to mitigate the volatility in fuel costs passed through to its retail customers. When these positions close, actual gains or losses are deferred and included in the fuel adjustment clause in the month the physical contract settles. However, recovery of any of these fuel adjustment clause costs is subject to, and may be disallowed as part of, a prudency review or a periodic fuel audit conducted by the LPSC.

Cleco Power manages its exposure to energy commodity activities by establishing and enforcing risk limits and risk management procedures. These risk limits and risk management procedures may not be as effective as planned, particularly if intentional misconduct is involved, and cannot eliminate all risk associated with these activities.

Transmission Constraints

Transmission constraints could have a material adverse effect on the Registrants’ results of operations, financial condition, and cash flows.

Because of Cleco Power’s location on the transmission grid, Cleco Power relies on two main suppliers of electric transmission when accessing external power markets. At times, physical constraints limit the amount of purchased power these transmission providers can deliver into Cleco Power’s service territory, which in turn can affect capacity or power purchases under long-term contracts, as well as spot market power purchases. If the amount of purchased power actually delivered into Cleco’s transmission system were less than the amount of power contracted for delivery, Cleco Power may rely on its own generation facilities to meet customer demand. Cleco Power’s incremental generation cost at that time could be higher than the cost to purchase power from the wholesale power market, thereby increasing its customers’ ultimate cost. In addition, the LPSC may not allow Cleco Power to recover part or all of its incremental generation cost, which could be substantial.

Commodity Prices

Cleco Power is subject to the fluctuation in the market prices of various commodities which may increase the cost of producing power.

Cleco Power purchases coal, lignite, natural gas, petroleum coke, and fuel oil under long-term contracts and on the spot market. Historically, the markets for oil, natural gas, petroleum coke, and coal have been volatile and are likely to remain volatile in the future. Cleco Power’s retail rates include a fuel adjustment clause that enables it to adjust rates for monthly fluctuations in the cost of fuel and purchased power. However, recovery of any of these fuel adjustment clause costs is subject to, and may be disallowed as part of, a prudency review or a periodic fuel audit conducted by the LPSC.

Cleco Power Generation Facilities

Cleco Power’s generation facilities are susceptible to unplanned outages, significant maintenance requirements, and interruption of fuel deliveries.

The operation of power generation facilities involves many risks, including breakdown or failure of equipment, fuel supply interruption, and performance below expected levels of output or efficiency. Some of Cleco Power’s facilities were originally constructed many years ago. Older equipment, even if maintained in accordance with good engineering practices, may require significant expenditures to operate at peak efficiency or availability, or in compliance with its environmental permits.

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If Cleco Power fails to make adequate expenditures for equipment maintenance, Cleco Power risks incurring more frequent unplanned outages, higher than anticipated operating and maintenance expenditures, increased fuel or power purchase costs, and potentially the loss of revenue related to competitive opportunities. Newer equipment, such as that installed at Rodemacher Unit 3, can be subject to startup issues, such as failures due to immaturity of control equipment safeguards and experience with operating under forced outage conditions. Equipment manufacturer warranty coverage will be subject to proof of Cleco Power’s proper operation of the equipment.

Cleco Power’s generating facilities are fueled primarily by coal, natural gas, petroleum coke, and lignite. The deliverability of these fuel sources may be constrained due to such factors as higher demand, production shortages, weather-related disturbances or lack of transportation capacity. If the suppliers are unable to deliver the contracted volume of fuel, Cleco Power would have to replace any deficiency with alternative sources, which may not be as favorable and could increase the ultimate cost of fuel to customers. Fuel and purchased power expenses are recovered from customers through the fuel adjustment clause, which is subject to refund until either a prudency review or a periodic fuel audit is conducted by the LPSC.

Competition for access to other natural resources, particularly oil and natural gas, could negatively impact Cleco Power’s ability to access its lignite reserves. Land owners may grant other parties access for oil and natural gas drilling in the same area to which Cleco has been granted access for lignite reserves. Placement of drilling rigs and pipelines for developing oil and gas reserves can preclude access to lignite in the same areas, making right of first access critical with respect to extracting lignite. Competition for the right of first access may need to be determined through legal processes. Additionally, Cleco Power could be liable for the impacts of other companies’ activities on lands that have been mined and reclaimed by Cleco Power. Loss of access to the lignite reserves or the liability for impacts on reclaimed lands could have material adverse effects to the Registrants’ results of operations, financial condition, and cash flows.

ERO

In 2005, FERC’s authority was expanded to include the establishment and enforcement of mandatory reliability standards on the transmission system, as well as the capacity to impose fines and civil penalties on those who fail to comply with those standards.

The Energy Policy Act of 2005 authorized the creation of an ERO with authority to establish and enforce mandatory reliability standards, subject to FERC approval, for users of the nation’s transmission system. In July 2006, FERC named NERC as the ERO. FERC has approved numerous reliability standards developed by NERC. A final order was issued by FERC in March 2007, and in June 2007, FERC began enforcing compliance with these standards. New standards are being developed and existing standards are continuously being modified.

As these standards continue to be adopted and modified, they may impose additional compliance requirements on Cleco Power, Acadia, and Evangeline operations, which may result in an increase in capital expenditures and operating expenses. Failure to comply with the reliability standards approved by FERC can result in the imposition of material fines and civil penalties. Cleco is scheduled for an audit by SPP, the RTO for Cleco’s region, in April 2010. Management is currently unable to predict the outcome of the audit and whether the result will have a material adverse effect on the Registrants’ results of operations, financial condition, and cash flows.

Environmental Compliance

Cleco’s costs of compliance with environmental laws and regulations are significant. The costs of compliance with new environmental laws and regulations, as well as the incurrence of incremental environmental liabilities, could be significant to the Registrants.

Cleco is subject to extensive environmental oversight by federal, state, and local authorities and is required to comply with numerous environmental laws and regulations related to air quality, water quality, waste management, natural resources, and health and safety. Cleco also is required to obtain and comply with numerous governmental permits in operating its facilities. Existing environmental laws, regulations, and permits could be revised or reinterpreted, and new laws and regulations could be adopted or become applicable to Cleco. For example, Congress is considering climate change legislation that, if ultimately enacted, could impose a cap on CO2 emissions by electric generating units and subject these units to an emissions allowance-based trading system. Cleco may incur significant capital expenditures or additional operating costs to comply with these revisions, reinterpretations, and new requirements. If Cleco fails to comply with these revisions, reinterpretations, and requirements, it could be subject to civil or criminal liabilities and fines or may be forced to shut down or reduce productions from its facilities.

Environmental advocacy groups, states, other organizations, some government agencies, and the presidential administration are focusing considerable attention on emissions from power generation facilities, including CO2 emissions, and their potential role in climate change. Future changes in environmental regulations governing power plant emissions could make some of Cleco’s electric generating units uneconomical to maintain or operate. In addition, any legal obligation that would require Cleco to substantially reduce its emissions beyond present levels could require extensive mitigation efforts and could raise uncertainty about the future viability of some fossil fuels as an energy source for new and existing electric generation facilities.

Cleco Power may request recovery from its retail customers of its costs to comply with new environmental laws and regulations. If revenue relief were to be approved by the

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

LPSC, then Cleco Power’s retail rates could increase. If the LPSC were to deny Cleco Power’s request to recover all or part of its environmental compliance costs, there could be a material adverse effect on the Registrants’ results of operations, financial condition, and cash flows.

Regulatory Compliance

Cleco operates in a highly regulated environment and adverse regulatory decisions or changes in applicable regulations could have a material adverse effect on the Registrants’ businesses or result in significant additional costs.

Cleco’s business is subject to extensive federal, state, and local energy, environmental and other laws and regulations. The LPSC regulates Cleco’s retail operations, and FERC regulates Cleco’s wholesale operations. The construction, planning, and siting of Cleco’s power plants and transmission lines also are subject to the jurisdiction of the LPSC and FERC. Additional regulatory authorities have jurisdiction over some of Cleco’s operations and construction projects including the EPA, the United States Bureau of Land Management, the United States Fish and Wildlife Services, the United States Department of Energy, the United States Army Corps of Engineers, the United States Department of Homeland Security, the Occupational Safety and Health Administration, the United States Department of Transportation, the LDEQ, the Louisiana Department of Health and Hospitals, the Louisiana Department of Natural Resources, the Louisiana Department of Public Safety, regional water quality boards, and various local regulatory districts.

Cleco must periodically apply for licenses and permits from these various regulatory authorities and abide by their respective orders. Should Cleco be unsuccessful in obtaining necessary licenses or permits or should these regulatory authorities initiate any investigations or enforcement actions or impose penalties or disallowances on Cleco, Cleco’s business could be adversely affected. Existing regulations may be revised or reinterpreted and new laws and regulations may be adopted or become applicable to Cleco or Cleco’s facilities in a manner that may have a detrimental effect on the Registrants’ business or result in significant additional costs because of Cleco’s need to comply with those requirements.

Weather Sensitivity

The operating results of Cleco Power are affected by weather conditions and may fluctuate on a seasonal and quarterly basis.

Weather conditions directly influence the demand for electricity, particularly kWh sales to residential customers. In Cleco Power’s service territory, demand for power typically peaks during the hot summer months. As a result, Cleco Power’s financial results may fluctuate on a seasonal basis. In addition, Cleco Power has sold less power, and consequently earned less income, when weather conditions were milder. Unusually mild weather in the future could have a material adverse impact on the Registrants’ results of operations, financial condition, and cash flows.

Severe weather, including hurricanes and winter storms, can be destructive, causing outages and property damage that can potentially result in additional expenses and lower revenue.

Retail Electric Service

Cleco Power’s retail electric rates and business practices are regulated by the LPSC.

Cleco Power’s retail rates for residential, commercial, and industrial customers and other retail sales are regulated by the LPSC, which conducts an annual review of Cleco Power’s earnings and regulatory return on equity. Through 2009, Cleco Power filed annual monitoring reports with the LPSC for 12-month periods ended September 30. In 2010, the reports will be filed for 12-month periods ended June 30 and September 30. Beginning in 2011, Cleco Power will file annual monitoring reports for the 12-month period ended June 30. Cleco Power could be required to make a substantial refund of previously recorded revenue as a result of the LPSC review, and such refund could result in a material adverse effect on the Registrants’ results of operations, financial condition, and cash flows.

Wholesale Electric Service

Cleco Power’s wholesale electric rates and business practices are regulated by FERC.

Cleco Power’s wholesale rates are regulated by FERC, which conducts a review of Cleco Power’s generation market power every three years, in addition to each time generation capacity changes. If FERC determines Cleco Power possesses generation market power in excess of certain thresholds, Cleco Power could lose the right to sell wholesale generation at market-based rates within its control area, which could result in a material adverse effect on the Registrants’ results of operations, financial condition, and cash flows.

Cleco Credit Ratings

A downgrade in Cleco Corporation’s or Cleco Power’s credit rating could result in an increase in their respective borrowing costs and a reduced pool of potential investors and funding sources.

While the senior unsecured debt ratings of Cleco Corporation and Cleco Power are currently investment grade, in recent years such ratings have been downgraded or put on negative watch by Moody’s and Standard & Poor’s. Cleco Corporation or Cleco Power cannot assure that its current debt ratings will remain in effect for any given period of time or that one or more of its debt ratings will not be lowered or withdrawn entirely by a rating agency. Credit ratings are not recommendations to buy, sell, or hold securities and each rating should be evaluated independently of any other rating. If Moody’s or Standard & Poor’s were to downgrade Cleco Corporation’s or Cleco Power’s long-term ratings, particularly below investment grade, the value of their debt securities would likely be adversely affected, and the borrowing cost of Cleco Corporation

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

or Cleco Power would likely increase. In addition, Cleco Corporation or Cleco Power would likely be required to pay higher interest rates in future debt financings and be subject to more onerous debt covenants, and its pool of potential investors and funding sources could decrease.

Interest Rate Swap

Cleco Power has entered into an interest rate swap relating to its variable rate debt. The effectiveness of this contract is dependent on the ability of the counterparty to perform its obligations and nonperformance could harm Cleco Power's results of operations, financial condition, and cash flows.

Cleco Power utilizes interest rate swaps to offset the effects of interest rate fluctuations on its variable rate debt. The effectiveness of these contracts is dependent, in part, upon the counterparties to these contracts honoring their financial obligations. If the counterparties to the interest rate swaps are unable to perform their obligations, Cleco Power would be exposed to the effect of the fluctuations of the LIBOR market on its variable rate debt and may have to pay increased interest expenses, which could have a material adverse impact on the Registrants’ results of operations, financial condition, and cash flows.

Holding Company

Cleco Corporation is a holding company, and its ability to meet its debt obligations and pay dividends on its common stock is dependent on the cash generated by its subsidiaries.

Cleco Corporation is a holding company and conducts its operations primarily through its subsidiaries. Substantially all of Cleco’s consolidated assets are held by its subsidiaries. Accordingly, Cleco’s ability to meet its debt obligations and to pay dividends on its common stock is largely dependent upon the cash generated by these subsidiaries. Cleco’s subsidiaries are separate and distinct entities and have no obligation to pay any amounts due on Cleco’s debt or to make any funds available for such payment. In addition, Cleco’s subsidiaries’ ability to make dividend payments or other distributions to Cleco may be restricted by their obligations to holders of their outstanding securities and to other general business creditors. Moreover, Cleco Power, Cleco’s principal subsidiary, is subject to regulation by the LPSC, which may impose limits on the amount of dividends that Cleco Power may pay Cleco Corporation.

Evangeline and Acadia Generation Facilities

The Evangeline and Acadia generation facilities are susceptible to unplanned outages, significant maintenance requirements, interruption of fuel deliveries, and transmission constraints.

The operation of power generation facilities involves many risks, including breakdown or failure of equipment, fuel interruption, and performance below expected levels of output or efficiency. If adequate expenditures for equipment maintenance are not made, a facility may incur more frequent unplanned outages, higher than anticipated operating and maintenance expenditures, increased fuel costs, and potentially the loss of revenue related to competitive opportunities.

The Evangeline and Acadia generating facilities are fueled by natural gas. The deliverability of this fuel source may be constrained due to such factors as higher demand, production shortages, weather-related disturbances, or lack of transportation capacity.

Because of Acadia’s location on the transmission grid, Acadia relies on two main suppliers of electric transmission when accessing external power markets. However, at times, physical constraints limit the amount of power these transmission providers can deliver.

Cleco Power’s Rates

The LPSC and FERC regulate the rates that Cleco Power can charge its customers.

Cleco Power’s ongoing financial viability depends on its ability to recover its costs from its LPSC-jurisdicational customers in a timely manner through its LPSC-approved rates and its ability to pass through to its FERC customers in rates its FERC-authorized revenue requirements. Cleco Power’s financial viability also depends on its ability to recover in rates an adequate return on capital, including long-term debt and equity. If Cleco Power is unable to recover any material amount of its costs in rates in a timely manner or recover an adequate return on capital, the Registrants’ results of operations, financial condition, and cash flows could be materially adversely affected.

Cleco Power’s revenues and earnings are substantially affected by regulatory proceedings known as rate cases. During those cases, the LPSC determines Cleco Power’s rate base, depreciation rates, operation and maintenance costs, and administrative and general costs that Cleco Power may recover from its retail customers through its rates. These proceedings may examine, among other things, the prudence of Cleco Power’s operation and maintenance practices, level of subject expenditures, allowed rates of return, and previously incurred capital expenditures. The LPSC has the authority to disallow costs found not to have been prudently incurred. These regulatory proceedings typically involve multiple parties, including governmental bodies and officials, consumer advocacy groups, and various consumers of energy, who have differing concerns but who have the common objective of limiting rate increases or reducing rates. Rate cases generally have long timelines, which may be limited by statute. Decisions are typically subject to appeal, potentially leading to additional uncertainty.

Alternate Generation Technology

Changes in technology may negatively impact the value of the Cleco Power, Evangeline, and Acadia generation facilities.

A basic premise of Cleco’s business is that generating electricity at central power plants achieves economies of scale and produces electricity at a relatively low price. There are

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

alternate technologies to produce electricity, most notably fuel cells, microturbines, windmills, and photovoltaic (solar) cells. Research and development activities are ongoing to seek improvements in alternate technologies. It is possible that advances will reduce the cost of alternate methods of electricity production to a level that is equal to or below that of most central station production. Also, as new technologies are developed and become available, the quantity and pattern of electricity usage by customers could decline, with a corresponding decline in revenues derived by generators. In addition, the current presidential administration and U.S. Congress have voiced strong support for such alternative energy sources. The American Recovery and Reinvestment Act of 2009 specifically provides a total of $58.0 billion to be available for energy-related initiatives, primarily $20.0 billion in renewable energy tax credits to encourage development of wind, solar, and other renewable energy sources, and $32.0 billion for development of a “smart grid” in the U.S. It is uncertain at this time to what extent these initiatives may impact Cleco’s businesses, except that little impact is expected in the short term. As a result of these factors, the value of the Cleco Power, Evangeline, and Acadia generation facilities could be significantly reduced.

Technology and Terrorism Threats

Man-made problems such as computer viruses or terrorism may negatively impact the Registrants’ operating results.

Man-made problems such as computer viruses or terrorism may disrupt the Registrants’ operations and harm the Registrants’ operating results. The Registrants operate in a highly regulated industry that requires the continued operation of sophisticated information technology systems and network infrastructure. Despite the implementation of security measures, all of the Registrants’ technology systems are vulnerable to disability or failures due to hacking, viruses, acts of war or terrorism, and other causes. If the Registrants’ technology systems were to fail and the Registrants were unable to recover in a timely way, the Registrants would be unable to fulfill critical business functions, which could have a material adverse effect on the Registrants’ business, operating results, financial condition, and cash flows. In addition, the Cleco Power, Evangeline, and Acadia generation plants, fuel storage facilities, transmission, and distribution facilities may be targets of terrorist activities that could disrupt the Registrants’ ability to produce or distribute some portion of their energy products. Any such disruption could result in a material decrease in revenues and significant additional costs to repair and insure the Registrants’ assets, which could have a material adverse effect on the Registrants’ business, operating results, financial condition, and cash flows. The continued threat of terrorism and heightened security and military action in response to this threat, or any future acts of terrorism, may cause further disruptions to the economies of the United States and other countries and create further uncertainties or otherwise materially harm the Registrants’ business, operating results, financial condition, and cash flows.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

ITEM 1B. UNRESOLVED STAFF COMMENTS

None.

ITEM 2. PROPERTIES

CLECO

Electric Transmission Substations

As of December 31, 2009, Cleco Corporation owned one active transmission substation in Louisiana and one active transmission substation in Mississippi.

CLECO POWER

All of Cleco Power’s electric generating stations and all other electric operating properties are located in the state of Louisiana. Cleco Power considers all of its properties to be well maintained, in good operating condition, and suitable for their intended purposes. For information on Cleco Power’s generating facilities, see Item 1, “Business — Operations — Cleco Power — Power Generation.”

Electric Generating Stations

As of December 31, 2009, Cleco Power either owned or had an ownership interest in three steam electric generating stations and one gas turbine with a combined name plate capacity of 1,359 MW, and a combined electric net generating capacity of 1,318 MW. The net generating capacity is the result of capacity testing performed between June and September 2007, as required by NERC. This amount reflects the maximum production capacity these units can sustain over a specified period of time. Rodemacher Unit 3, a 600-MW solid-fuel power plant, commenced commercial operations on February 12, 2010. During 2009, Acadia executed definitive agreements with Cleco Power to acquire 50% of the Acadia Power Station, or one of its two 580-MW units. The transaction with Cleco Power was completed in February 2010. For additional information on Cleco Power’s generating facilities, see Item 1, “Business — Operations — Cleco Power — Power Generation” and Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 15 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Acadia Transactions” and Note 23 — “Subsequent Events — Acadia Transaction.”

Electric Substations

As of December 31, 2009, Cleco Power owned 70 active transmission substations and 224 active distribution substations.

Electric Lines

As of December 31, 2009, Cleco Power’s transmission system consisted of approximately 67 circuit miles of 500-kiloVolt (kV) lines; 460 circuit miles of 230-kV lines; 676 circuit miles of 138 kV lines; and 21 circuit miles of 69-kV lines. Cleco Power’s distribution system consisted of approximately 3,464 circuit miles of 34.5-kV lines and 8,107 circuit miles of other lines.

General Properties

Cleco Power owns various properties throughout Louisiana, which include a headquarters office building, regional offices, service centers, telecommunications equipment, and other general-purpose facilities.

Title

Cleco Power’s electric generating plants and certain other principal properties are owned in fee. Electric transmission and distribution lines are located either on private rights-of-way or along streets or highways by public consent.

Substantially all of Cleco Power’s property, plant and equipment are subject to a lien of Cleco Power’s Indenture of Mortgage, which does not impair the use of such properties in the operation of its business. As of December 31, 2009, no obligations were outstanding under the Indenture of Mortgage.

MIDSTREAM

Midstream considers all of its properties to be well maintained, in good operating condition, and suitable for their intended purposes. For information on Midstream’s generating facilities, see Item 1, “Business — Operations — Midstream.”

Electric Generation

As of December 31, 2009, Midstream owned one electric generating station, Evangeline, and had a 50% ownership interest in an additional station, Acadia, both located in Louisiana. During 2009, Acadia executed definitive agreements with both Cleco Power and Entergy Louisiana whereby Cleco Power and Entergy Louisiana would each acquire a 580-MW unit at the Acadia plant. The transaction with Cleco Power was completed in February 2010 and the transaction with Entergy Louisiana is expected to be completed in late 2010 or early 2011. For additional information on Midstream’s generating facilities, see Item 1, “Business — Operations — Midstream” and Part II, Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 23 — Subsequent Events — Acadia Transaction.”

Title

Midstream’s assets are owned in fee, including Midstream’s portion of Acadia. Evangeline was subject to a lien securing obligations under an Indenture of Mortgage, which did not impair the use of such properties in the operation of its business. On February 22, 2010, Evangeline and JPMVEC terminated the Evangeline Tolling Agreement and executed the Evangeline 2010 Tolling Agreement. For additional information, see Part II, Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 23 — Subsequent Events — Evangeline Transactions.”

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

ITEM 3. LEGAL PROCEEDINGS

CLECO

For information on legal proceedings affecting Cleco, see Part I, Item I, “Business — Environmental Matters — Environmental Quality — Air Quality” and “— Water Quality” and Part II, Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 15 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation.”

CLECO POWER

For information on legal proceedings affecting Cleco Power, see Part II, Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 15 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation.”

ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS

CLECO

There were no matters submitted to a vote of security holders of Cleco Corporation during the fourth quarter of 2009.

CLECO POWER

The information called for by Item 4 with respect to Cleco Power is omitted pursuant to General Instruction I(2)(c) to Form 10-K (Omission of Information by Certain Wholly Owned Subsidiaries).

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

Board of Directors of Cleco

The names of the members of the Board of Directors of Cleco, their ages, dates of election, employment history and committee assignments as of December 31, 2009, are included below. The term of each directorship is three years, and directors are divided among three classes. The terms of the three classes are staggered in a manner so that only one class is elected by the shareholders annually.

NAME OF DIRECTOR	AGES AS OF DECEMBER 31, 2009
Sherian G. Cadoria	Age 69; Elected 1993 Brigadier General, U.S. Army (retired) Retired President, Cadoria Speaker and Consultancy Service, Mansura, LA Member of the Audit, Nominating/Governance and Qualified Legal Compliance committees
Richard B. Crowell	Age 71; Elected 1997 Partner, law firm of Crowell & Owens, Alexandria, LA Member of the Audit, Nominating/Governance and Qualified Legal Compliance committees
J. Patrick Garrett	Age 66; Elected 1981 Retired President and Chief Executive Officer, Windsor Food Company, Ltd., Houston, TX Chairman of the Board and chairman of the Executive, Nominating/Governance and Qualified Legal Compliance committees
Elton R. King	Age 63; Elected 1999 Retired President of network and carrier services group, BellSouth Telecommunications, Inc., Atlanta, GA. Also retired president and Chief Executive Officer of Visual Networks, Inc. Member of the Finance and Nominating/Governance committees
Logan W. Kruger	Age 59; Elected 2008 President, Chief Executive Officer and Director of Century Aluminum Company, Monterey, CA since December 2005. Executive Vice President of Technical Services, Inco Limited from September 2003 to September 2005; President, Inco Asia Pacific from September 2005 to November 2005. Member of the Audit and Compensation committees
Michael H. Madison	Age 61; Elected 2005 President and Chief Executive Officer, Cleco Corporation, Pineville, LA Member of the Executive Committee
William L. Marks	Age 66; Elected 2001 Retired Chairman and Chief Executive Officer, Whitney Holding Corporation and Whitney National Bank, New Orleans, LA Chairman of the Finance Committee and member of the Compensation and Executive committees
Robert T. Ratcliff Sr.	Age 67; Elected 1993 Chairman, President and Chief Executive Officer, Ratcliff Construction Company, LLC, Alexandria, LA Member of the Audit and Finance committees
Peter M. Scott III	Age 60; Elected 2009 Retired Executive Vice President and Chief Financial Officer, Progress Energy, Inc., Raleigh, NC. Also retired President and Chief Executive Officer of Progress Energy Service Company, LLC Member of the Audit and Compensation committees
William H. Walker Jr.	Age 64; Elected 1996 Retired Chairman, Howard Weil, Inc., New Orleans, LA Chairman of the Compensation Committee and member of the Executive and Finance committees
W. Larry Westbrook	Age 70; Elected 2003 Retired Chief Financial Officer and Senior Risk Officer of Southern Company, Atlanta, GA Chairman of the Audit Committee and member of the Compensation, Executive and Finance committees

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

Executive Officers of Cleco

The names of the executive officers of Cleco and certain subsidiaries, their positions held, five-year employment history, ages, and years of service as of December 31, 2009, are presented below. Executive officers are appointed annually to serve for the ensuing year or until their successors have been appointed.

NAME OF EXECUTIVE	POSITION AND FIVE-YEAR EMPLOYMENT HISTORY
Michael H. Madison Cleco Corporation Cleco Power	President and Chief Executive Officer since May 2005. Chief Executive Officer since May 2005; President and Chief Operating Officer from October 2003 to May 2005. (Age 61; 6 years of service)
Dilek Samil Cleco Corporation Cleco Power	Executive Vice President and Chief Financial Officer from April 2004 to May 2005. President and Chief Operating Officer since May 2005; Executive Vice President and Chief Financial Officer from April 2004 to May 2005. (Age 54; 8 years of service)
Darren J. Olagues Cleco Corporation Cleco Power Midstream	Senior Vice President and Chief Financial Officer since May 2009. Senior Vice President from July 2007 to May 2009; Vice President, Power - Asset Management and Development, Exelon Corporation from November 2006 to July 2007; Director - Corporate Development, Exelon Corporation from March 2005 to November 2006; Senior Vice President and Chief Financial Officer, Sithe Energies from October 2002 to February 2005. (Age 39; 2 years of service)
George W. Bausewine Cleco Corporation Cleco Power	Senior Vice President Corporate Services since May 2005; Vice President Regulatory and Rates from October 2002 to May 2005. (Age 54; 24 years of service)
Jeffrey W. Hall Cleco Corporation Cleco Power	Senior Vice President Governmental Affairs and Chief Diversity Officer since July 2006; Vice President Governmental and Community Affairs from July 2005 to July 2006. Senior Vice President Governmental Affairs and Chief Diversity Officer since July 2006; Vice President Governmental and Community Affairs from October 2004 to July 2006. (Age 58; 29 years of service)
Wade A. Hoefling Cleco Corporation Cleco Power	Senior Vice President, General Counsel & Director - Regulatory Compliance since April 2008; Senior Vice President, General Counsel, Director - Regulatory Compliance and Assistant Corporate Secretary from January 2007 to April 2008; General Counsel, Northeast Utilities Enterprises, Inc. from July 2004 to January 2007. (Age 54; 3 years of service)
Anthony L. Bunting Cleco Power	Vice President Customer Services and Energy Delivery since October 2004. (Age 50; 18 years of service)
Stephen M. Carter Cleco Power	Vice President Regulated Generation since April 2003. (Age 50; 21 years of service)

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

NAME OF EXECUTIVE	POSITION AND FIVE-YEAR EMPLOYMENT HISTORY
Keith D. Crump Cleco Corporation Cleco Power	Treasurer from May 2005 to March 2007; Manager Forecasting and Analytics, Budgeting from December 2004 to May 2005. Vice President - Regulatory, Retail Operations and Resource Planning since March 2007. (Age 48; 20 years of service)
R. Russell Davis Cleco Corporation Cleco Power	Vice President - Investor Relations and Chief Accounting Officer since May 2009; Vice President, Chief Accounting Officer & Interim CFO from June 2008 to May 2009; Vice President and Chief Accounting Officer from May 2005 to June 2008; Vice President and Controller from July 2000 to May 2005. (Age 53; 10 years of service)
William G. Fontenot Cleco Power Midstream	Vice President Regulated Generation Development since July 2005. Chief Restructuring Officer of Perryville from April 2004 to July 2005. (Age 46; 24 years of service)
Charles A. Mannix Cleco Corporation Cleco Power	Vice President - Tax & Treasurer since March 2008; Manager of Income Taxes, Treasurer of Energy Risk Assurance Co., Ameren Corporation from October 2004 to March 2008. (Age 51; 2 years of service)
Judy P. Miller Cleco Corporation Cleco Power	Corporate Secretary since January 2004. (Age 52; 25 years of service)
Terry L. Taylor Cleco Corporation Cleco Power	Assistant Controller since August 2006; Director of Accounting Services and Affiliate Compliance from January 2004 to August 2006. (Age 54; 9 years of service)
W. Keith Johnson, Jr. Midstream	Acting Vice President since May 2009; General Manager - Midstream Commercial Operations from October 2007 to May 2009; Director -Business Development from October 2002 to October 2007. (Age 48; 15 years of service)

In January 2004, Perryville entered into an agreement to sell its 718-MW power plant to Entergy Louisiana. As part of the sales process, Perryville and PEH filed voluntary petitions in the Perryville and PEH Bankruptcy Court for protection under Chapter 11 of the U.S. Bankruptcy Code. Ms. Samil and Mr. Fontenot were managers of Perryville and/or PEH within the two years preceding the voluntary bankruptcy filing.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

PART II

ITEM 5. MARKET FOR REGISTRANTS’ COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND CLECO CORPORATION’S PURCHASES OF EQUITY SECURITIES

CLECO CORPORATION

Cleco Corporation’s common stock is listed for trading on the New York Stock Exchange (NYSE). For information on the high and low sales prices for Cleco Corporation’s common stock as reported on the NYSE Composite Tape and dividends paid per share during each calendar quarter of 2009 and 2008, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 22 — Miscellaneous Financial Information (Unaudited).” During the year ended December 31, 2009, none of Cleco Corporation’s equity securities registered pursuant to Section 12 of the Securities Exchange Act of 1934 were purchased by or on behalf of Cleco Corporation or any of its “affiliated purchasers,” as defined in Rule 10b-18(a)(3) under the Securities Exchange Act of 1934. For information on Cleco Corporation’s common stock repurchase program, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 7 — Common Stock — Common Stock Repurchase Program.”

Subject to the prior rights of the holders of the respective series of Cleco Corporation’s preferred stock, such dividends as determined by the Board of Directors of Cleco Corporation may be declared and paid on the common stock from time to time out of funds legally available. The provisions of Cleco Corporation’s charter applicable to preferred stock and certain provisions contained in the debt instruments of Cleco under certain circumstances restrict the amount of retained earnings available for the payment of dividends by Cleco Corporation. The most restrictive covenant, which is in Cleco Corporation’s credit facility, requires Cleco Corporation’s total indebtedness to be less than or equal to 65% of total capitalization. At December 31, 2009, approximately $401.7 million of retained earnings were unrestricted.

As of January 29, 2010, there were 6,701 holders of record of Cleco Corporation’s common stock, and the closing price of Cleco Corporation’s common stock as reported on the NYSE Composite Tape was $25.92 per share.

The Board of Directors of Cleco Corporation has approved a dividend policy that will increase its quarterly dividend rate, subject to future dividend declarations by the Board of Directors, from $0.225 per common share to $0.25 per common share beginning with the dividend payable May 15, 2010. The declaration of dividend payments is at the Board of Directors' sole discretion and future dividend increases are subject to numerous factors that ordinarily affect dividend policy, including the result of Cleco’s operations and its financial position, as well as general economic and business conditions.

CLECO POWER

There is no market for Cleco Power’s membership interests. All of Cleco Power’s outstanding membership interests are owned by Cleco Corporation. Distributions on Cleco Power’s membership interests are paid when and if declared by Cleco Power’s Board of Managers. Any future distributions also may be restricted by any credit or loan agreements that Cleco Power may enter into from time to time.

During 2009, Cleco Power made $30.0 million of distribution payments to Cleco Corporation. There were no distributions from Cleco Power to Cleco Corporation during 2008 or 2007.

Cleco Power received no equity contributions from Cleco Corporation in 2009 or 2008. During 2007, Cleco Power received equity contributions of $85.0 million from Cleco Corporation.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

ITEM 6. SELECTED FINANCIAL DATA

CLECO

The information set forth below should be read in conjunction with the Consolidated Financial Statements and the related Notes in Item 8, “Financial Statements and Supplementary Data.”

Perryville and PEH were deconsolidated from Cleco in connection with their bankruptcy filings, and no income or loss associated with those subsidiaries was recognized in Midstream’s consolidated financial statements subsequent to the bankruptcy filing on January 28, 2004. In October 2005, an order confirming PEH and Perryville’s plan of reorganization became final. In accordance with the authoritative guidance for transfers and servicing, Cleco recorded its investment in Perryville on the equity method of accounting. In accordance with the authoritative guidance on investments, since PEH and Perryville had a negative cost basis and incurred losses for 2004 and the first and second quarters of 2005, PEH and Perryville were not to be reflected in Cleco Corporation’s Consolidated Statements of Income until such time as PEH and Perryville had sufficient income to exceed their negative cost basis and cumulative losses. In the third quarter of 2005, Perryville recognized earnings sufficient to exceed PEH’s and Perryville’s initial negative cost basis and cumulative losses incurred after January 28, 2004. The previous financial results of Perryville and PEH were reintegrated with Cleco’s consolidated financial results effective in the third quarter of 2005.

Cleco’s adoption of the authoritative guidance on compensation-stock compensation on January 1, 2006, impacted Cleco’s consolidated financial results for 2009, 2008, 2007, and 2006 as compared to prior years. Cleco’s adoption of the authoritative guidance as it relates to compensation-retirement benefits on December 31, 2006, impacted Cleco’s consolidated financial position as of December 31, 2009, 2008, 2007, and 2006 as compared to prior years. This guidance required all equity instruments, including stock options, to be expensed at their fair value.

Cleco’s consolidated financial results for 2007 included the settlement of Acadia’s pre-petition unsecured claims against CES and Calpine and amounts received by APH relating to Cajun’s purchase of CAH’s 50% equity ownership interest in Acadia, offset by a pre-tax impairment loss. For additional information, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 20 — Calpine Bankruptcy Settlement.”

Cleco’s adoption of the authoritative guidance on income taxes on January 1, 2007, impacted Cleco’s consolidated financial results for 2009, 2008, and 2007 as compared to prior years. The guidance impacted the financial statement presentation and timing of the recognition of uncertain tax positions.

Five-Year Selected Financial Data

(THOUSANDS, EXCEPT PER SHARE AND PERCENTAGES)	2009			2008			2007			2006			2005
Operating revenue, net (excluding intercompany revenue)
Cleco Power	$	842,227		$	1,069,674		$	1,023,411		$	994,191		$	911,971
Midstream		8,749			7,921			5,066			4,400			4,984
Other		2,782			2,603			2,139			2,084			3,199
Total	$	853,758		$	1,080,198		$	1,030,616		$	1,000,675		$	920,154
Income from continuing operations before income taxes	$	115,886		$	120,598		$	222,561		$	116,719		$	298,929
Net income applicable to common stock	$	106,261		$	102,095		$	151,331		$	72,856		$	180,779
Basic earnings per share applicable to common stock	$	1.77		$	1.70		$	2.55		$	1.36		$	3.54
Diluted earnings per share applicable to common stock	$	1.76		$	1.70		$	2.54		$	1.36		$	3.53
Capitalization
Common shareholders’ equity		45.77	%		48.89	%		56.74	%		57.81	%		52.15	%
Preferred stock		0.04	%		0.05	%		0.06	%		1.32	%		1.52	%
Long-term debt		54.19	%		51.06	%		43.20	%		40.87	%		46.33	%
Common shareholders’ equity	$	1,115,043		$	1,059,836		$	1,010,340		$	876,129		$	686,229
Preferred stock	$	1,029		$	1,029		$	1,029		$	20,092		$	20,034
Long-term debt, net	$	1,320,299		$	1,106,819		$	769,103		$	619,341		$	609,643
Total assets	$	3,694,847		$	3,341,204		$	2,706,623		$	2,448,067		$	2,145,172
Cash dividends declared per common share	$	0.900		$	0.900		$	0.900		$	0.900		$	0.900

CLECO POWER

The information called for by Item 6 with respect to Cleco Power is omitted pursuant to General Instruction I(2)(a) to Form 10-K (Omission of Information by Certain Wholly Owned Subsidiaries).

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

OVERVIEW

Cleco is a regional energy services holding company that conducts substantially all of its business operations through its two primary subsidiaries:

§	Cleco Power, an integrated electric utility services company regulated by the LPSC, FERC, and other regulators, which serves approximately 277,000 customers across Louisiana and also engages in energy management activities; and

Midstream, a merchant energy company regulated by FERC, which owns and operates a merchant power plant (Evangeline). At December 31, 2009, Midstream also owned a 50 percent interest in a merchant power plant (Acadia) and operated the plant on behalf of its partner. For information on Cleco Power and Entergy Louisiana each acquiring one 580-MW unit of the Acadia Power Station, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 15 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Acadia Transactions” and Note 23 — “Subsequent Events — Acadia Transaction.” For additional information on Evangeline, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 23 — Subsequent Events — Evangeline Transactions.”

For information on Cleco’s affiliated companies and the services each company provides to other affiliates, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 17 — Affiliate Transactions.”

While management believes that Cleco remains a strong company, Cleco continues to focus on several challenges and factors that could affect its results of operations and financial condition in the near term.

Cleco Power

Many factors affect Cleco Power’s primary business of selling electricity. These factors include the presence of a stable regulatory environment, which can impact cost recovery and return on equity, as well as the recovery of costs related to growing energy demand and rising fuel prices; the ability to increase energy sales while containing costs; and the ability to meet increasingly stringent regulatory and environmental standards.

In July 2008, Cleco Power filed a rate plan to establish new rates to be effective upon the commercial operation of Rodemacher Unit 3, which was February 12, 2010. Recovery of the Rodemacher Unit 3 investment was the largest component in Cleco Power’s new rate plan. As part of the new rate plan, Cleco Power requested a return on equity of 12.25%.

Cleco Power’s then-current base rates allowed it the opportunity to earn a maximum regulated return on equity of 11.65%, which was based on a return on equity of 11.25%, with any regulated earnings between 11.25% and 12.25% shared between shareholders and customers in a 40/60 ratio. All regulated earnings over 12.25% were to be returned to customers.

In October 2009, the LPSC approved Cleco Power’s new retail rate plan which includes a target return on equity of 10.7%, including returning to retail customers 60% of retail earnings between 11.3% and 12.3% and all retail earnings over 12.3%. The new rates became effective upon the commercial operation of Rodemacher Unit 3. The retail rate plan is expected to increase retail base revenues in the first twelve months of Rodemacher Unit 3 commercial operations by approximately $173.0 million with an anticipated net billing decrease for retail customers of approximately $40.0 million, or 5.0% (assuming a gas price of $5/MMBtu), including a reduction of approximately $97.0 million resulting from the cessation of the collection and the refund of Rodemacher Unit 3 construction financing costs based on a five-year crediting period. The retail rate plan established that $183.2 million be returned to customers over the five-year period. For additional information, see Part I, Item 1, “Business — Regulatory Matters, Industry Developments, and Franchises — Rates — Cleco Power’s Rate Case,” and “— Financial Condition — Liquidity and Capital Resources — Regulatory Matters —”Rodemacher Unit 3” and “— Retail Rates of Cleco Power.”

Cleco Power released a RFP in October 2007 seeking long-term resources to fill the needs identified by the latest IRP. In February 2009, Cleco Power announced that it had chosen the acquisition of 50% of the Acadia Power Station, or one of its two 580-MW units, as the lowest bid in its 2007 long-term RFP for capacity beginning in 2010. Cleco Power will own and operate one unit and operate the other 580-MW unit on behalf of Acadia or a future owner as described further under “— Midstream.” Cleco Power and the parties have executed the definitive agreements. Cleco Power received LPSC and FERC approvals for the transaction in January 2010 and February 2010, respectively. Beginning in January 2010, Acadia operated the plant and served Cleco Power under a tolling agreement covering 50% of the Acadia Power Station. The tolling agreement was approved by the LPSC in October 2009 and by FERC in December 2009. The tolling agreement was terminated when the transaction closed in February 2010. The transaction was consummated through a $304.0 million equity contribution from Cleco Corporation to Cleco Power.

Cleco Power’s construction of Rodemacher Unit 3 and Cleco Power’s acquisition of 50% of Acadia were driven by primary objectives to diversify fuel mix, stabilize fuel costs, and develop reliable sources of generating capacity to meet customers’ long-term power needs. With Rodemacher Unit 3 commencing commercial operations on February 12, 2010, and Cleco Power completing the transaction with Acadia, Cleco Power will more than double its rate base and diversify the fuel mix of its generating portfolio.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

Midstream

In recent years, Acadia has marketed short-, mid- and long-term products where available. Through its third-party energy marketer, Acadia has pursued opportunities in the hourly, weekly, monthly, and annual markets. Acadia’s success in these marketing efforts was a primary driver of its earnings and cash flow. During 2009, Acadia’s revenues were primarily derived from two short-term capacity agreements with Cleco Power and NRG Power Marketing, Inc. that were managed by the third-party energy marketer.

In February 2009, Cleco Power announced that it had selected Acadia’s proposal to fulfill Cleco Power’s capacity and energy needs as defined in the Cleco Power 2007 long-term RFP. Under the proposed arrangement, Cleco Power would acquire and operate one of Acadia’s generating units and operate the other unit, as described further above under “— Cleco Power.”

In October 2009, Acadia and Entergy Louisiana announced that definitive agreements had been executed whereby Entergy Louisiana would purchase 50% of the Acadia Power Station, or one of its two 580-MW units. The transaction is anticipated to be completed in late 2010 or early 2011. The agreements provide that, beginning in May 2010, Acadia will serve Entergy Louisiana under a tolling agreement covering 50% of the Acadia Power Station until the sale is completed. Both the asset sale and interim tolling agreement require regulatory approval. Cleco Power will continue to operate both units at Acadia after the Entergy Louisiana transaction is completed.

Midstream’s other source of revenue, which will be its principal source of revenue upon completion of the Acadia transactions described above, will be from its new tolling agreement at Evangeline, under which the counterparty has the right to dispatch the electric generation capacity of the facility. For additional information on Evangeline’s new tolling agreement, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 23 — Subsequent Events — Evangeline Transactions.”

RESULTS OF OPERATIONS

Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Actual results could differ materially from those estimates.

Cleco Consolidated Results of Operations —

Year ended December 31, 2009,

Compared to Year ended December 31, 2008

				FOR THE YEAR ENDED DECEMBER 31,
							FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2009			2008			VARIANCE			CHANGE
Operating revenue, net	$	853,758		$	1,080,198		$	(226,440	)		(21.0	)%
Operating expenses		746,949			965,321			218,372			22.6	%
Operating income	$	106,809		$	114,877		$	(8,068	)		(7.0	)%
Interest income	$	1,512		$	5,417		$	(3,905	)		(72.1	)%
Allowance for other funds used during construction	$	73,269		$	64,953		$	8,316			12.8	%
Equity loss from investees	$	(17,423	)	$	(5,542	)	$	(11,881	)		(214.4	)%
Other income	$	5,581		$	1,263		$	4,318			341.9	%
Other expense	$	2,807		$	7,970		$	5,163			64.8	%
Interest charges	$	51,055		$	52,400		$	1,345			2.6	%
Federal and state income taxes	$	9,579		$	18,457		$	8,878			48.1	%
Net income applicable to common stock	$	106,261		$	102,095		$	4,166			4.1	%

Consolidated net income applicable to common stock increased $4.2 million, or 4.1%, in 2009 compared to 2008 primarily due to increased corporate earnings. Increased corporate earnings were primarily driven by lower interest charges and lower other expenses as discussed in further detail below. Partially offsetting this increase were lower earnings at Cleco Power and higher losses at Midstream.

Operating revenue, net decreased $226.4 million, or 21.0%, in 2009 compared to 2008 largely as a result of lower fuel cost recovery revenue at Cleco Power.

Operating expenses decreased $218.4 million, or 22.6%, in 2009 compared to 2008 primarily due to lower per-unit costs and volumes of purchased power for utility customers.

Interest income decreased $3.9 million, or 72.1%, in 2009 compared to 2008 primarily due to lower interest rates and lower average investment balances. Also contributing to the decrease was a lower recovery of interest costs relating to Cleco Power’s lower deferred lignite mining costs.

Allowance for other funds used during construction increased $8.3 million, or 12.8%, in 2009 compared to 2008, primarily due to increased construction activity at Rodemacher Unit 3.

Equity loss from investees increased $11.9 million, or 214.4%, in 2009 compared to 2008 primarily due to equity losses at Evangeline primarily from higher interest on uncertain tax positions and higher equity losses at APH.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

Other income increased $4.3 million, or 341.9%, in 2009 compared to 2008 primarily due to the recognition of an increase in the cash surrender value of life insurance policies at Cleco Corporation and higher mutual assistance revenue at Cleco Power.

Other expense decreased $5.2 million, or 64.8%, in 2009 compared to 2008 primarily due to the absence in 2009 of decreases in the cash surrender value of life insurance policies at Cleco Corporation during 2008. Partially offsetting this decrease were higher mutual assistance expenses at Cleco Power.

Interest charges decreased $1.3 million, or 2.6%, in 2009 compared to 2008 primarily due to lower interest charges at Cleco Corporation from interest related to uncertain tax positions, the favorable settlement of a franchise tax lawsuit, and the repayment of senior notes. These decreases were partially offset by higher net interest charges at Cleco Power as discussed below.

Federal and state income taxes decreased $8.9 million, or 48.1%, in 2009 compared to 2008 primarily due to a decrease in pre-tax income, excluding equity AFUDC, the flow through of state tax benefits to customers, and tax credits utilized in 2009. The effective income tax rate is less than the expected statutory rate due to the significant impact of flow-through treatment on electric plant-related differences such as equity AFUDC.

Results of operations for Cleco Power and Midstream are more fully described below.

CLECO POWER

Significant Factors Affecting Cleco Power

Revenue is primarily affected by the following factors:

As an electric utility, Cleco Power is affected, to varying degrees, by a number of factors influencing the electric utility industry in general. These factors include, among others, an increasingly competitive business environment, the cost of compliance with environmental and reliability regulations, conditions in the credit markets and global economy, and changes in the federal and state regulation of generation, transmission, and the sale of electricity. For a discussion of various regulatory changes and competitive forces affecting Cleco Power and other electric utilities, see Part I, Item 1 “Business — Regulatory Matters, Industry Developments, and Franchises — Franchises” and “— Financial Condition — Market Restructuring.” For a discussion of risk factors affecting Cleco Power’s business, see Item 1A, “Risk Factors — Global Economic Downturn,” “— Future Electricity Sales,” “— Fuel Cost Audits,” “— Hedging and Risk Management Activities,” “— Transmission Constraints,” “— Commodity Prices,” “— Cleco Power Generation Facilities,” “— ERO,” “— Environmental Compliance,” “— Regulatory Compliance,” “— Weather Sensitivity,” “— Retail Electric Service,” “— Wholesale Electric Service,” “— Cleco Credit Ratings,” “— Interest Rate Swap,” and “— Cleco Power’s Rates.”

Cleco Power’s residential customers’ demand for electricity largely is affected by weather. Weather generally is measured in cooling degree-days and heating degree-days. A cooling degree-day is an indication of the likelihood that a consumer will use air conditioning, while a heating degree-day is an indication of the likelihood that a consumer will use heating. An increase in heating degree-days does not produce the same increase in revenue as an increase in cooling degree-days, because alternative heating sources are more available and because winter energy is priced below the rate charged for energy used in the summer. Normal heating degree-days and cooling degree-days are calculated for a month by separately calculating the average actual heating and cooling degree-days for that month over a period of 30 years.

Cleco Power’s expected retail sales are dependent upon factors such as weather conditions, natural gas prices, customer conservation efforts, retail marketing and business development programs, and the economy of Cleco Power’s service area. Cleco Power has experienced over the last five years, and anticipates over the next five years, moderate growth in sales volume except for sales to industrial customers. Two large industrial customers have installed cogeneration, another has discontinued a portion of its product line, and another has ceased operations. The decrease in sales attributed to these four customers is approximately 321,000 MWh. After this initial decrease attributable to these customers, Cleco Power anticipates moderate growth on the remaining industrial sales over the next five years.

Other issues facing the electric utility industry that could affect sales include:

§	imposition of federal and/or state renewable portfolio standards;

§	imposition of energy efficiency mandates;

§	legislative and regulatory changes;

§	increases in environmental regulations and compliance costs;

§	cost of power impacted by the price increases of natural gas, the addition of lower cost solid-fuel plants, and the addition of additional generation capacity;

§	increase in capital and operations and maintenance costs due to higher construction and labor costs;

§	retention or loss of large industrial customers and municipal franchises;

§	changes in electric rates compared to customers’ ability to pay;

§	access to transmission systems;

§	need for additional transmission capacity for reliability purposes;

§	turmoil in the credit markets and global economy; and

§	implementation of automated metering initiatives or smart grid technologies.

For more information on energy legislation in regulatory matters that could affect Cleco, see “— Financial Condition — Market Restructuring — Wholesale Electric Markets.”

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

Cleco Power’s revenues and earnings also are substantially affected by regulatory proceedings known as rate cases. During those cases, the LPSC determines Cleco Power’s rate base, depreciation rates, operation and maintenance costs, and administrative and general costs that Cleco Power may recover from its customers through the rates charged for electric service. These proceedings may examine, among other things, the prudence of Cleco Power’s operation and maintenance practices, level of subject expenditures, allowed rates of return, and previously incurred capital expenditures. The LPSC has the authority to disallow costs found not to have been prudently incurred. These regulatory proceedings typically involve multiple parties, including governmental bodies and officials, consumer advocacy groups, and various consumers of energy, who have differing concerns but who have the common objective of limiting rate increases or reducing rates. Rate cases generally have long timelines, which may be limited by statute. Decisions are typically subject to appeal, potentially leading to additional uncertainty.

In October 2009, the LPSC voted unanimously to approve the retail rate plan that Cleco Power filed to increase its base rates for electricity. The retail rate plan became effective upon the commercial operation of Rodemacher Unit 3, which was February 12, 2010. For additional information see “— Overview — Cleco Power.”

Other expenses are primarily affected by the following factors:

The majority of Cleco Power’s non-fuel cost recovery expenses consist of other operations, maintenance, depreciation, and taxes other than income taxes. Other operations expenses are affected by, among other things, the cost of employee benefits, insurance expenses, and the costs associated with energy delivery and customer service. Maintenance expenses associated with Cleco Power’s plants generally depend upon their physical characteristics, as well as the effectiveness of their preventive maintenance programs. Transmission and distribution maintenance expenses are generally affected by the level of repair and rehabilitation of lines to maintain reliability. Depreciation expense primarily is affected by the cost of the facility in service, the time the facility was placed in service, and the estimated useful life of the facility. Taxes other than income taxes generally include payroll taxes and ad valorem taxes. Cleco Power anticipates certain non-fuel cost recovery expenses to be higher in 2010 compared to 2009. These expenses include higher depreciation expense, higher generation expenses related to operations and maintenance, and higher salaries and benefits. In addition, Cleco Power expects the implementation of the Pension Protection Act, in conjunction with material pension plan portfolio losses in 2008, will result in annual pension contributions going-forward that are significantly higher than estimates calculated in prior years. For additional information, see “— Regulatory Matters — Pension Protection Act of 2006.”

Cleco Power’s Results of Operations —

Year ended December 31, 2009,

Compared to Year ended December 31, 2008

					FOR THE YEAR ENDED DECEMBER 31,
					FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2009		2008		VARIANCE			CHANGE
Operating revenue
Base	$	355,091	$	352,120	$	2,971			0.8	%
Fuel cost recovery		453,555		680,850		(227,295	)		(33.4	)%
Other operations		33,558		36,675		(3,117	)		(8.5	)%
Affiliate revenue		23		29		(6	)		(20.7	)%
Intercompany revenue		1,372		2,008		(636	)		(31.7	)%
Total operating revenue		843,599		1,071,682		(228,083	)		(21.3	)%
Operating expenses
Fuel used for electric generation – recoverable		253,911		226,250		(27,661	)		(12.2	)%
Power purchased for utility customers – recoverable		199,619		454,649		255,030			56.1	%
Non-recoverable fuel and power purchased		24,832		26,068		1,236			4.7	%
Other operations		99,704		93,288		(6,416	)		(6.9	)%
Maintenance		47,179		43,030		(4,149	)		(9.6	)%
Depreciation		77,064		76,420		(644	)		(0.8	)%
Taxes other than income taxes		29,758		31,011		1,253			4.0	%
Loss on sales of assets		70		-		(70	)		-
Total operating expenses		732,137		950,716		218,579			23.0	%
Operating income	$	111,462	$	120,966	$	(9,504	)		(7.9	)%
Interest income	$	1,449	$	3,943	$	(2,494	)		(63.3	)%
Allowance for other funds used during construction	$	73,269	$	64,953	$	8,316			12.8	%
Other income	$	2,370	$	1,467	$	903			61.6	%
Other expense	$	3,525	$	2,258	$	(1,267	)		(56.1	)%
Interest charges	$	58,562	$	47,283	$	(11,279	)		(23.9	)%
Federal and state income taxes	$	15,297	$	27,956	$	12,659			45.3	%
Net income	$	111,166	$	113,832	$	(2,666	)		(2.3	)%

Cleco Power’s net income for 2009 decreased $2.7 million, or 2.3%, compared to 2008. Contributing factors include:

§	higher other operations and maintenance expenses,

§	higher interest charges,

§	lower interest income,

§	lower other operations revenue, and

§	higher other expense.

These were partially offset by:

§	higher allowance for other funds used during construction,

§	higher base revenue,

§	lower effective income tax rate,

§	lower taxes other than income taxes, and

§	lower non-recoverable fuel and power purchased.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

	FOR THE YEAR ENDED DECEMBER 31,
			FAVORABLE/
(MILLION kWh)	2009	2008	(UNFAVORABLE)
Electric sales
Residential	3,637	3,545	2.6 %
Commercial	2,484	2,450	1.4 %
Industrial	2,232	2,898	(23.0)%
Other retail	136	134	1.5 %
Total retail	8,489	9,027	(6.0)%
Sales for resale	560	441	27.0 %
Unbilled	60	16	275.0 %
Total retail and wholesale customer sales	9,109	9,484	(4.0)%

	FOR THE YEAR ENDED DECEMBER 31,
					FAVORABLE/
(THOUSANDS)	2009		2008		(UNFAVORABLE)
Electric sales
Residential	$	157,672	$	154,001		2.4	%
Commercial		95,453		94,226		1.3	%
Industrial		50,957		55,560		(8.3	)%
Other retail		5,715		5,589		2.3	%
Storm surcharge		19,661		21,105		(6.8	)%
Total retail		329,458		330,481		(0.3	)%
Sales for resale		23,371		19,685		18.7	%
Unbilled		2,262		1,954		15.8	%
Total retail and wholesale customer sales	$	355,091	$	352,120		0.8	%

The following chart shows how cooling and heating degree-days varied from normal conditions and from the prior period. Cleco Power uses temperature data collected by the National Oceanic and Atmospheric Administration to determine cooling and heating degree-days.

			FOR THE YEAR ENDED DECEMBER 31,
				2009 CHANGE
	2009	2008	NORMAL	PRIOR YEAR	NORMAL
Cooling degree-days	2,977	2,923	2,662	1.8 %	11.8 %
Heating degree-days	1,447	1,437	1,645	0.7 %	(12.0)%

Base

Base revenue during 2009 increased $3.0 million, or 0.8%, compared to 2008 primarily due to Cleco Power providing service to a new wholesale customer that commenced in April 2009 and higher residential sales primarily from an increase in the number of customers served. Partially offsetting these increases were lower sales to industrial customers largely as a result of decreased production at one of Cleco Power’s large industrial customers and the start of a large customer cogenerating a portion of its electricity requirements. Cleco Power’s future industrial sales, including customers in the wood and paper industries, may continue to decrease as a result of customers beginning self-generation operations and customers decreasing their production lines. In December 2009, one of Cleco Power’s large industrial customers closed its operations. Cleco Power’s annual base revenue billings to this customer were expected to be approximately $2.3 million in 2010. For information on other effects of future energy sales on Cleco Power’s financial condition, results of operations, and cash flows, see Part I, Item 1A, “Risk Factors — Future Electricity Sales.” When Rodemacher Unit 3 achieved commercial operations on February 12, 2010, Cleco Power began returning amounts collected to customers, as established in Cleco Power’s retail rate plan over a period of five years. Over the five-year period, base revenue will be reduced $40.2 million, representing the amortization of this regulatory asset. For additional information, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 3 — Regulatory Assets and Liabilities — Deferred Construction Carrying Costs.”

Fuel Cost Recovery

Fuel cost recovery revenue billed to customers during 2009 compared to 2008 decreased $227.3 million, or 33.4%, primarily due to decreases in the per-unit cost and volume of power purchased for utility customers. Partially offsetting the decrease were increases in the per-unit cost and volume of fuel used for electric generation.

Other Operations

Other operations revenue decreased $3.1 million, or 8.5%, in 2009 compared to 2008, primarily due to $2.6 million of lower transmission revenue, customer fees, and pole attachment revenue. Also contributing to the decrease was a $0.5 million net loss relating to economic hedge transactions associated with fixed-price power being provided to a wholesale customer. For information on Cleco’s energy commodity activities, see Item 7A, “Quantitative and Qualitative Disclosures about Market Risk — Risk Overview — Commodity Price Risks.”

Operating Expenses

Operating expenses decreased $218.6 million, or 23.0%, in 2009 compared to 2008. Fuel used for electric generation (recoverable) increased $27.7 million, or 12.2%, primarily due to higher per-unit costs of fuel used as compared to the same period of 2008, as a result of realized losses on fuel hedging due to lower natural gas prices. Also contributing to the increase were higher fuel costs deferred in prior periods and higher volumes of fuel used for electric generation. Power purchased for utility customers (recoverable) decreased $255.0 million, or 56.1%, largely due to lower per-unit costs and volumes of purchased power. Fuel used for electric generation and power purchased for utility customers generally are influenced by natural gas prices, as well as availability of transmission. However, other factors such as scheduled and/or unscheduled outages, unusual maintenance or repairs, or other developments may affect fuel used for electric generation and power purchased for utility customers. Non-recoverable fuel and power purchased decreased $1.2 million, or 4.7%, primarily due to lower non-recoverable expenses primarily related to fixed-price power being provided to a wholesale customer. Partially offsetting this decrease were higher net capacity charges. Other operations expense increased $6.4 million, or 6.9%, primarily due to higher general liability expense, and higher employee benefit costs and administrative expenses. Maintenance expenses during 2009 increased $4.1 million, or 9.6%, compared to 2008 primarily due to a planned major outage at one of Cleco Power’s generating facilities during 2009. Taxes other than income taxes

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

decreased $1.3 million, or 4.0%, primarily due to lower franchise fees.

Interest Income

Interest income decreased $2.5 million, or 63.3%, during 2009 compared to 2008 primarily due to a lower recovery of interest costs relating to Cleco Power’s lower balance of deferred lignite mining costs and lower interest rates and lower average investment balances.

Allowance for Other Funds Used During Construction

Allowance for other funds used during construction increased $8.3 million, or 12.8%, during 2009 compared to 2008 primarily due to increased construction activity at Rodemacher Unit 3. Allowance for other funds used during construction comprised 65.9% of Cleco Power’s net income for 2009, compared to 57.1% for 2008. Through December 2009, Cleco Power was recording AFUDC associated with the construction of Rodemacher Unit 3. Cleco Power ceased recording AFUDC related to Rodemacher Unit 3 on February12, 2010, the commercial operation date of Rodemacher Unit 3.

Other Income

Other income increased $0.9 million, or 61.6%, during 2009 compared to 2008 primarily due to higher revenue from mutual assistance to other utilities for restoration efforts, partially offset by other miscellaneous income.

Other Expense

Other expense increased $1.3 million, or 56.1%, during 2009 compared to 2008 primarily due to higher expenses from mutual assistance to other utilities for restoration efforts.

Interest Charges

Interest charges increased $11.3 million, or 23.9%, during 2009 compared to 2008 primarily due to $8.3 million related to the May 2008 issuance of senior notes, $6.6 million related to the December 2008 issuance of GO Zone bonds, $2.5 million on tax related items, $1.2 million related to the March 2008 issuance of storm recovery bonds, and $1.1 million related to solid waste disposal facility bonds. Partially offsetting these increases were the capitalization of an additional $6.5 million of allowance for borrowed funds used during construction associated with Rodemacher Unit 3 and $1.9 million of lower net other miscellaneous charges.

Income Taxes

Federal and state income taxes decreased $12.7 million, or 45.3%, during 2009 compared to 2008, primarily due to a decrease in pre-tax income, excluding equity AFUDC, and the flow through of state tax benefits to customers. The effective income tax rate is less than the expected statutory rate due to the significant impact of flow-through treatment on electric plant-related differences such as equity AFUDC.

MIDSTREAM

Significant Factors Affecting Midstream

Earnings are primarily affected by the following factors:

Midstream’s equity earnings from investees were derived in 2009 primarily from the Evangeline Tolling Agreement with JPMVEC, which prior to November 2007, was with Williams, and from its 50% interest in Acadia, which derived its revenue from energy sales. In 2009, Acadia’s revenues were primarily derived from two short-term capacity agreements with Cleco Power and NRG Power Marketing, Inc. that were managed by the third party marketer. On February 22, 2010, Evangeline and JPMVEC terminated the existing tolling agreement and entered into a new tolling agreement. Revenue from tolling contracts generally is affected by the availability and efficiency of the facility and the level at which it operates. A facility’s availability requirements can be satisfied by providing replacement power to the tolling counterparties. A tolling agreement gives the tolling counterparty the right to own, dispatch, and market all of the electric generation capacity of the respective facility. JPMVEC is responsible for providing its own natural gas to Evangeline. JPMorgan Chase & Co. guaranteed JPMVEC’s obligations under the Evangeline Tolling Agreement and is also guaranteeing JPMVEC’s obligations under the Evangeline 2010 Tolling Agreement.

Under the tolling agreement, JPMVEC pays Evangeline a fixed fee and a variable fee for operating and maintaining the facility. The Evangeline Tolling Agreement was accounted for as an operating lease. For additional information on Cleco’s operating leases, see “— Critical Accounting Policies — Midstream.” Equity income from the Evangeline Tolling Agreement correlated with the seasonal usage of the plant. Evangeline’s 2009 revenue was recognized in the following manner:

§	17% in the first quarter;

§	22% in the second quarter;

§	43% in the third quarter; and

§	18% in the fourth quarter.

Evangeline’s 2010 revenue is anticipated to be recognized in a similar manner; however, revenue under the Evangeline 2010 Tolling Agreement will be reflected in operating revenue. The new tolling agreement will be accounted for as an operating lease. For additional information on recognition of revenue from the Evangeline Tolling Agreement, see “— Critical Accounting Policies — Midstream” and Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 2 — Summary of Significant Accounting Policies — Revenue and Fuel Costs — Equity Income” and Note 23 — “Subsequent Events — Evangeline Transactions.”

For additional information on the factors affecting Midstream, see Part I, Item 1A, “Risk Factors — Evangeline and Acadia Generation Facilities.”

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

Expenses are primarily affected by the following factors:

Midstream’s expenses include depreciation, maintenance, and other operations expenses. Depreciation expense is affected by the cost of the facility in service, the time the facility was placed in service, and the estimated useful life of the facility. Maintenance expenses generally depend on the physical characteristics of the facility, the frequency and duration of the facility’s operations, and the effectiveness of preventive maintenance. Other operating expenses mainly relate to administrative expenses, employee benefits, and generation operating expenses.

Other Factors Affecting Midstream

Evangeline

In accordance with the authoritative guidance on consolidations, Cleco reported its investment in Evangeline on the equity method of accounting and reflected Evangeline’s net operating results in the equity income (loss) from investees’ line during 2009 and prior years presented. Effective January 1, 2010, the requirements for consolidation changed. On and after January 1, 2010, Evangeline’s assets, liabilities, revenues, expenses, and cash flows will be presented in the appropriate line items of the consolidated financial statements. For additional information, see “— Critical Accounting Policies” below. For additional information on the consolidation guidelines and the equity method of accounting related to Evangeline, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 13 — Equity Investment in Investees.” On February 22, 2010, Evangeline and JPMVEC executed the Evangeline 2010 Tolling Agreement. For additional information, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 23 — Subsequent Events — Evangeline Transactions.”

Midstream’s Results of Operations —

Year ended December 31, 2009,

Compared to Year ended December 31, 2008

	FOR THE YEAR ENDED DECEMBER 31,
							FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2009			2008			VARIANCE			CHANGE
Operating revenue
Other operations	$	1		$	1		$	-			-
Affiliate revenue		8,748			7,920			828			10.5	%
Total operating revenue		8,749			7,921			828			10.5	%
Operating expenses
Other operations		6,292			6,670			378			5.7	%
Maintenance		3,887			3,800			(87	)		(2.3	)%
Depreciation		177			307			130			42.3	%
Taxes other than income taxes		403			395			(8	)		(2.0	)%
Loss (gain) on sales of assets		5			(99	)		(104	)		(105.1	)%
Total operating expenses		10,764			11,073			309			2.8	%
Operating loss		(2,015	)		(3,152	)		1,137			36.1	%
Equity loss from investees	$	(19,339	)	$	(7,037	)	$	(12,302	)		(174.8	)%
Federal and state income tax benefit	$	(11,027	)	$	(7,182	)	$	3,845			53.5	%
Net loss	$	(17,730	)	$	(10,017	)	$	(7,713	)		(77.0	)%

Factors affecting Midstream during 2009 are described below.

Operating Revenue

Operating revenue increased $0.8 million, or 10.5%, in 2009 compared to 2008. The increase was primarily due to additional employees hired by Generation Services for the benefit of Midstream to provide power plant operations, maintenance, and engineering services to Acadia and Evangeline. As a result, revenue associated with these services is included in affiliate revenue.

Operating Expenses

Operating expenses decreased $0.3 million, or 2.8%, in 2009 compared to 2008. The decrease was primarily due to lower outside consulting fees and lower employee benefit costs and administrative expenses. These expenses were partially offset by higher expenses due to additional employees hired by Generation Services for the benefit of Midstream to provide power plant operations, maintenance, and engineering services to Acadia and Evangeline.

Equity Loss from Investees

Equity loss from investees increased $12.3 million, or 174.8%, in 2009 compared to 2008. The increase was due to a $6.3 million decrease in equity earnings at Evangeline and a $6.0 million increase in equity losses at APH. The decreased earnings at Evangeline were primarily from higher interest related to uncertain tax positions, partially offset by lower maintenance expenses and the absence in 2009 of replacement power purchases that were made in 2008 as a result of an unplanned outage. The increased loss at APH was primarily due to outages at the facility during 2009, resulting in higher removal and retirement costs and higher turbine and general

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

maintenance expenses. Also contributing to the increased losses were higher legal fees associated with the sale transactions. These decreases were partially offset by higher net revenue from Acadia's short-term tolling agreement with Cleco Power and lower depreciation expense resulting from certain Acadia assets meeting the criteria of assets held for sale, at which point depreciation of these assets ceased. For additional information, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 13 — Equity Investment in Investees — Acadia.”

Income Taxes

Federal and state income taxes decreased $3.8 million, or 53.5%, during 2009 compared to 2008, primarily due to a decrease in pre-tax income.

Cleco Consolidated Results of Operations —

Year ended December 31, 2008,

Compared to Year ended December 31, 2007

				FOR THE YEAR ENDED DECEMBER 31,
						FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2008			2007		VARIANCE			CHANGE
Operating revenue, net	$	1,080,198		$	1,030,616	$	49,582			4.8	%
Operating expenses		965,321			933,072		(32,249	)		(3.5	)%
Operating income	$	114,877		$	97,544	$	17,333			17.8	%
Interest income	$	5,417		$	11,754	$	(6,337	)		(53.9	)%
Allowance for other funds used during construction	$	64,953		$	32,955	$	31,998			97.1	%
Equity (loss) income from investees	$	(5,542	)	$	93,148	$	(98,690	)		(105.9	)%
Other income	$	1,263		$	29,531	$	(28,268	)		(95.7	)%
Other expense	$	7,970		$	4,405	$	(3,565	)		(80.9	)%
Interest charges	$	52,400		$	37,966	$	(14,434	)		(38.0	)%
Federal and state income taxes	$	18,457		$	70,772	$	52,315			73.9	%
Net income applicable to common stock	$	102,095		$	151,331	$	(49,236	)		(32.5	)%

Consolidated net income applicable to common stock decreased $49.2 million, or 32.5%, in 2008 compared to 2007 primarily due to decreased Midstream and Corporate earnings. Partially offsetting these decreases were increased Cleco Power earnings.

Operating revenue, net increased $49.6 million, or 4.8%, in 2008 compared to 2007 largely as a result of higher fuel cost recovery revenue at Cleco Power.

Operating expenses increased $32.2 million, or 3.5%, in 2008 compared to 2007 primarily due to higher fuel costs at Cleco Power.

Interest income decreased $6.3 million, or 53.9%, in 2008 compared to 2007 primarily due to lower interest rates and lower average investment balances.

Allowance for other funds used during construction increased $32.0 million, or 97.1%, in 2008 compared to 2007, primarily due to increased construction activity at Rodemacher Unit 3.

Equity income from investees decreased $98.7 million, or 106.0%, in 2008 compared to 2007. The decrease primarily was due to decreased equity earnings at APH, resulting from the $78.2 million 2007 settlement of Acadia’s claims against CES and Calpine and $60.0 million received by APH during 2007 relating to Cajun’s purchase of CAH’s 50% equity ownership interest in Acadia, offset by a $45.8 million pre-tax impairment loss.

Other income decreased $28.3 million, or 95.7%, in 2008 compared to 2007 as a result of amounts received by APH during 2007 relating to Cajun’s purchase of CAH’s 50% equity ownership interest in Acadia. For additional information, see “— Midstream — Equity Income from Investees” and “— Other Income.”

Other expense increased $3.6 million, or 80.9%, in 2008 compared to 2007 primarily due to a decrease in the cash surrender value of life insurance policies at Cleco Corporation. Partially offsetting this increase was APH’s payment in 2007 to acquire Calpine’s interest in Acadia’s claim against Cleco Power regarding a potential electric metering error at the Acadia facility.

Interest charges increased $14.4 million, or 38.0%, in 2008 compared to 2007 primarily due to the carrying cost of the tax benefits of storm damage costs, a favorable 2007 settlement with the IRS, and interest related to the issuances of new senior notes, solid waste disposal facility bonds, GO Zone bonds, and storm recovery bonds. Partially offsetting this increase was the allowance for borrowed funds used during construction associated with the construction activity at Rodemacher Unit 3, the repayments of medium-term and senior notes at Cleco Power and Cleco Corporation, respectively, the storm damage surcredit, and interest related to retainage from Shaw.

Federal and state income taxes decreased $52.3 million, or 73.9%, in 2008 compared to 2007 primarily due to a decrease in pre-tax income, excluding equity AFUDC. The effective income tax rate is less than the expected statutory rate due to the significant impact of flow-though treatment on electric plant-related differences such as equity AFUDC.

Results of operations for Cleco Power and Midstream are more fully described below.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

Cleco Power’s Results of Operations —

Year ended December 31, 2008,

Compared to Year ended December 31, 2007

					FOR THE YEAR ENDED DECEMBER 31,
					FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2008		2007		VARIANCE			CHANGE
Operating revenue
Base	$	352,120	$	353,562	$	(1,442	)		(0.4	)%
Fuel cost recovery		680,850		634,631		46,219			7.3	%
Other operations		36,675		35,176		1,499			4.3	%
Affiliate revenue		29		42		(13	)		(31.0	)%
Intercompany revenue		2,008		2,008		-			-
Total operating revenue		1,071,682		1,025,419		46,263			4.5	%
Operating expenses
Fuel used for electric generation – recoverable		226,250		264,975		38,725			14.6	%
Power purchased for utility customers – recoverable		454,649		369,659		(84,990	)		(23.0	)%
Non-recoverable fuel and power purchased		26,068		24,567		(1,501	)		(6.1	)%
Other operations		93,288		97,320		4,032			4.1	%
Maintenance		43,030		46,704		3,674			7.9	%
Depreciation		76,420		78,522		2,102			2.7	%
Taxes other than income taxes		31,011		37,658		6,647			17.7	%
Loss on sales of assets		-		15		15			100.0	%
Total operating expenses		950,716		919,420		(31,296	)		(3.4	)%
Operating income	$	120,966	$	105,999	$	14,967			14.1	%
Interest income	$	3,943	$	5,422	$	(1,479	)		(27.3	)%
Allowance for other funds used during construction	$	64,953	$	32,955	$	31,998			97.1	%
Interest charges	$	47,283	$	29,565	$	(17,718	)		(59.9	)%
Federal and state income taxes	$	27,956	$	29,613	$	1,657			5.6	%
Net income	$	113,832	$	84,673	$	29,159			34.4	%

Cleco Power’s net income for 2008 increased $29.2 million, or 34.4%, compared to 2007. Contributing factors include:

§	higher allowance for other funds used during construction,

§	lower other operations and maintenance expenses,

§	lower taxes other than incomes taxes,

§	lower depreciation expense, and

§	higher other operations revenue.

These were partially offset by:

§	higher interest charges,

§	lower interest income,

§	higher non-recoverable fuel and power purchased, and

§	lower base revenue.

	FOR THE YEAR ENDED DECEMBER 31,
			FAVORABLE/
(MILLION kWh)	2008	2007	(UNFAVORABLE)
Electric sales
Residential	3,545	3,596	(1.4)%
Commercial	2,450	2,478	(1.1)%
Industrial	2,898	3,008	(3.7)%
Other retail	134	135	(0.7)%
Total retail	9,027	9,217	(2.1)%
Sales for resale	441	473	(6.8)%
Unbilled	16	(19)	184.2 %
Total retail and wholesale customer sales	9,484	9,671	(1.9)%

	FOR THE YEAR ENDED DECEMBER 31,
						FAVORABLE/
(THOUSANDS)	2008		2007			(UNFAVORABLE)
Electric sales
Residential	$	154,001	$	157,521			(2.2	)%
Commercial		94,226		93,644			0.6	%
Industrial		55,560		56,534			(1.7	)%
Other retail		5,589		5,702			(2.0	)%
Storm surcharge		21,105		24,170			(12.7	)%
Total retail		330,481		337,571			(2.1	)%
Sales for resale		19,685		16,614			18.5	%
Unbilled		1,954		(623	)		413.6	%
Total retail and wholesale customer sales	$	352,120	$	353,562			(0.4	)%

			FOR THE YEAR ENDED DECEMBER 31,
				2008 CHANGE
	2008	2007	NORMAL	PRIOR YEAR	NORMAL
Cooling degree-days	2,923	2,999	2,663	(2.5)%	9.8 %
Heating degree-days	1,437	1,411	1,654	1.8 %	(13.1)%

Base

Base revenue during 2008 decreased $1.4 million, or 0.4%, compared to 2007. The decrease was primarily due to lower electric sales to retail and wholesale customers, generally resulting from changes in weather, hurricane-related outages, and decreases in the amount being recovered for storm restoration costs through a monthly customer surcharge and in base rates. The monthly cost to customers was reduced in March 2008 when the storm costs were financed through the issuance of storm recovery bonds by Cleco Katrina/Rita. These decreases were partially offset by higher sales to municipal customers.

Fuel Cost Recovery

Fuel cost recovery revenue billed to customers during 2008 compared to 2007 increased $46.2 million, or 7.3%, primarily due to increases in the per-unit cost of power purchased for utility customers and higher volumes of fuel used for electric generation. Partially offsetting the increase were decreased volumes of power purchased for utility customers and decreases in the per-unit cost of fuel used for electric generation.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

Other Operations

Other operations revenue increased $1.5 million, or 4.3%, in 2008 compared to 2007, primarily due to $3.7 million of higher transmission revenue, customer fees, and pole attachment revenue, partially offset by a $2.2 million net loss relating to economic hedge transactions associated with fixed-price power being provided to a wholesale customer. For information on Cleco’s energy commodity activities, see Item 7A, “Quantitative and Qualitative Disclosures about Market Risk — Risk Overview — Commodity Price Risks.”

Operating Expenses

Operating expenses increased $31.3 million, or 3.4%, in 2008 compared to 2007. Fuel used for electric generation (recoverable) decreased $38.7 million, or 14.6%, primarily due to lower per-unit costs of fuel used as compared to the same period of 2007, as a result of realized gains on fuel hedging due to the price volatility of natural gas. Partially offsetting this decrease were higher volumes of fuel used for electric generation, primarily from the absence in 2008 of plant outages as compared to the same period of 2007. Power purchased for utility customers (recoverable) increased $85.0 million, or 23.0%, primarily due to higher per-unit costs of purchased power. Partially offsetting this increase were lower volumes of purchased power. Fuel used for electric generation and power purchased for utility customers generally are influenced by natural gas prices, as well as availability of transmission. However, other factors such as scheduled and/or unscheduled outages, unusual maintenance or repairs, or other developments may affect fuel used for electric generation and power purchased for utility customers. Non-recoverable fuel and power purchased increased $1.5 million, or 6.1%, primarily due to higher capacity payments made during 2008. Other operations expense decreased $4.0 million, or 4.1%, primarily due to lower employee benefit costs and administrative expenses. Maintenance expenses during 2008 decreased $3.7 million, or 7.9%, compared to 2007 primarily due to less distribution and generating station maintenance work performed during 2008. Depreciation expense decreased $2.1 million, or 2.7%, primarily due to $3.6 million of lower storm amortization costs, partially offset by $1.5 million related to normal recurring additions to fixed assets. Taxes other than income taxes decreased $6.6 million, or 17.7%, primarily due to a change in the accounting treatment of city franchise fees as a result of an LPSC order and lower property taxes.

Interest Income

Interest income decreased $1.5 million, or 27.3%, during 2008 compared to 2007 primarily due to a lower recovery of interest costs relating to Cleco Power’s lower deferred lignite mining costs. For additional information, see “— Financial Condition — Other Matters — Lignite Deferral.”

Allowance for Other Funds Used During Construction

Allowance for other funds used during construction increased $32.0 million, or 97.1%, during 2008 compared to 2007 primarily due to increased construction activity at Rodemacher Unit 3. Allowance for other funds used during construction comprised 57.1% of Cleco Power’s net income for 2008, compared to 38.9% for 2007.

Interest Charges

Interest charges increased $17.7 million, or 59.9%, during 2008 compared to 2007 primarily due to the following: $9.6 million related to the May 2008 issuance of senior notes; $7.2 million related to the March 2008 issuance of storm recovery bonds; $3.6 million related to the November 2007 issuance of solid waste disposal facility bonds; $7.5 million related to the carrying cost of the tax benefits of storm damage costs; $6.6 million primarily related to a favorable 2007 settlement with the IRS; and $0.4 million related to the December 2008 issuance of GO Zone bonds. Partially offsetting this increase was $6.5 million of allowance for borrowed funds used during construction associated with the construction activity at Rodemacher Unit 3, $5.9 million related to the storm damage surcredit, $2.1 million related to the repayment of medium-term notes during 2007, $1.7 million related primarily to lower interest rates on Cleco Power’s credit facility, and $1.0 million related to interest on retainage from Shaw.

Income Taxes

Income tax expense decreased $1.7 million, or 5.6%, during 2008 compared to 2007, primarily due to a decrease in pre-tax income excluding equity AFUDC. The effective income tax rate is less than the expected statutory rate due to the significant impact of flow-through treatment on electric plant-related differences such as equity AFUDC.

Midstream’s Results of Operations —

Year ended December 31, 2008,

Compared to Year ended December 31, 2007

	FOR THE YEAR ENDED DECEMBER 31,
							FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2008			2007			VARIANCE			CHANGE
Operating revenue
Other operations	$	1		$	16		$	(15	)		(93.8	)%
Affiliate revenue		7,920			5,050			2,870			56.8	%
Operating revenue		7,921			5,066			2,855			56.4	%
Operating expenses
Other operations		6,670			6,289			(381	)		(6.1	)%
Maintenance		3,800			2,499			(1,301	)		(52.1	)%
Depreciation		307			306			(1	)		(0.3	)%
Taxes other than income taxes		395			316			(79	)		(25.0	)%
Gain on sales of assets		(99	)		-			99			-
Total operating expenses		11,073			9,410			(1,663	)		(17.7	)%
Operating loss		(3,152	)		(4,344	)		1,192			27.4	%
Interest income		-			1,047			(1,047	)		(100.0	)%
Equity (loss) income from investees	$	(7,037	)	$	91,581		$	(98,618	)		(107.7	)%
Other income	$	-		$	27,924		$	(27,924	)		(100.0	)%
Other expense	$	32		$	1,253		$	1,221			97.4	%
Interest charges	$	6,978		$	19,053		$	12,075			63.4	%
Federal and state income tax (benefit) expense	$	(7,182	)	$	36,585		$	43,767			119.6	%
Net (loss) income	$	(10,017	)	$	59,317		$	(69,334	)		(116.9	)%

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

Factors affecting Midstream during 2008 are described below.

Operating Revenue and Operating Expenses

Operating revenue increased $2.9 million, or 56.4%, in 2008 compared to 2007. Operating expenses increased $1.7 million, or 17.7%, in 2008 compared to 2007. The increases were primarily due to the accounting treatment of Acadia’s power plant operations, maintenance, and engineering services resulting from Cajun’s purchase of Calpine’s 50% ownership interest in Acadia in September 2007. Prior to September 2007, Calpine employees provided power plant operations, maintenance, and engineering services to Acadia. Subsequent to September 2007, these services were provided by Midstream. As a result, revenue and expenses associated with plant operations for Acadia are included in affiliate revenue and operating expenses, respectively.

Interest Income

Interest income decreased $1.0 million, or 100.0%, in 2008 compared to 2007, primarily due to lower investment balances at APH.

Equity Income from Investees

Equity income from investees decreased $98.6 million, or 107.7%, in 2008 compared to 2007. The decrease was due to a $91.5 million decrease in equity earnings at APH and a $7.1 million decrease at Evangeline. This decrease at APH was primarily due to the absence in 2008 of the settlement of Acadia’s pre-petition unsecured claims against CES and Calpine and amounts received by APH in 2007 relating to CAH’s 50% equity ownership interest in Acadia. Partially offsetting these decreases was an impairment loss recorded during 2007. The decrease at Evangeline was primarily due to higher maintenance expenses largely relating to a planned combustion turbine major inspection outage during 2008, higher maintenance expenses under Evangeline’s long-term maintenance contract, and higher other unplanned maintenance expenses as compared to 2007. As previously discussed, Midstream’s ownership interests in Perryville and Attala were transferred to Cleco Corporation effective February 1, 2007, and are no longer reported as equity income from investees on Midstream’s financial statements. In accordance with the authoritative guidance on segment reporting, operating results for prior periods have been adjusted to reflect this new structure. For additional information, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 11 — Disclosures about Segments.”

Other Income

Other income decreased $27.9 million, or 100.0%, during 2008 compared to 2007, as a result of amounts being received by APH during 2007 relating to Cajun’s purchase of CAH’s 50% equity ownership interest in Acadia. Of this amount, $25.0 million represented consideration of APH’s guaranteed payments from Acadia and $2.9 million represented break-up fees.

Other Expense

Other expense decreased $1.2 million, or 97.4%, during 2008 compared to 2007, primarily due to APH’s payment during 2007 to acquire Calpine’s interest in Acadia’s claim against Cleco Power regarding a potential electric metering error at the Acadia facility.

Interest Charges

Interest charges decreased $12.1 million, or 63.4%, during 2008 compared to 2007, primarily due to a lower interest rate and a lower balance on affiliate debt relating to APH’s investment in Acadia.

Income Taxes

Income tax expense decreased $43.8 million, or 119.6%, during 2008 compared to 2007, primarily due to a decrease in pre-tax income.

CLECO POWER LLC — NARRATIVE ANALYSIS OF RESULTS OF OPERATIONS

For a narrative analysis of the results of operations explaining the reasons for material changes in the amount of revenue and expense items of Cleco Power between the year ended December 31, 2009 and the year ended December 31, 2008, see “Results of Operations — Cleco Power’s Results of Operations — Year ended December 31, 2009, Compared to Year ended December 31, 2008.”

For a narrative analysis of the results of operations explaining the reasons for material changes in the amount of revenue and expense items of Cleco Power between the year ended December 31, 2008, and the year ended December 31, 2007, see “Results of Operations — Cleco Power’s Results of Operations — Year ended December 31, 2008, Compared to Year ended December 31, 2007.”

The narrative analyses referenced above should be read in combination with Cleco Power’s Financial Statements and the Notes contained in this Form 10-K.

CRITICAL ACCOUNTING POLICIES

Cleco’s critical accounting policies include those accounting policies that are both important to Cleco’s financial condition and results of operations and those that require management to make difficult, subjective, or complex judgments about future events, which could result in a material impact to the financial statements of Cleco Corporation’s segments or to Cleco as a consolidated entity. The financial statements contained in this report are prepared in accordance with accounting principles generally accepted in the United States of America, which require Cleco to make estimates and assumptions. Estimates and assumptions about future events and their effects cannot be made with certainty. Management bases its current estimates and assumptions on historical experience and on various other factors that are believed to be reasonable under the circumstances. On an ongoing basis, these estimates and assumptions are evaluated and, if necessary, adjustments are made when warranted by new or updated information or by a change in circumstances or

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

environment. Actual results may differ significantly from these estimates under different assumptions or conditions. For additional information on Cleco’s accounting policies, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 2 — Summary of Significant Accounting Policies.”

Cleco believes that the following are the most significant critical accounting policies for the Company:

Cleco accounts for pensions and other postretirement benefits under applicable GAAP. To determine assets, liabilities, income, and expense relating to pension and other postretirement benefits, management must make assumptions about future trends. Assumptions and estimates include, but are not limited to, discount rate, expected return on plan assets, future rate of compensation increases, and medical inflation trend rates. These assumptions are reviewed and updated on an annual basis. Changes in the rates from year to year and newly enacted laws could have a material effect on Cleco’s financial condition and results of operations by changing the recorded assets, liabilities, income, expense, or required funding of the pension plan obligation. One component of pension expense is the expected return on plan assets. It is an assumed percentage return on the market-related value of plan assets. The market-related value of plan assets differs from the fair value of plan assets by the amount of deferred asset gains or losses. Actual asset returns that differ from the expected return on plan assets are deferred and recognized in the market-related value of assets on a straight-line basis over a five-year period. The 2009 return on pension plan assets was 16.0% compared to an expected long-term return of 7.8%. For 2008, the return on plan assets was (26.9)% compared to an expected long-term return of 8.4%. During 2009, Cleco reduced its expected long-term return on plan assets from 8.4% to 7.8%. The reduction caused an increase in net pension expense of approximately $1.4 million in 2009.

Cleco uses the Citigroup Pension Liability Index, adjusted for differences in cash flows, in determining the discount rate applied to its pension plans. Management believes the use of the Citigroup Pension Index, as adjusted, is appropriate because the index’s cash flows are materially similar to those of Cleco’s pension plans. As a result of the annual review of assumptions, the discount rate decreased from 6.01% to 5.91%.

A change in the assumed discount rate creates a deferred actuarial gain or loss. Generally, when the assumed discount rate decreases compared to the prior measurement date, a deferred actuarial loss is created. When the assumed discount rate increases compared to the prior measurement date, a deferred actuarial gain is created. Actuarial gains and losses also are created when actual results, such as assumed compensation increases, differ from assumptions. The net of the deferred gains and losses is amortized to pension expense over the average service life of the remaining plan participants, 16 years for Cleco’s plan, when it exceeds certain thresholds. This approach to amortization of gains and losses has the effect of reducing the volatility of pension expense attributable to investment returns. Over time, it is not expected to reduce or increase the pension expense relative to an approach that immediately recognizes losses and gains.

The decrease in the discount rate combined with accumulated differences between assumed long-term return on plan assets and actual return is expected to increase pension expense by $0.4 million in 2010 compared to 2009. Since both assumptions are evaluated yearly, the increase may not extend past 2010.

Cleco Power made $18.8 million of discretionary contributions to the pension plan during 2009 as compared to a $6.0 million discretionary contribution to the pension plan in 2008 and none in 2007. Future discretionary contributions may be made depending on changes in assumptions, the ability to utilize the contribution as a tax deduction and requirements concerning recognizing a minimum pension liability. Currently, Cleco Power expects to be required to make $70.0 million in contributions to the pension plan over the next five years. The required contributions are driven by liability funding target percentages set by law which could cause the required contributions to be uneven among the years. The ultimate amount and timing of the contributions will be affected by changes in the discount rate, changes in the funding regulations, and actual returns on fund assets. For additional information on pensions and other postretirement benefits, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 9 — Pension Plan and Employee Benefits.”

Income tax expense and related balance sheet amounts are comprised of a “current” portion and a “deferred” portion. The current portion represents Cleco’s estimate of the income taxes payable or receivable for the current year. The deferred portion represents Cleco’s estimate of the future income tax effects of events that have been recognized in the financial statements or income tax returns in the current or prior years. Cleco makes assumptions and estimates when it records income taxes, such as its ability to deduct items on its tax returns, the timing of the deduction, and the effect of regulation by the LPSC on income taxes. Cleco’s income tax expense and related assets and liabilities could be affected by changes in its assumptions and estimates and by ultimate resolution of assumptions and estimates with taxing authorities. The actual results may differ from the estimated results based on these assumptions and may have a material effect on Cleco’s results of operations. For additional information about Cleco Corporation’s income taxes, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 10 — Income Taxes.”

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

Effective January 1, 2007, Cleco adopted the provisions of the authoritative guidance relating to uncertain tax positions. The guidelines require management to estimate the reliability of positions taken on tax returns. These estimates could differ significantly from the ultimate outcome. For additional information on the adoption of these guidelines, see Item 8, “Financial Statements and Supplemental Data — Notes to the Financial Statements — Note 2 — Summary of Significant Accounting Policies — Recent Authoritative Guidance.”

Cleco Corporation consolidates entities as required by GAAP. Generally, a parent consolidates entities in which it controls, either directly or indirectly, the majority of the voting interest. Additionally, a parent could be required to consolidate an entity in which it does not control a majority voting interest if the subsidiary is a variable interest entity and meets certain criteria making the parent the primary beneficiary of an entity. An entity is a variable interest entity if it lacks the ability to finance its activities without support from other parties; if its owners lack controlling financial interest in the entity; or if the entity either conducts substantially all of its activities with or on behalf of an investor or if voting rights are disproportional to risks and rewards. While consolidation or the equity method of accounting will not affect net income applicable to common shareholders, it may affect specific line items within the income statement, such as revenue, specific expense line items, and income from equity investees. Consolidation or the equity method of accounting of an entity will affect specific balance sheet items such as property, plant and equipment and long-term debt, which will cause changes in total assets and total liabilities. Shareholders’ equity should not be affected by consolidation or the equity method of accounting of entities. Effective January 1, 2010, the requirements for consolidation changed. The implementation of this amendment on January 1, 2010, required Cleco Corporation to consolidate three wholly owned subsidiaries that had been accounted for using the equity method. Prior to January 1, 2010, Perryville, Attala, and Evangeline were presented in the consolidated financial statements;

o	All entities’ results of operations before taxes as one line item on the consolidated statements of income entitled Equity (loss) income from investees,

o	All entities’ assets and liabilities on the consolidated balance sheets as one line item entitled Equity investment in investees, and

o	All entities’ cash flows in the consolidated statement of cash flows as return on equity investment in investee, return of equity investment in investee and equity investment in investee.

On and after January 1, 2010, all entities’ assets, liabilities, revenues, expenses and cash flows will be presented on the appropriate line items of the consolidated financial statements. Cleco has chosen to implement the consolidation prospectively and not retrospectively, therefore the consolidation will not be carried back to comparative prior periods in financial statements issued after implementation. For additional information on Perryville, Attala and Evangeline, see Item 8, “Financial Statements and Supplementary Data — Note 2 — Summary of Significant Accounting Policies — Recent Authoritative Guidance” and Note 13 — “Equity Investment in Investees.”

Part of the compensation employees and directors receive is in the form of equity instruments. The instruments may take the form of restricted stock, stock options, stock equivalent units, or other types of equity instruments as described in the compensatory plans. Cleco recognizes equity compensation at the grant date fair value for instruments settled in equity and reporting date fair value for equity compensation settled in cash. Estimates used in the calculation require management judgments and could cause volatility in earnings. For additional information on stock-based compensation, see Item 8, “Financial Statements and Supplemental Data — Notes to the Financial Statements — Note 7 — Common Stock — Stock-Based Compensation.”

Cleco Power

Cleco Power’s prices are regulated by the LPSC and FERC. By determining what costs can be recovered by Cleco Power through the price it charges its customers, regulatory assets and liabilities are recognized. Future changes made by the regulatory bodies could have a material impact on the operations and financial condition of Cleco Power. Below are three areas that could be materially impacted by future actions of regulators.

The LPSC determines the ability of Cleco Power to recover prudent costs incurred in developing long-lived assets. If the LPSC was to rule that the cost of current or future long-lived assets was imprudent and not recoverable, Cleco Power could be required to write down the imprudent cost and incur a corresponding impairment loss. At December 31, 2009, the carrying value of Cleco Power’s long-lived assets was $2.2 billion. Currently, Cleco Power has concluded that none of its long-lived assets are impaired.

Cleco Power has concluded it is probable that regulatory assets can be recovered from ratepayers in future rates. At December 31, 2009, Cleco Power had $327.5 million in regulatory assets, net of regulatory liabilities. Actions by the LPSC could limit the recovery of these regulatory assets, causing Cleco Power to record a loss on some or all of the regulatory assets. For additional information on the LPSC and regulatory assets, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 2 — Summary of Significant Accounting Policies — Regulation,” Note 3 — “Regulatory Assets and Liabilities,” and “— Financial Condition — Other Matters — Lignite Deferral.”

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

The LPSC determines the amount and type of fuel and purchased power costs that Cleco Power can charge customers through the fuel adjustment clause. Changes in the determination of allowable costs already incurred by Cleco Power could cause material changes in fuel revenue. For the years ended December 31, 2009, 2008, and 2007, Cleco Power reported fuel revenue of $453.6 million, $680.9 million, and $634.6 million, respectively.

Midstream

Generally, Midstream is most affected by market conditions and changes in contract counterparty credit ratings and financial condition. The most important are listed below.

Certain triggering events could cause Midstream to determine that its long-lived assets or its equity method investments may be impaired according to applicable accounting guidance. Triggering events which apply to long-lived assets include, but are not limited to, a significant decrease in the market value of long-lived assets, significant changes in a tolling agreement counterparty’s financial condition, a significant change in legal factors, such as adverse changes in environmental laws, or a current operating or cash flow loss combined with a projection of continued losses in the future. An equity method investment is required to be tested for impairment if an “other than temporary” decline in market value occurs. Any impairment calculated is subject to many assumptions and estimations. Management must make assumptions about expected future cash flows, long-term interest rates, estimates about the probability of the occurrence of future events, and estimates of market value of assets without a readily observable market price. Differences between the estimate made at a particular balance sheet date and actual events could cause material adjustments to an impairment charge. In September 2007, Midstream recognized an impairment of its indirect equity investment in Acadia of $45.8 million. At December 31, 2009, Midstream had $1.0 million in long-lived assets and $223.7 million in equity method investments. For additional information on the impairment charges, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 13 — Equity Investment in Investees.”

During 2009, Acadia’s long-lived assets met the criteria of held for sale. When assets are held for sale, depreciation expense ceases to be recognized and the assets are classified as current. The assets were tested for impairment. Due to the price for the assets being above the carrying cost, no impairment was recognized. If events occur that prevent the transaction from closing, some or all of Acadia’s assets might be considered as held for use, impairment recalculated and recognized, and depreciation expense would be recognized. At December 31, 2009, Acadia had $405.9 million of assets that met the criteria of held for sale. For additional information on Acadia, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 13 — Equity Investment in Investees.”

Midstream records income from Evangeline as income from an equity investment and accounts for the Evangeline Tolling Agreement as an operating lease. If the tolling agreement was to be modified to the extent that it would make lease accounting no longer appropriate, future results could materially differ from those currently reported. Under current lease accounting rules, over the first 10 years of the tolling agreement, Evangeline will recognize revenue that will not be billed and collected until the last 10 years of the tolling agreement. If lease accounting was to cease, the revenue would be recognized as billed, causing the revenue recognized in the first 10 years to be lower than it would have been under lease accounting. As of December 31, 2009, Evangeline had recorded $26.9 million in revenue that will not be billed and collected until the last 10 years of the tolling agreement, beginning in the year 2010. If the tolling agreement is modified substantially, the $26.9 million may not be collectible, and Evangeline may be required to incur a loss of some or all of the $26.9 million. In February 2010, Evangeline and JPMVEC entered into the Evangeline Restructuring Agreement. Under this agreement the existing Evangeline Tolling Agreement was terminated, and the parties entered into the Evangeline 2010 Tolling Agreement, effective March 1, 2010. The Evangeline 2010 Tolling Agreement expires on December 31, 2011, with an option for JPMVEC to extend the term of the agreement through December 31, 2012. Also, under the Evangeline Restructuring Agreement, $126.6 million of Evangeline Senior Secured bonds owned by JPMVEC were transferred to Evangeline and subsequently retired by Evangeline and $5.3 million of accrued interest associated with the Evangeline bonds transferred to Evangeline was eliminated. Cleco received a $56.7 million cash payment from JPMVEC, which was partially a settlement of the $26.9 million operating lease asset that represented the straight line recognition of a fixed escalation. The Evangeline 2010 Tolling Agreement is expected to produce lower revenues than previously expected under the Evangeline Tolling Agreement. For additional information on the Evangeline transactions, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 23 — Subsequent Events — Evangeline Transactions.”

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

FINANCIAL CONDITION

Liquidity and Capital Resources

General Considerations and Credit-Related Risks

Credit Ratings and Counterparties

Financing for operational needs and construction requirements is dependent upon the cost and availability of external funds from capital markets and financial institutions. Access to funds is dependent upon factors such as general economic and capital market conditions, regulatory authorizations and policies, Cleco Corporation’s credit rating, the credit rating of Cleco Corporation’s subsidiaries, the cash flows from routine operations, and the credit ratings of project counterparties. The following table presents the credit ratings of Cleco Corporation, Cleco Power, Evangeline, and Cleco’s tolling agreement counterparty at December 31, 2009:

	MOODY’S		STANDARD & POOR’S
	SENIOR UNSECURED DEBT	SENIOR SECURED DEBT	SENIOR UNSECURED DEBT	SENIOR SECURED DEBT
Cleco Corporation	Baa3	-	BBB-	-
Cleco Power	Baa2	-	BBB	-
Evangeline	-	Ba2	-	-

Tolling Counterparty:
JPMorgan Chase & Co.	Aa3	-	A+	-

Cleco notes that credit ratings are not recommendations to buy, sell, or hold securities and may be subject to revision or withdrawal at any time by the assigning rating agency. Each rating should be evaluated independently of any other rating.

At December 31, 2009, Moody’s and Standard & Poor’s outlooks for both Cleco Corporation and Cleco Power were stable. In November 2009, Moody’s downgraded Cleco Power’s credit rating by one level. This downgrade placed Cleco Power’s credit rating at Moody’s at a level similar to Cleco Power’s credit rating at Standard & Poor’s. Cleco Corporation and Cleco Power pay fees and interest under their bank credit agreements based on the highest rating held. If Cleco Corporation or Cleco Power’s credit rating were to be downgraded by Moody’s and Standard & Poor’s, Cleco Corporation and/or Cleco Power would be required to post additional fees and higher interest rates under their bank credit agreements. Cleco Power’s collateral for derivatives is based on the lower rating held. If Cleco Power’s credit ratings were to be downgraded by Standard & Poor’s or Moody’s, Cleco Power would be required to post additional collateral for derivatives. For additional information on the impacts of a downgrade in credit ratings, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 15 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Risks and Uncertainties — Cleco Power.”

At December 31, 2009, Moody’s outlook for Evangeline was stable. In February 2010, Evangeline and JPMVEC entered into a new tolling agreement. JPMorgan Chase & Co. is guaranteeing JPMVEC’s obligations under the Evangeline 2010 Tolling Agreement. The tolling agreement is the principal source of cash flow for Evangeline. For more information regarding the Evangeline 2010 Tolling Agreement, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 23 — Subsequent Events — Evangeline Transactions.”

In August 2005, Cleco Power entered into an EPC contract with Shaw to construct Rodemacher Unit 3. Under the terms of the Amended EPC Contract, until the final acceptance of Rodemacher Unit 3, in the event Cleco Power does not maintain a senior unsecured credit rating of either: (i) Baa3 or better from Moody’s or (ii) BBB- or better from Standard & Poor’s, Cleco Power will be required to provide a letter of credit to Shaw in the amount of $20.0 million. In the event of further downgrade to both of its credit ratings to: (i) Ba2 or below from Moody’s, and (ii) BB or below from Standard & Poor’s, Cleco Power will be required to provide an additional $15.0 million letter of credit to Shaw.

With respect to any open power or natural gas trading positions that Cleco may initiate in the future, Cleco may be required to provide credit support or pay liquidated damages. The amount of credit support that Cleco may be required to provide at any point in the future is dependent on the amount of the initial transaction, changes in the market price of power and natural gas, the changes in open power and gas positions, and changes in the amount counterparties owe Cleco. Changes in any of these factors could cause the amount of requested credit support to increase or decrease.

Global Economic Conditions

The current economic conditions may have an impact on Cleco’s business and financial condition. Although Cleco has not experienced restrictions in the financial markets, Cleco’s ability to access the capital markets may be restricted at a time when Cleco would like, or need, to do so, which could have a material impact on its ability to fund capital expenditures or debt service, or on Cleco’s flexibility to react to changing economic and business conditions. The credit constraints could have a material negative impact on Cleco’s lenders or Cleco’s customers causing them to fail to meet their obligations to Cleco or to delay payment of such obligations. The lower interest rates that Cleco has been exposed to have been beneficial to recent debt issuances; however, these rates have negatively affected interest income for Cleco’s short-term investments. Moreover, as a result of the 2008 global economic downturn, the pension plan portfolio experienced significant losses in 2008. If the market does not continue to improve, the plan could experience more losses in the future. For a discussion of certain risks related to market conditions, see Item 1A, “Risk Factors — Global Economic Downturn.”

Fair Value Measurements

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

issuance. Cleco and Cleco Power are required to disclose the fair value of certain assets and liabilities by one of three levels when required for recognition purposes under GAAP. Other financial assets and liabilities, such as long-term debt, are reported at their carrying values at their date of issuance on the consolidated balance sheets with their fair values disclosed without regard to the three levels. For more information about fair value levels, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 5 — Fair Value Accounting.”

Debt

At December 31, 2009, Cleco Corporation was in violation of a covenant under its credit facility, relating to a covenant included in the $50.0 million Cleco Power bank term loan entered into in August 2009. In February 2010, Cleco Corporation obtained a waiver from its lenders for such non-compliance. Cleco Corporation paid the lenders no fees related to this waiver.

At December 31, 2009, Cleco Power was in compliance with the covenants in its credit facilities. In August 2009, Cleco Corporation and Cleco Power entered into amendments to their respective credit facilities that increased thresholds in a representation relating to pension plan obligations above the amount of the current plan assets. Cleco Corporation and Cleco Power incurred $0.1 million in expenses obtaining bank waivers related to the amendments. If Cleco Corporation were to default under the covenants in its various credit facilities, it would be unable to borrow additional funds under the facilities. Further, if Cleco Power were to default under its credit facility, Cleco Corporation would be considered in default under its credit facility. The bonds issued by Evangeline are non-recourse to Cleco Corporation, and a default on these bonds would not be considered a default under Cleco Corporation’s credit facility. If Cleco Corporation’s credit rating were to be downgraded one level below investment grade, Cleco Corporation would be required to pay fees and interest at a rate of 0.45% higher than the current level for its $150.0 million credit facility. A similar downgrade to the credit ratings of Cleco Power would require Cleco Power to pay fees and interest at a rate of 0.60% higher than the current level on its $275.0 million credit facility.

Cleco Consolidated

Cleco had no short-term debt outstanding at December 31, 2009, or 2008. At December 31, 2009, Cleco’s long-term debt outstanding was $1.3 billion, of which $11.5 million is long-term debt due within one year, compared to $1.2 billion at December 31, 2008, which included $63.5 million long-term debt due within one year. The long-term debt due within one year represents $11.5 million of principal payments for the Cleco Katrina/Rita storm recovery bonds scheduled to be paid in the next twelve months.

For Cleco, long-term debt increased $161.4 million during 2009 primarily due to the issuance of $145.0 million of 6.50% senior notes due December 1, 2035, in November 2009, a $65.0 million increase in Cleco Corporation’s credit facility draws, the execution of a $50.0 million variable-rate monthly bank loan in August 2009, and a $19.1 million net increase in long-term capital leases. These increases were partially offset by the $50.0 million repayment of medium-term notes at maturity in May 2009, the $49.5 million repayment of insured quarterly notes in August 2009, and $13.5 million related to scheduled Cleco Katrina/Rita storm recovery bond principal payments. During January 2009, Cleco Power entered into a capital lease agreement for barges to be used for fuel transportation for Rodemacher Unit 3, causing a $19.1 million net increase in long-term debt. For additional information, see “— Cleco Corporation (Holding Company Level)” and “— Cleco Power” below, and also see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 15 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Other Contingencies — Fuel Transportation Agreement.”

At December 31, 2009, and 2008, Cleco had a working capital surplus of $252.1 million and $105.5 million, respectively. Included in working capital at December 31, 2009 and 2008, was $29.9 million and $62.3 million, respectively, which was restricted for the use of debt payments. The $146.6 million increase in working capital is primarily due to net proceeds from the issuance of bonds, partially offset by additions to property plant and equipment, including Rodemacher Unit 3.

At December 31, 2009, Cleco’s Consolidated Balance Sheet reflected $2.6 billion of total liabilities compared to $2.3 billion at December 31, 2008. The $0.3 billion increase in total liabilities was primarily due to increases in long-term debt, total other regulatory liabilities, and uncertain tax positions. As discussed above, long-term debt increased $161.4 million during 2009. The $97.3 million increase in total other regulatory liabilities from December 31, 2008, was primarily due to the increase in deferred construction carrying costs of Rodemacher Unit 3. The increase in uncertain tax positions contributed $39.5 million of the change in total liabilities. For more information on the deferred construction carrying costs of Rodemacher Unit 3, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 3 — Regulatory Assets and Liabilities — Deferred Construction Carrying Costs.” For more information on uncertain tax positions, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 10 — Income Taxes— Uncertain Tax Positions.”

Cash and cash equivalents available at December 31, 2009, were $145.2 million combined with $315.0 million facility capacity ($40.0 million from Cleco Corporation and $275.0 million from Cleco Power) for total liquidity of $460.2 million. Cash and cash equivalents available at December 31, 2009 increased $47.7 million when compared to cash and cash equivalents available at December 31, 2008. This increase is primarily due to the issuance of bonds, reduced by additions to property, plant and equipment, including Rodemacher Unit 3.

At December 31, 2009, Cleco and Cleco Power were exposed to concentrations of credit risk through their short-term

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

investments classified as cash equivalents. In order to mitigate potential credit risk, Cleco and Cleco Power have established guidelines for short-term investments. For more on the concentration of credit risk through short-term investments classified as cash equivalents, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 5 — Fair Value Accounting.”

Cleco Corporation (Holding Company Level)

Cleco Corporation had no short-term debt outstanding at December 31, 2009, or 2008. At December 31, 2009, Cleco Corporation’s long-term debt outstanding was $95.0 million, of which none was due within one year, compared to $30.0 million of long-term debt of which none was due within one year at December 31, 2008.

Cleco Corporation’s $150.0 million five-year credit facility matures on June 2, 2011. This facility provides for working capital and other needs. Cleco Corporation’s borrowing costs under the facility are equal to LIBOR plus 0.65%, including facility fees. The facility contains the following material covenants:

§	a requirement that Cleco maintain at all times total indebtedness equal to or less than 65% of total capitalization;

§	a requirement that Cleco maintain a ratio of earnings before interest, taxes, depreciation, and amortization to interest expense as of the end of any fiscal quarter of at least 2.50 to 1.00;

a prohibition against incurring debt other than under the facility, subject to the following permitted exceptions, among others: (i) up to $425.0 million (less borrowings under the facility) of specified types of other debt may be incurred; (ii) guarantees of Cleco Power obligations and (iii) other specified guarantees, up to specified amounts;

§	a prohibition against creating liens upon any property, subject to permitted exceptions;

§	restrictions on merging, consolidating, or selling assets outside the ordinary course of business;

§	limitations on the payment of dividends, redemptions or repurchases of equity securities and payments in respect of subordinated debt, subject to various exceptions;

§	a prohibition against making loans or investments, subject to permitted exceptions, including exceptions for investments of up to $10.0 million per year in subsidiaries other than Cleco Power and loans of up to $20.0 million in the aggregate to such subsidiaries;

§	a prohibition against transactions with affiliates, subject to permitted exceptions;

§	a prohibition against Cleco and Cleco Power entering into agreements or arrangements that prohibit or restrict their ability to incur liens, or Cleco Power’s ability to pay dividends or to repay debt or make payments to Cleco, subject to permitted exceptions; and

§	a prohibition against entering into speculative and other hedge agreements intended to be a borrowing of funds.

At December 31, 2009, $95.0 million was outstanding under Cleco Corporation’s $150.0 million credit facility. The weighted average interest rate of outstanding borrowings under the credit facility at December 31, 2009 was 0.763%. Off-balance sheet commitments also reduced available borrowings under the credit facility by $15.0 million, leaving available capacity of $40.0 million. An uncommitted line of credit with a bank in an amount up to $10.0 million is available to support Cleco Corporation’s working capital needs. For more information about these commitments, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 15 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Off-Balance Sheet Commitments and Disclosures about Guarantees.”

Cash and cash equivalents available at December 31, 2009, were $7.1 million, combined with $40.0 million credit facility capacity, for total liquidity of $47.1 million. Cash and cash equivalents available at December 31, 2009 increased $1.1 million when compared to cash and cash equivalents available at December 31, 2008, primarily due to routine working capital fluctuations.

Cleco Power

There was no short-term debt outstanding at Cleco Power at December 31, 2009, or 2008. At December 31, 2009, Cleco Power’s long-term debt outstanding was $1.2 billion, of which $11.5 million was due within one year, compared to $1.1 billion at December 31, 2008, of which $63.5 million was due within one year. The $11.5 million of long-term debt due within one year represents principal payments for the Cleco Katrina/Rita storm recovery bonds scheduled to be paid in the next twelve months.

For Cleco Power, long-term debt increased $96.4 million during 2009 primarily due to the issuance of $145.0 million of 6.50% senior notes, due December 1, 2035, in November 2009, the execution of a $50.0 million variable-rate monthly bank loan in August 2009, and a $19.1 million net increase in long-term capital leases. These increases were partially offset by the $50.0 million repayment of a medium-term note at maturity in May 2009, the $49.5 million repayment of insured quarterly notes in August 2009, and $13.5 million of scheduled principal payments for the Cleco Katrina/Rita storm recovery bonds. During January 2009, Cleco Power entered into a capital lease agreement for barges to be used for fuel transportation for Rodemacher Unit 3, causing a $19.1 million net increase in long-term debt. For additional information regarding the barge lease, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 15 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Other Contingencies — Fuel Transportation Agreement.”

Cleco Power’s $275.0 million five-year credit facility matures on June 2, 2011. This facility provides for working capital and other needs. Cleco Power’s borrowing costs under the facility are equal to LIBOR plus 0.50%, including facility fees. The facility includes the following material covenants:

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

§	a requirement that Cleco Power maintain at all times total indebtedness equal to or less than 65% of total capitalization;

§	a requirement that Cleco Power maintain a ratio of earnings before interest, taxes, depreciation, and amortization to interest expense as of the end of any fiscal quarter of at least 2.50 to 1.00;

§	a prohibition against creating liens upon any property, subject to permitted exceptions;

§	restrictions on merging, consolidating, or selling assets outside the ordinary course of business;

§	a prohibition against making loans, subject to permitted exceptions; and

§	a prohibition against amending Cleco Power’s Indenture of Mortgage dated July 1, 1950.

At December 31, 2009, and 2008, Cleco Power had a working capital surplus of $182.7 million and $88.0 million, respectively. Included in working capital at December 31, 2009 and 2008 was $29.9 million and $62.3 million, respectively, which was restricted for the use of debt payments. The $94.7 million increase in working capital is primarily due to net proceeds from the issuance of bonds, partially offset by additions to property plant and equipment, including Rodemacher Unit 3.

At December 31, 2009, Cleco Power’s Consolidated Balance Sheet reflected $2.4 billion of total liabilities compared to $2.1 billion at December 31, 2008. The $0.3 billion increase in total liabilities during 2009 was primarily due to increases in total other regulatory liabilities, long-term debt, and accumulated deferred federal and state income taxes, net. The $97.3 million increase in total other regulatory liabilities from December 31, 2008, was primarily due to the increase in deferred construction carrying costs of Rodemacher Unit 3. Long-term debt increased $96.4 million during 2009, as discussed above. The $47.3 million increase in accumulated deferred federal and state income taxes, net, was primarily due to a change in the tax accounting method for repairs. For more information on the deferred construction carrying costs of Rodemacher Unit 3, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 3 — Regulatory Assets and Liabilities — Deferred Construction Carrying Costs.”

At December 31, 2009, no borrowings were outstanding under Cleco Power’s $275.0 million, five-year revolving credit facility. An uncommitted line of credit with a bank in an amount up to $10.0 million also is available to support Cleco Power’s working capital needs.

In August 2009, Cleco Power redeemed all $49.5 million principal amount of its outstanding 6.05% insured quarterly notes due June 2012. Once redeemed, the notes were replaced with a one-month LIBOR plus 3.00% floating rate bank loan, maturing on August 19, 2012. In July 2009, Cleco Power locked in a $50.0 million interest rate swap arrangement related to this loan. This swap was effective on August 19, 2009 and will mature on May 31, 2012. For additional information, see Part I, Item 1A, “Risk Factors — Interest Rate Swap” and Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 5 — Fair Value Accounting — Interest Rate Swap.”

In October 2009, Cleco Power entered into a treasury rate lock contract in order to mitigate the interest rate exposure on a possible future debt issuance. The notional amount of the treasury rate lock was $75.0 million. The reference rate of 4.005% was based on the 30-year treasury note yield as of October 2, 2009.

In November 2009, Cleco Power issued $145.0 million aggregate principal amount of senior unsecured notes as additional notes of a class of $150.0 million senior notes issued in November 2005. The interest rate for the notes is 6.50%, and the aggregate $295.0 million of the notes mature on December 1, 2035. The net proceeds from the November 2009 offering were used for general corporate purposes, including financing a portion of the construction costs related to the Acadiana Load Pocket transmission project.

Also in November 2009, Cleco Power settled the treasury rate lock that was entered into in October 2009. The reference rate, based on the 30-year treasury note yield, on the date of settlement of the treasury rate lock was 4.378%, which resulted in Cleco Power receiving $4.7 million from the counterparty. The treasury rate lock is considered a derivative instrument that qualifies as a cash flow hedge for accounting purposes. While the treasury rate lock meets the definition of “highly effective,” it did contain some ineffectiveness relating to the discount period of the treasury rate lock (30 years) as compared to the discount period used to calculate the senior note issuance discount (26 years). Cleco Power recorded the ineffective portion of $0.4 million as a reduction in interest expense. The remaining effective portion of $4.3 million was recorded as an increase in accumulated other comprehensive income. The $4.3 million in accumulated other comprehensive income will be reclassified as a reduction to interest expense over the remaining 26-year life of the senior notes.

Cash and cash equivalents available at December 31, 2009, were $138.1 million, combined with $275.0 million facility capacity for total liquidity of $413.1 million. Cash and cash equivalents at December 31, 2009 increased $46.6 million, when compared to cash and cash equivalents at December 31, 2008. This increase is primarily due to cash received from the issuance of bonds, partially offset by additions to property, plant and equipment, including Rodemacher Unit 3.

In February 2006, the LPSC approved Cleco Power’s plans to build Rodemacher Unit 3. Terms of the approval included acceptance of an LPSC Staff recommendation that Cleco Power collect from customers an amount equal to 75% of the carrying costs of capital during the construction phase of the unit. In addition to this recovery, Cleco Power funded the construction costs related to Rodemacher Unit 3 by utilizing cash on hand, available funds from its credit facility, the issuance of long-term debt, and equity contributions from Cleco Corporation. In October 2009, the LPSC approved Cleco Power’s new retail rate plan, which established that $183.2 million be returned to customers over a five-year period. Once Rodemacher Unit 3 began commercial operations on

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

February 12, 2010, Cleco Power began refunding the construction carrying costs to customers. At December 31, 2009, $33.6 million was due to be returned within one year. For more information regarding the refunding of Rodemacher Unit 3 construction carrying costs, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 3 — Regulatory Assets and Liabilities — Deferred Construction Carrying Cost.”

Midstream

Midstream had no short- or long-term debt outstanding at December 31, 2009, or 2008.

Evangeline, which is accounted for under the equity method, had no short-term debt outstanding at December 31, 2009, or 2008. Evangeline had $161.8 million and $168.9 million of long-term debt outstanding at December 31, 2009, and 2008, respectively, in the form of 8.82% Senior Secured bonds due 2019. Of these amounts, $8.2 million and $7.1 million were due within one year at December 31, 2009, and 2008, respectively. The Senior Secured bonds issued by Evangeline were non-recourse to Cleco Corporation. In February 2010, Evangeline and JPMVEC entered into the Evangeline Restructuring Agreement. In conjunction with the agreement, JPMVEC transferred $126.6 million of Senior Secured bonds owned by JPMVEC to Evangeline, which bonds were subsequently retired, and the remaining $35.2 million of principal bonds were called for irrevocable redemption. For more information, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 23 — Subsequent Events — Evangeline Transactions.”

Cash Generation and Cash Requirements

Restricted Cash

Various agreements to which Cleco is subject contain covenants that restrict its use of cash. As certain provisions under these agreements are met, cash is transferred out of related escrow accounts and becomes available for general corporate purposes. At December 31, 2009, and 2008, $56.4 million and $103.0 million of cash, respectively, was restricted on Cleco Corporation’s Consolidated Balance Sheets. At December 31, 2009, restricted cash consisted of $0.1 million under the Diversified Lands mitigation escrow agreement, $22.2 million reserved at Cleco Power for GO Zone project costs, $25.4 million reserved at Cleco Power for future storm restoration costs, and $8.7 million at Cleco Katrina/Rita restricted for payment of operating expenses and interest, and principal on storm recovery bonds. Restricted cash at Cleco Power at December 31, 2009, decreased $46.5 million compared to December 31, 2008, primarily due to the use of $22.4 million of funds for GO Zone project costs, the release of $14.7 million for the construction of Cleco Power’s solid waste disposal facilities, a $7.5 million net decrease in Cleco Katrina/Rita restricted cash due to the payment of operating expenses and interest, and principal on storm recovery bonds, offset by collections, and Cleco Power’s net use of $1.9 million for approved storm damage costs.

Evangeline’s restricted cash is not reflected in Cleco Corporation’s Consolidated Balance Sheets due to equity method accounting. Evangeline’s restricted cash at December 31, 2009, and 2008, was $30.1 million and $25.0 million, respectively. This cash was restricted under Evangeline’s Senior Secured bond indenture for major maintenance expenses and principal and interest payments on the Senior Secured bonds. In February 2010, Evangeline and JPMVEC entered into the Evangeline Restructuring Agreement. In conjunction with the agreement, Evangeline’s restricted cash will be released to Cleco Corporation. For more information, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 23 — Subsequent Events — Evangeline Transactions.”

Cleco Cash Flows

Net Cash Provided by Operating Activities

Net cash provided by operating activities was $135.2 million during 2009, $89.5 million in 2008, and $263.0 million in 2007.

Cash provided by operating activities during 2009 increased $45.7 million from 2008, primarily due to higher collections of accounts receivable; increases in customer deposits; lower vendor payments; higher tax refunds; and lower gas prepayments. These were partially offset by higher purchases of fuel, materials, and supplies inventories, primarily related to preparation for Rodemacher Unit 3 to begin commercial operation; higher postretirement benefit contribution payments into the Cleco pension plan; and a large retainage payment made to Shaw related to work completed on Rodemacher Unit 3.

Cash from operating activities during 2008 decreased $173.5 million from that reported in 2007, primarily due to the absence of proceeds from the 2007 sale of bankruptcy claims, lower dividends from equity investments in Acadia and Evangeline, and higher margin deposits. These were partially offset by higher collections of customer accounts and lower retainage payments to Shaw related to work completed on Rodemacher Unit 3.

Net Cash Used in Investing Activities

Net cash used in investing activities was $177.2 million during 2009, $368.7 million in 2008, and $480.7 million in 2007. Net cash used in investing activities in 2009 was lower than 2008 primarily due to transfers from restricted accounts and lower additions to property, plant and equipment related to the Rodemacher Unit 3 project. Net cash used in investing activities in 2008 was lower than 2007 primarily due to lower additions to property, plant and equipment related to the Rodemacher Unit 3 project.

During 2009, Cleco had additions to property, plant and equipment, net of AFUDC of $177.0 million, a $15.7 million investment in New Market Tax Credits, a $16.9 million investment in Acadia, and a $12.9 million investment in Oxbow. This was partially offset by the transfer of $46.5 million of cash from restricted accounts, primarily related to solid waste disposal and GO Zone bonds.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

During 2008, Cleco had additions to property, plant and equipment, net of AFUDC, of $270.8 million, a $12.2 million investment in New Market Tax Credits, a $6.4 million investment in Perryville, and $85.0 million of cash became restricted, primarily related to solid waste disposal, GO Zone, and storm restoration bonds. This was partially offset by a $4.0 million return of equity from Evangeline.

During 2007, Cleco had additions to property, plant and equipment, net of AFUDC, of $477.2 million, a $2.2 million investment in company- and trust-owned life insurance policies, and an $8.4 million investment in Acadia. This was partially offset by a $6.5 million transfer of cash from restricted accounts, primarily related to solid waste disposal bonds.

Net Cash Provided by Financing Activities

Net cash provided by financing activities was $89.7 million during 2009, $247.7 million in 2008, and $154.2 million in 2007. Net cash provided by financing activities in 2009 was lower than 2008 primarily due to lower issuances of long-term debt, partially offset by lower retirements of long-term debt. Net cash provided by financing activities in 2008 was higher than 2007 primarily due to the issuance of long-term debt, partially offset by retirements of long-term debt and the absence in 2008 of proceeds from the 2007 conversion of stock options to common stock.

During 2009, Cleco received net proceeds of $255.4 million for the issuance of long-term debt, consisting of $145.0 million of long-term bonds, $65.0 million of credit facility draws, and $50.0 million in a bank term loan. This was partially offset by $114.8 million of cash used for repayment of medium term notes and storm restoration bonds, and $54.2 million used for common stock dividends.

During 2008, Cleco received net proceeds of $651.5 million from the issuance of long-term debt, which was partially offset by $190.0 million of cash used to repay borrowings under Cleco Power’s credit facility, $160.0 million of cash used for repayment of long-term debt, and $54.0 million used for common stock dividends.

During 2007, Cleco received $190.0 million from draws on Cleco Power’s credit facility, $60.0 million from the issuance of long-term debt, and $9.5 million from the conversion of stock options to common stock. This was partially offset by $50.3 million of cash used for repayment of long-term debt and $53.7 million used for common and preferred stock dividends.

Cleco Power Cash Flows

Net Cash Provided by Operating Activities

Net cash provided by operating activities was $141.7 million during 2009, $62.1 million in 2008, and $97.6 million in 2007.

Cash provided by operating activities during 2009 increased $79.6 million from 2008, primarily due to higher collections of accounts receivable; increases in customer deposits; lower vendor payments; higher tax refunds; and lower gas prepayments. These were partially offset by higher purchases of fuel, materials, and supplies inventories, primarily related to preparation for Rodemacher Unit 3 to begin commercial operation; higher postretirement benefit contribution payments into the Cleco pension plan; and a large retainage payment made to Shaw related to work completed on Rodemacher Unit 3.

Cash from operating activities in 2008 decreased $35.5 million from that reported in 2007, primarily due to higher margin deposits and higher materials inventory purchases. This was partially offset by lower retainage payments to Shaw related to work completed on Rodemacher Unit 3.

Net Cash Used in Investing Activities

Net cash used in investing activities was $142.0 million during 2009, $353.2 million in 2008, and $469.6 million in 2007. Net cash used in investing activities in 2009 was lower than 2008 primarily due to transfers from restricted accounts and lower additions to property, plant and equipment related to the Rodemacher Unit 3 project. Net cash used in 2008 was lower than 2007 primarily due to lower additions to property, plant and equipment related to the Rodemacher Unit 3 project.

During 2009, Cleco Power had additions to property, plant and equipment, net of AFUDC of $176.0 million and a $12.9 million investment in Oxbow. This was partially offset by the transfer of $46.5 million of cash from restricted accounts, primarily related to solid waste disposal and GO Zone bonds.

During 2008, Cleco Power had additions to property, plant and equipment, net of AFUDC of $269.7 million and $85.0 million of cash became restricted, primarily related to solid waste disposal, GO Zone, and storm restoration bonds.

During 2007, Cleco Power had additions to property, plant and equipment, net of AFUDC of $476.2 million. This was partially offset by the transfer of $6.5 million of cash from restricted accounts, primarily related to solid waste disposal bonds.

Net Cash Provided by Financing Activities

Net cash provided by financing activities was $46.8 million during 2009, compared to $370.8 million in 2008, and $282.1 million in 2007. Net cash provided by financing activities in 2009 was lower than 2008 primarily due to lower issuance of long-term debt and a $30.0 million distribution to Cleco. This was partially offset by lower retirements of long-term debt. Net cash provided by financing activities in 2008 was higher than 2007, primarily due to the higher issuance of long-term debt, partially offset by higher retirements of long-term debt and the absence in 2008 of the 2007 net contribution from Cleco.

Shelf Registrations

On October 30, 2009, a registration statement (No. 333-162772) providing for the issuance of up to $300.0 million of Cleco Corporation debt securities was declared effective by the SEC. At December 31, 2009, all $300.0 million remained available. On October 30, 2009, a registration statement (No. 333-162773) providing for the issuance of up to $500.0 million of Cleco Power debt securities was declared effective by the SEC. At December 31, 2009, Registration Statement No.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

333-162773 had remaining capacity allowing for the issuance of up to $355.0 million of debt securities.

Construction Overview

Cleco allocates its construction budget among its major first-tier subsidiaries — Cleco Power and Midstream. Cleco Power construction costs relate primarily to assets that may be included in Cleco Power’s rate base and, if considered prudent by the LPSC, can be recovered from its customers. Those assets also earn a rate of return authorized by the LPSC and are subject to the rate agreement. Such assets consist of improvements to Cleco Power’s distribution system, transmission system, and generating stations. Midstream’s construction activities pertain predominately to Evangeline and Acadia.

Cleco’s 2010 expenditures for construction and debt maturity are estimated to total $191.0 million, which includes $179.0 million of estimated construction expenditures, excluding AFUDC, and $12.0 million of estimated debt maturity payments. Cleco’s 2010 estimated construction expenditures include $55.0 million for Acadiana Load Pocket project costs, excluding AFUDC, and $12.0 million for Rodemacher Unit 3 project costs, excluding AFUDC.

For the five-year period ending in 2014, Cleco’s expenditures for construction and debt maturity are expected to total approximately $1.0 billion, which includes $667.0 million of estimated construction expenditures, excluding AFUDC, and $346.0 million of estimated debt maturity payments. Approximately 19% of the planned construction expenditures for the five-year period are expected to be for Cleco Power’s portion of the joint project to upgrade the Acadiana Load Pocket transmission system. Total additional planned Acadiana Load Pocket project costs, excluding AFUDC, are estimated at $124.0 million. Approximately 2% of the planned construction expenditures for the five-year period is expected to be for Cleco Power’s construction of Rodemacher Unit 3. Total additional planned Rodemacher project costs, excluding AFUDC, are estimated at $12.0 million. Approximately 20% of the planned construction expenditures will support line extensions and substation upgrades to accommodate new business and load growth at Cleco Power. The remaining 59% will be for the rehabilitation of older transmission, distribution, and generation assets at Cleco Power and the purchase of computer hardware and software upgrades for Cleco.

Evangeline’s 2010 expenditures for construction and debt are estimated to total $158.0 million, which includes $3.0 million of estimated construction expenditures and $155.0 million of estimated debt maturity payments. For the five-year period ending in 2014, Evangeline’s expenditures for construction and debt maturity are expected to total $163.0 million, which includes $5.0 million of estimated construction expenditures and $158.0 million of estimated debt maturity payments. The construction and debt maturity payments for Evangeline are not included in Cleco’s totals due to the equity method of accounting for Evangeline. For more information on the equity method of accounting related to Evangeline, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 13 — Equity Investment in Investees.” For information on the maturities of Cleco’s debt, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 6 — Debt.”

Acadia’s 2010 expenditures for construction and debt maturity are estimated to total $4.0 million, which includes estimated construction expenditures of $4.0 million and no estimated debt payments. Due to the Cleco Power and Entergy Louisiana transactions, there are no estimated construction costs or debt payments after 2010. The construction and debt maturity payments for Acadia are not included in Cleco’s totals due to the equity method of accounting. For more information on the equity method of accounting related to Acadia or the Cleco Power and Entergy Louisiana transactions, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 13 — Equity Investment in Investees” and Note 23 — “Subsequent Events — Acadia Transaction.”

Cleco believes cash and cash equivalents on hand, together with cash generated from operations, borrowings from credit facilities, and the net proceeds of any issuances of equity or debt securities, will be adequate to fund normal ongoing capital expenditures, working capital, and debt service requirements for the foreseeable future.

Cleco Power Construction Overview

Cleco Power’s construction expenditures, excluding AFUDC, totaled $176.0 million in 2009, $269.7 million in 2008, and $476.2 million in 2007. The decrease in construction expenditures from 2007 through 2009 was primarily due to costs related to the construction at Rodemacher Unit 3.

Cleco Power’s construction expenditures for 2010, excluding AFUDC, are estimated to be $177.0 million. Cleco Power’s 2010 estimated construction expenditures include $55.0 million for Acadiana Load Pocket project costs, excluding AFUDC, and $12.0 million for Rodemacher Unit 3 project costs, excluding AFUDC. For the five-year period ending in 2014, estimated construction expenditures are expected to total $663.0 million. Approximately 19% of the planned construction expenditures for the five-year period are expected to be for Cleco Power’s portion of the joint project to upgrade the Acadiana Load Pocket transmission system. Total additional planned Acadiana Load Pocket project costs, excluding AFUDC, are estimated at $124.0 million. Approximately 2% of the planned construction is expected to be for Cleco Power’s construction of Rodemacher Unit 3. Total additional planned Rodemacher project costs, excluding AFUDC, are estimated at $12.0 million. Approximately 20% of the planned construction in the five-year period will support line extensions and substation upgrades to accommodate new business and load growth. The remaining 59% will be for the rehabilitation of older transmission, distribution, and generation assets.

For more information on the Acadiana Load Pocket, see “— Regulatory Matters — Wholesale Rates of Cleco — Acadiana Load Pocket.”

In 2009, 80.5% of Cleco Power’s construction

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

requirements were funded internally. In 2008 and 2007, 23.0% and 20.5%, respectively, of Cleco Power’s construction requirements were funded internally. In 2010, 100% of Cleco Power’s construction requirements are expected to be funded internally. For the five-year period ending 2014, 100% of the remaining construction requirements are expected to be funded internally. All computations of internally funded construction exclude AFUDC.

Other Subsidiary Construction

Other subsidiaries had construction expenditures of $1.0 million during each of the years ended December 31, 2009, 2008, and 2007. Other subsidiary expenditures for construction and debt payments in 2010 are estimated to total $2.0 million. For the five-year period ending 2014, estimated construction expenditures and debt payments are expected to total $3.0 million. The majority of the planned other construction in the five-year period will consist of upgrades of computer hardware and software for Support Group.

Other Cash Requirements

Cleco Power’s regulated operations and Midstream’s merchant power plants are Cleco’s primary sources of internally generated funds. These funds, along with the issuance of additional debt and equity in future years, will be used for general corporate purposes, construction, and to repay corporate debt.

Contractual Obligations and Other Commitments

Cleco, in the course of normal business activities, enters into a variety of contractual obligations. Some of these result in direct obligations that are reflected in Cleco’s Consolidated Balance Sheets while others are commitments, some firm and some based on uncertainties, that are not reflected in the consolidated financial statements. The obligations listed in the following table do not include amounts for ongoing needs for which no contractual obligation existed as of December 31, 2009, and represent only the projected future payments that Cleco was contractually obligated to make as of December 31, 2009.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

							PAYMENTS DUE BY PERIOD
CONTRACTUAL OBLIGATIONS (THOUSANDS)	TOTAL		LESS THAN ONE YEAR		1-3 YEARS		4-5 YEARS		MORE THAN 5 YEARS
Cleco Corporation *
Long-term debt obligations (1)	$	95,267	$	188	$	95,079	$	-	$	-
Operating lease obligations (3)		403		158		231		9		5
Purchase obligations (4)		22,451		11,620		6,235		3,449		1,147
Other long-term liabilities (5)		8,807		147		1,173		342		7,145
Pension obligations (6)		148,481		4,696		10,395		11,319		122,071
Total Cleco Corporation	$	275,409	$	16,809	$	113,113	$	15,119	$	130,368
Cleco Power
Long-term debt obligations (1)	$	2,369,773	$	84,277	$	218,138	$	287,651	$	1,779,707
Capital lease obligations (2)		41,747		4,748		9,244		9,256		18,499
Operating lease obligations (3)		40,767		9,354		16,273		8,311		6,829
Purchase obligations (4)		753,785		542,519		163,013		47,325		928
Other long-term liabilities (5)		264,204		61,986		84,713		28,681		88,824
Total Cleco Power	$	3,470,276	$	702,884	$	491,381	$	381,224	$	1,894,787
Midstream *
Purchase obligations (4)	$	8	$	8	$	-	$	-	$	-
Other long-term liabilities (5)		231		67		125		39		-
Total Midstream	$	239	$	75	$	125	$	39	$	-
Total long-term debt obligations (1)	$	2,465,040	$	84,465	$	313,217	$	287,651	$	1,779,707
Total capital lease obligations (2)	$	41,747	$	4,748	$	9,244	$	9,256	$	18,499
Total operating lease obligations (3)	$	41,170	$	9,512	$	16,504	$	8,320	$	6,834
Total purchase obligations (4)	$	776,244	$	554,147	$	169,248	$	50,774	$	2,075
Total other long-term liabilities (5)	$	273,242	$	62,200	$	86,011	$	29,062	$	95,969
Total pension obligations (6)	$	148,481	$	4,696	$	10,395	$	11,319	$	122,071
Total	$	3,745,924	$	719,768	$	604,619	$	396,382	$	2,025,155

(1)Long-term debt existing as of December 31, 2009, is debt that has a final maturity of January 1, 2011, or later (current maturities of long-term debt are due within one-year). Cleco’s anticipated interest payments related to long-term debt also are included in this category. Scheduled maturities of debt will total $11.5 million for 2010 and $1.3 billion for the years thereafter. These amounts also include capital lease maturities. For additional information regarding Cleco’s long-term debt, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 6 — Debt” and “— Debt” above.

(2)Capital leases are maintained in the ordinary course of Cleco’s business activities. These leases include mobile data terminal leases and barges.

(3)Operating leases are maintained in the ordinary course of Cleco’s business activities. These leases include tolling agreements and towboat, rail car, vehicle, office space, operating facilities, office equipment, and operating equipment leases and have various terms and expiration dates from 1 to 15 years. For additional information regarding Cleco’s operating leases, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 14 — Operating Leases.”

(4)Significant purchase obligations for Cleco are listed below:

Fuel Contracts: To supply a portion of the fuel requirements for Cleco Power’s generating plants, Cleco has entered into various commitments to obtain and deliver coal, lignite, petroleum coke, and natural gas. Some of these contracts contain provisions for price escalation and minimum purchase commitments. Generally, fuel and purchased power expenses are recovered through the LPSC-established fuel adjustment clause, which enables Cleco Power to pass on to customers substantially all such charges. For additional information regarding fuel contracts, see Part I, Item 1, “Business — Operations — Cleco Power — Fuel and Purchased Power.”

Power Purchase Agreements: Cleco Power has entered into agreements with energy suppliers for purchased power to meet system load and energy requirements, replace generation from Cleco Power owned units under maintenance and during outages, and meet operating reserve obligations. In general, these contracts provide for capacity payments, subject to meeting certain contract obligations, and energy payments based on actual power taken under the contracts. Cleco Power also has entered into agreements to purchase transmission capacity. For additional information regarding power purchase agreements, see Part I, Item 1, “Business — Operations — Fuel and Purchased Power — Power Purchases.”

EPC contract: Cleco Power entered into the Amended EPC Contract with Shaw to construct Rodemacher Unit 3. For more information, see “— Regulatory Matters — Rodemacher Unit 3 — Construction.”

Gas Futures Contracts: Cleco Power entered into natural gas purchase contracts in order to hedge the risk associated with the volatility in the cost of fuel purchased for utility generation and the risk associated with the fixed-price power that is being provided to a wholesale customer through December 2010. For more information, see Item 7A, “Quantitative and Qualitative Disclosures about Market Risk — Risk Overview — Commodity Price Risk.”

Interest Rate Swap: Cleco Power entered into an interest rate swap to minimize the risk associated with its variable-rate debt obligations. For additional information regarding the interest rate swap, see Item 8, “Financial Statements and Supplementary Data — Notes to Financial Statements — Note 5 — Fair Value Accounting — Interest Rate Swap."

Purchase orders: Cleco has entered into purchase orders in the course of normal business activities.

(5)Other long-term liabilities primarily consist of obligations for franchise payments, deferred compensation, facilities use, and various operating and maintenance agreements.

(6)Pension obligations consist of obligations for SERP and other postretirement obligations.

For purposes of this table, it is assumed that all terms and rates related to the above obligations will remain the same, and all franchises will be renewed according to the rates used in the table.

*Long-term debt, long-term maintenance agreements, and various other operating and maintenance agreements related to Cleco Corporation’s equity investments in Perryville and Attala, and Midstream’s equity investments in Evangeline and Acadia are not reflected in the chart above. For additional information on these entities, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 13 — Equity Investment in Investees.”

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

Other Commitments

The obligations listed in the following table represent the projected future payments that Cleco may be obligated to make relative to uncertain tax positions as of December 31, 2009. For more information on Cleco’s uncertain tax positions, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 10 — Income Taxes — Uncertain Tax Positions.”

UNCERTAIN TAX POSITIONS (THOUSANDS)	AT DECEMBER 31, 2009
Tax liability	$	129,235
Interest		40,518
Total*	$	169,753

Cleco	$	169,753	(1)
Cleco Power	$	106,511	(2)
Midstream	$	70,814	(3)
*Uncertain federal and state tax positions as of December 31, 2009, that will be settled at some future date with the IRS and Louisiana Department of Revenue. (1) Includes interest of $ 40,518 (2) Includes interest of $22,151 (3) Includes interest of $26,387

Off-Balance Sheet Commitments

Cleco Corporation and Cleco Power have entered into various off-balance sheet commitments, in the form of guarantees and standby letters of credit, in order to facilitate their activities and the activities of Cleco Corporation’s subsidiaries and equity investees (affiliates). Cleco Corporation and Cleco Power have also agreed to contractual terms that require them to pay third parties if certain triggering events occur. These contractual terms generally are defined as guarantees in the authoritative guidance.

Cleco Corporation entered into these off-balance sheet commitments in order to entice desired counterparties to contract with its affiliates by providing some measure of credit assurance to the counterparty in the event Cleco’s affiliates do not fulfill certain contractual obligations. If Cleco Corporation had not provided the off-balance sheet commitments, the desired counterparties may not have contracted with Cleco’s affiliates, or may have contracted with them at terms less favorable to its affiliates.

The off-balance sheet commitments are not recognized on Cleco’s Consolidated Balance Sheets, because it has been determined that Cleco’s affiliates are able to perform the obligations under their contracts and that it is not probable that payments by Cleco will be required. Some of these commitments reduce borrowings available to Cleco Corporation under its credit facility pursuant to the terms of the credit facility. Cleco’s off-balance sheet commitments as of December 31, 2009, are summarized in the following table, and a discussion of the off-balance sheet commitments follows the table. The discussion should be read in conjunction with the table to understand the impact of the off-balance sheet commitments on Cleco’s financial condition.

							AT DECEMBER 31, 2009
							REDUCTIONS TO THE
							AMOUNT AVAILABLE
							TO BE DRAWN ON
	FACE				NET		CLECO CORPORATION’S
(THOUSANDS)	AMOUNT		REDUCTIONS		AMOUNT		CREDIT FACILITY
Cleco Corporation
Guarantee issued to Entergy companies for performance obligations of Perryville	$	177,400	$	135,000	$	42,400	$	-
Obligations under standby letter of credit issued to the Evangeline Tolling Agreement counterparty		15,000		-		15,000		15,000
Guarantee issued to Entergy Mississippi on behalf of Attala		500		-		500		-
Cleco Power
Obligations under standby letter of credit issued to Louisiana Department of Labor		3,525		-		3,525		-
Total	$	196,425	$	135,000	$	61,425	$	15,000

Cleco Corporation provided a limited guarantee and an indemnification to Entergy Louisiana and Entergy Gulf States for Perryville’s performance, indemnity, representation, and warranty obligations under the Sale Agreement, the Power Purchase Agreement, and other ancillary agreements related to the sale of the Perryville facility. As of December 31, 2009, the aggregate guarantee of $177.4 million is limited to $42.4 million due to the performance of some of the underlying obligations that were guaranteed. Management believes it is unlikely that Cleco Corporation will have any other liabilities which would give rise to indemnity claims. The discounted probability-weighted liability under the guarantees and indemnifications as of December 31, 2009, was $0.3 million.

Prior to February 22, 2010, if Evangeline failed to perform certain obligations under the Evangeline Tolling Agreement, Cleco Corporation would have been required to make payments to the Evangeline Tolling Agreement counterparty. Cleco Corporation’s obligation under the Evangeline commitment was in the form of a standby letter of credit from investment grade banks and was limited to $15.0 million. Rating triggers did not exist in the Evangeline Tolling Agreement. Evangeline met its obligations under the Evangeline Tolling Agreement and Cleco Corporation was not required to make payments to the counterparty. The letter of credit was issued under Cleco Corporation’s credit facility and therefore reduced the amount that could be borrowed under the credit facility. On February 22, 2010, Evangeline entered into the Evangeline 2010 Tolling Agreement and as a result, the need to provide a letter of credit was terminated. For additional information, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 23 — Subsequent Events — Evangeline Transactions.”

In January 2006, Cleco Corporation provided a $0.5 million guarantee to Entergy Mississippi for Attala’s obligations under the Interconnection Agreement. This guarantee will be effective through the life of the agreement.

The State of Louisiana allows employers of certain financial net worth to self-insure their workers’ compensation benefits.

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Cleco Power has a certificate of self-insurance from the Louisiana Office of Workers’ Compensation and is required to post a $3.5 million letter of credit, an amount equal to 110% of the average losses over the previous three years, as surety.

As part of the Lignite Mining Agreement amended in 2009, Cleco Power and SWEPCO, joint owners of Dolet Hills, have agreed to pay the lignite miner’s loan and lease principal obligations when due, if the lignite miner does not have sufficient funds or credit to pay. Any amounts paid on behalf of the miner would be credited by the lignite miner against the next invoice for lignite delivered. At December 31, 2009, Cleco Power recorded a liability of $3.8 million related to the amended agreement. The lignite mining contract is in place until 2026 and does not affect the amount Cleco Corporation can borrow under its credit facility.

The following table summarizes the expected termination dates of the guarantees and standby letters of credit discussed above:

			AT DECEMBER 31, 2009
			AMOUNT OF COMMITMENT EXPIRATION PER PERIOD
	NET								MORE
	AMOUNT		LESS THAN						THAN
(THOUSANDS)	COMMITTED		ONE YEAR		1-3 YEARS		3-5 YEARS		5 YEARS
Guarantees	$	42,900	$	-	$	-	$	-	$	42,900
Standby letters of credit		18,525		3,525		-		-		15,000
Total commercial commitments	$	61,425	$	3,525	$	-	$	-	$	57,900

Inflation

Annual inflation rates, as measured by the U.S. Consumer Price Index, have averaged approximately 2.12% during the three years ended December 31, 2009. Cleco believes inflation, at this level, does not materially affect its results of operations or financial condition. However, under existing regulatory practice, only the historical cost of a plant is recoverable from customers. As a result, Cleco Power’s cash flows designed to provide recovery of historical plant costs may not be adequate to replace property, plant and equipment in future years.

Regulatory Matters

Generation RFP

2008 Short-Term RFP for 2009 Resources

In March 2008, Cleco Power issued a RFP for a minimum of 50 MW up to 450 MW to meet its 2009 capacity and energy requirements. Cleco Power selected and negotiated a 235-MW peaking product with Acadia. The product was for supply that started March 1, 2009 and ended October 1, 2009.

On January 6, 2009, Cleco Power issued a RFP for a minimum capacity amount of 50 MW up to 200 MW in order to serve additional load. Cleco Power has selected and negotiated a 200-MW intermediate product with NRG Power Marketing, Inc. The product was for supply that started April 1, 2009, and ended November 1, 2009.

2007 Long-Term RFP

In June 2007, Cleco Power filed a proposed RFP with the LPSC for up to approximately 600 MW of intermediate and/or peaking resources to meet projected load growth over a 10-year period beginning in 2010. To meet these needs, Cleco Power asked for products with a term of 2 to 30 years. Out of the approximately 600-MW total, up to approximately 350 MW may be sourced from a peaking resource. After the LPSC review, the RFP was issued in October 2007, and bids were received in December 2007. On February 26, 2009, Cleco Power announced that it had chosen the acquisition of 50% of the Acadia Power Station, or one of its two 580-MW units, as the lowest bid in its 2007 long-term RFP. Cleco Power will own and operate one unit and operate the other 580-MW unit on behalf of Acadia or a future owner. Cleco Power and the parties have executed the definitive agreements. Cleco Power received LPSC and FERC approvals for the transaction in January 2010 and February 2010, respectively. Beginning in January 2010, Acadia operated the plant and served Cleco Power under a tolling agreement covering 50% of the Acadia Power Station. The tolling agreement was approved by the LPSC in October 2009 and by FERC in December 2009. The tolling agreement was terminated when the transaction closed in February 2010.

Rodemacher Unit 3

Construction

In May 2006, Cleco Power began construction of Rodemacher Unit 3, a 600-MW solid fuel power plant at its Rodemacher facility. The unit commenced commercial operations on February 12, 2010, approximately four and one-half months behind the originally anticipated date of September 30, 2009. Rodemacher Unit 3 is in service as Cleco Power has accepted care, custody, and control of its operations. Rodemacher Unit 3 is capable of burning various solid fuels, but initially will primarily burn petroleum coke produced by several refineries throughout the Gulf Coast region. Cleco Power has entered into contracts with suppliers to collectively supply over 1.4 million tons of petroleum coke annually for a three-to five-year period beginning in 2009, representing over 90% of Rodemacher Unit 3 fuel requirements for such period. As of January 31, 2010, Cleco Power had stock piled over 445,000 tons of petroleum coke for future consumption.

In May 2006, Cleco Power and Shaw entered into an Amended EPC Contract, which provided for substantial completion of the construction of Rodemacher Unit 3 by September 30, 2009. Pursuant to various amendments, the date was established as September 28, 2009, as a result of a broader settlement of fuel and force majeure related Shaw claims. Under the amended contract, the lump-sum price is $795.6

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million. Various claims remain in dispute resolution between Cleco Power and Shaw including the claims for force majeure related costs, which have been agreed upon as not to exceed $24.0 million, less a settlement credit of $6.0 million. As of December 31, 2009, Cleco Power had incurred approximately $989.3 million in project costs, including AFUDC. The Rodemacher Unit 3 budget remains within 1% of its estimated projections, as the resulting additional AFUDC costs from delays were principally offset by Shaw payments for delay liquidated damages under the Amended EPC Contract. Such amounts withheld as of December 31, 2009 were $9.8 million. In support of its performance obligations, Shaw, as of December 31, 2009, has provided two letters of credit collectively in the amount of $117.5 million, an additional $0.6 million of payment retainage, as well as a $200.0 million payment and performance bond in favor of Cleco as specified under the Amended EPC Contract. The retention and letters of credit are provided in support of Shaw’s potential payment of liquidated damages, or other payment performance obligations.

CCN

In May 2006, the LPSC issued its order granting Cleco Power a CCN to construct, own, and operate Rodemacher Unit 3. The CCN authorizes Cleco Power to issue up to $700.0 million of securities and other financial instruments during the 2006 through 2010 time frame in order to finance Rodemacher Unit 3. The CCN requires that Cleco Power provide the LPSC Staff with an advanced review of any specific long-term debt issuance, and the Staff has the right to object.

A condition within the LPSC’s implementing order requires that Cleco Power submit periodic updates during the construction phase of Rodemacher Unit 3. At its September 2006 business meeting, the LPSC approved a Rodemacher Unit 3 post-certification monitoring plan that requires, at least quarterly, reports addressing construction progress, expenditures, project financing, environmental compliance, and other related matters. Cleco Power is in compliance with this monitoring plan. The monitoring plan will remain in place for at least six months after the unit begins commercial operation, which was February 12, 2010.

Environmental Matters

For information on environmental matters, see Part I, Item 1, “Business — Regulatory Matters, Industry Developments, and Franchises — Environmental Matters.”

Retail Rates of Cleco Power

Retail rates regulated by the LPSC accounted for approximately 95% of Cleco Power’s 2009 and 2008 revenue.

Fuel Rates

The cost of fuel used for electric generation and the cost of power purchased for utility customers are recovered through an LPSC-established fuel adjustment clause that enables Cleco Power to pass onto its customers substantially all such charges. These fuel and purchased power costs are subject to audit by the LPSC pursuant to the Fuel Adjustment Clause General Order issued in November 1997 in Docket No. U-21497, which anticipates that an audit will be performed not less than every other year. The LPSC has reviewed Cleco Power’s fuel and purchased power costs through the year 2002 and, in July 2006, began an audit of Cleco Power’s fuel adjustment clause filings for the period January 2003 through December 2004. In March 2009, the LPSC indicated its intent to proceed with the audit for the years 2003 through 2008. This review is still pending. The total amount of fuel expenses included in the audit is approximately $3.2 billion. Cleco Power could be required to make a substantial refund of previously recorded revenue as a result of these audits, and such refund could result in a material adverse effect on the Registrants’ results of operations, financial condition, and cash flows.

To help stabilize electricity costs, the LPSC in 2001 suggested hedging the exposure to natural gas price volatility through the use of financial instruments. Cleco Power hedges a portion of the projected natural gas volumes used to serve its native electric load during each year. The hedge quantity is reviewed and adjusted periodically based on projected market indicators.

In February 2008, the LPSC opened an inquiry and issued a request for comments to investigate the potential for incentive-based mechanisms for fuel cost recovery. In February 2009, the LPSC also reopened a docket to study if Louisiana should have a renewable target or efficiency mandates. Management is unable to predict the time of completion and cannot determine the impact any potential rulemaking may have on the financial condition and results of operations of Cleco Power.

Base Rates

Beginning in 1996, the amount of Cleco Power’s yearly retail earnings has been subject to the terms of a RSP established by Cleco Power and the LPSC in a 1996 earnings review settlement. The RSP establishes a target return on common equity and requires all or a portion of regulated earnings for each yearly review period above the targeted regulatory rate of return on equity to be credited to Cleco Power’s customers.

The terms of the then-current RSP were approved by the LPSC in July 2006, and became effective October 1, 2006, along with Cleco Power’s request to extend the terms of the RSP to the commercial operation date of Rodemacher Unit 3, which was February 12, 2010. The then-current RSP allowed Cleco Power the opportunity to earn a maximum regulated return on equity of 11.65%. This maximum return was based on a return on equity of 11.25%, with any regulated earnings between 11.25% and 12.25% shared between shareholders and customers in a 40/60 ratio. All regulated earnings over 12.25% will be returned to customers. The amount of credits due customers, if any, is determined by Cleco Power and the LPSC annually, based on results for each 12-month period ended September 30. The RSP terms require the credits to be included on customers’ bills the following summer.

For information concerning amounts accrued and refunded by Cleco Power as a result of the RSP and information

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on the Staff’s RSP reviews, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 12 — Electric Customer Credits.”

In July 2008, Cleco Power filed a request for a new rate plan with the LPSC to increase its base rates for electricity. Cleco Power sought recovery of revenues sufficient to cover the addition of Rodemacher Unit 3 to its existing expenses and rate base levels.

The new retail rate plan includes a Formula Rate Plan (FRP) that has a target return on equity of 10.7%, including returning to retail customers 60.0% of retail earnings between 11.3% and 12.3% and all retail earnings over 12.3%. The capital structure assumes an equity ratio of 51.0%. The FRP also has a mechanism allowing for recovery of future revenue requirements for the Acadiana Load Pocket transmission project and the acquisition of the Acadia Power Station as a result of the Cleco Power 2007 Long-Term RFP. The retail rate plan allows Cleco Power to propose additional capital projects for inclusion in the FRP to the LPSC during the FRP’s initial four-year term.

The retail rate plan is expected to increase retail base revenues, in the first twelve months of Rodemacher Unit 3 commercial operations, by approximately $173.0 million with an anticipated net billing decrease for retail customers of approximately $40.0 million, or 5.0% (assuming a gas price of $5/MMBtu), including a reduction of approximately $97.0 million resulting from the cessation of collection of and the refund of Rodemacher Unit 3 construction financing based on a five-year crediting period. The retail rate plan provides for the placement of Rodemacher Unit 3 in rate base and recovery of the operating costs of Rodemacher Unit 3 in rate base and recovery of other costs including costs associated with damage caused by Hurricanes Gustav and Ike. For information about the risk related to the base rates, see Part I, Item 1A, “Risk Factors — Cleco Power’s Rates.”

Storm Cost Recovery

During 2006, the LPSC approved an interim rate increase to recover storm restoration costs incurred by Cleco Power relating to Hurricanes Katrina and Rita. In September 2007, the LPSC approved securitization and recovery of Cleco Power’s storm restoration costs related to Hurricanes Katrina and Rita. In March 2008, the securitization financing was completed, collection of the interim surcharge ceased, and the right to bill and collect unamortized storm damage costs from customers was sold to Cleco Katrina/Rita, a special purpose, wholly owned subsidiary of Cleco Power. As part of the approval, the LPSC also authorized the funding and securitization of a $50.0 million reserve for Cleco Power’s future, extraordinary storm costs.

In September 2008, Cleco Power’s distribution and transmission systems sustained substantial damage from Hurricanes Gustav and Ike. The current estimate of the cost of restoration for Hurricanes Gustav and Ike totaled approximately $78.7 million, of which approximately 84% related to Hurricane Gustav and the remaining 16% to Hurricane Ike. Of the $78.7 million, $46.7 million was capitalized, and with approval from the LPSC, the remaining uncapitalized costs were offset against Cleco Power’s existing storm damage reserves. Restoration costs incurred by Cleco Power from damage caused by Hurricanes Gustav and Ike were reviewed by the LPSC as part of the retail rate plan and were found to be prudently incurred; therefore, there was no disallowance of costs.

Wholesale Rates of Cleco

Power Sales

Cleco’s wholesale electric power sales are regulated by FERC via cost- and market-based tariffs. Both Evangeline and Acadia have received approval by FERC to use market-based rates based on Cleco’s initial request to FERC in 1999 for market-based rates and Cleco’s demonstration of its lack of market power. These tariffs, including the associated codes of conduct accompanying them, are updated periodically to comply with FERC directives.

In April 2004, FERC issued an order revising the methodology to be used in assessing whether a jurisdictional electric utility has generation market power, requiring a utility to pass a screening test as a condition for securing and/or retaining approval to sell electricity in wholesale markets at market-based rates. Reviews conducted by FERC in 2005 and 2006 of filings submitted by Cleco’s authorized power marketing entities, Cleco Power, Evangeline, and Acadia, concluded that Cleco had demonstrated a lack of market power in Cleco Power’s control area, and the power marketing entities may continue to charge market-based rates for wholesale power. An updated market power analysis is to be filed with FERC every three years or when a major acquisition takes place.

In June 2009, Cleco Power filed a scheduled market power analysis. The review conducted by FERC for this filing concluded that Cleco demonstrated a lack of market power in Cleco Power’s control area, and the power marketing entities may continue to charge market-based rates for wholesale power. Cleco Power anticipates filing another market power analysis after acquiring 50%, or one of the two 580-MW units at Acadia.

Transmission Service

Cleco’s electric transmission rates are regulated by FERC via cost-based, pro forma open access transmission tariffs (OATTs), a FERC-approved document outlining rates, charges, rules and conditions under which a utility provides electric transmission service. The pro forma OATT was instituted by FERC in 1996 with the issuance of Order Nos. 888 and 889. These orders required FERC-regulated electric utilities to offer third parties access to transmission under terms and conditions comparable to the terms and conditions followed by the utilities for use of their own systems. The goal of these orders was to ensure that the provision of transmission

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service is reasonable and not unduly discriminatory or preferential.

On February 15, 2007, FERC issued Order No. 890 amending its regulations and the pro forma tariff adopted in FERC Order Nos. 888 and 889. The amendments addressed apparent deficiencies in the pro forma tariff and standardized several industry practices relating to the provision of wholesale transmission service. The order became effective on May 14, 2007, and contained various implementation deadlines ranging from 30 days to one year. Order No. 890 was modified by FERC with Order No. 890-A and 890-B, effective March 2008 and September 2008, respectively, which clarified certain changes to the pro forma OATT adopted in Order No. 890. Cleco Power has incorporated these new requirements and business practices into its operations and anticipates no significant impact to Cleco.

Acadiana Load Pocket

In September 2008, Cleco Power entered into an agreement with Lafayette Utilities System, a municipal utility, and Entergy Gulf States to upgrade interconnected transmission systems in south Louisiana. The project received the LPSC’s approval in February 2009 and confirmation that it is in the public’s interest. Also in February 2009, approval was received from the SPP, Cleco Power’s reliability coordinator, to begin construction. The joint project includes expanding and upgrading the electric transmission infrastructure in south central Louisiana in an area known as the “Acadiana Load Pocket.”

The project includes upgrades to certain existing electric facilities as well as the construction of new substations, transmission lines, and capacitor banks. The total estimated cost is approximately $250.0 million. Each utility is responsible for various components of the project. Cleco Power’s portion of the cost is approximately $150.0 million, including AFUDC. The first phase of construction began in September 2009, with the final phase scheduled to be completed in 2012. At December 31, 2009, Cleco Power had spent $13.7 million on the Acadiana Load Pocket project. Upgrading the interconnected transmission system is expected to increase capacity, reduce transmission constraints, and improve electric service for customers served by all three utilities.

Franchises

For information on the treatment of franchise fees paid to municipalities by the state’s utilities, see Part I, Item 1, “Business — Regulatory Matters, Industry Developments, and Franchises — Franchises.”

Market Restructuring

Wholesale Electric Markets

Regional Transmission Organization

In 1999, FERC issued Order No. 2000, which established a general framework for all transmission-owning entities in the nation to voluntarily place their transmission facilities under the control of an appropriate RTO. Although participation was voluntary, FERC made it clear that any jurisdictional entity not participating in a RTO likely would be subject to regulatory directives. FERC later relaxed its mandate to participate in a RTO, but continued to insist upon large regional models. Many transmission-owning entities and system operators have been trying to interpret and implement FERC’s directives by attempting to organize and/or join acceptable RTOs. In October 2004, FERC granted the SPP status as a RTO.

In April 2004, Entergy filed at FERC to make potentially significant modifications to its transmission tariff. The modifications would incorporate an independent third-party entity, the ICT, into its transmission operations, with the ICT having access to pertinent information regarding the Entergy transmission system. After receiving approval from FERC and state commissions (including the LPSC), the SPP began a four-year trial as Entergy’s acting ICT on November 17, 2006.

In March 2009, FERC required Entergy to explain its plans for a replacement arrangement or its intent to continue the ICT arrangement in its current or a modified form upon expiration of the ICT. In November 2009, Entergy filed a process for evaluating modifications to, or the replacement of, the current ICT arrangements.

As with RTO developments at large, other various parties, including several state commissions, utilities, and other industry participants, are participants in the RTO and Entergy proceedings described above. As both the SPP and Entergy proceedings could impact the ability to transport power into and out of the Cleco control area, Cleco will continue monitoring developments in these proceedings and plans to be a participant in these and all other proceedings affecting the availability and sale of power in and around Louisiana.

Electric Reliability Organization

The Energy Policy Act of 2005 added Section 215 to the Federal Power Act, which provides for a uniform system of mandatory, enforceable reliability standards. In July 2006, FERC named NERC as the ERO that will be required to develop the mandatory reliability standards. Formed in 1968, NERC’s goal is to help maintain and improve the reliability of North America’s bulk power system. All public utilities subject to FERC’s authority will be required to comply with the incorporated standards and could be subjected to financial penalties if they violate FERC’s reliability or business practice standards. In March 2007, FERC issued Order No. 693 approving 83 standards submitted by NERC for approval. The rules essentially deal with documentation and the standardization of practices across the industry. FERC began enforcement of these standards on June 18, 2007. Cleco Power has incorporated these new reliability standards into its operations. Cleco will continue to monitor and provide input in the development of new proposed standards and will implement processes as necessary to achieve compliance with the standards.

In February 2010, the SPP RE (Southwest Power Pool Regional Entity) notified Cleco that an audit will be conducted of Cleco Corporation to determine its compliance with the NERC Reliability Standard Requirements. Cleco will be evaluated for compliance with all the NERC Monitored Compliance

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Reliability Standards for 2010 that apply to Cleco based on its registered functions for the three previous years after 2007. The audit is expected to begin in April 2010. Management is currently unable to predict the outcome of the audit and whether the result will have a material adverse effect on the Registrants’ results of operations, financial condition, and cash flows.

For a discussion of risks associated with FERC’s regulation of Cleco Power’s wholesale electric business, see Part I, Item 1A, “Risk Factors — ERO.”

Retail Electric Markets

Cleco Power and a number of parties, including other Louisiana electric utilities, certain power marketing companies, and various associations representing industry and consumers, have been participating in electric industry restructuring activities before the LPSC since 1997. During 2000, the LPSC Staff developed a transition to competition plan that was presented to the LPSC. In September 2004, the LPSC reviewed a large customer retail choice pilot program study compiled by the Louisiana State University Center for Energy Studies. The study concluded that retail customers 5 MW or larger could lower their electric costs through direct access to overbuilt regional electric markets. The study also concluded that there would be minimal negative impact to remaining customers based on utilities’ ability to avoid purchase power costs for existing large customers. Cleco Power filed comments on the study in January 2005 stating the study’s suggested savings were overstated, and the impact on remaining captive customers was understated. In April 2005, the LPSC conducted a technical conference to discuss retail choice for large customers. At this time, Cleco cannot predict whether any regulation enacting a large customer pilot program or otherwise affecting Cleco Power will be adopted and, if adopted, what form such legislation or regulation may take. A potentially competitive environment presents both the opportunity to supply electricity to new customers and the risk of losing existing customers. Cleco Power is striving to be able to compete effectively should retail access be adopted at some future time in Louisiana. At this time, the LPSC has deferred pursuing retail open access pending developments at the federal level and in other states.

In April 2002, the LPSC adopted order R-26172 governing the way electric generation sources are to be solicited and tested versus self-build options of a utility. Cleco Power conducted a RFP pursuant to this order during 2003. In January 2004, the LPSC amended its prior order to formally add the requirement that the soliciting utility employ an independent monitor. The independent monitor’s role is to assure the RFP process is run fairly, that bidder data is treated confidentially, and that no preference is afforded bids from affiliate companies of the utility or the utility’s own self-build proposals. For additional information on Cleco Power’s 2007 and 2008 RFPs, see “— Regulatory Matters — Generation RFP.”

Currently, the LPSC does not provide exclusive service territories for electric utilities under its jurisdiction. Instead, retail service is obtained through a long-term nonexclusive franchise. The LPSC uses a “300-foot rule” for determining the supplier for new customers. The “300-foot rule” requires a customer to take service from the electric utility that is within 300 feet of the respective customer. If the customer is beyond 300 feet from any existing utility service, they may choose their electric supplier. The LPSC is currently reviewing its “300-foot rule” (Docket No. R-28955). Management is unable to predict the time of completion and cannot determine the impact any potential rulemaking may have on the financial condition and results of operations of Cleco Power. The application of the current rule has led to competition with neighboring utilities for retail customers at the borders of Cleco Power’s service areas. Such competition has led to complaints by competitors that Cleco Power has violated the 300-foot rule. Several complaints have been made by competitors who operate as rural electric cooperatives and, if the LPSC were to rule in favor of such competitors, Cleco Power may be fined. Management does not believe any such fines, if imposed, would have a material impact on Cleco Power’s financial condition. Cleco Power also competes in its service area with suppliers of alternative forms of energy, some of which may be less costly than electricity for certain applications. Cleco Power could experience some competition for electric sales to industrial customers in the form of cogeneration or from independent power producers.

For information on dual franchise attempts, see Part I, Item 1, “Business — Regulatory Matters, Industry Developments, and Franchises — Franchises.”

Other Matters

Lignite Deferral

Cleco Power operates a generating unit jointly owned with SWEPCO that uses lignite as its fuel source.

In May 2001, Cleco Power (along with SWEPCO) entered into the Lignite Mining Agreement with DHLC, the operator of the Dolet Hills mine. As ordered then by the LPSC, Cleco Power’s retail customers began receiving fuel cost savings equal to 2% of the projected costs under the previous mining contract (the benchmark price) through the year 2011. Actual mining costs incurred above 98% of the benchmark price were deferred, and can be recovered from retail customers through the fuel adjustment clause only when the actual mining costs are below 98% of the benchmark price. The benchmark price used the GDP-IPD index as a proxy for the numerous escalators in the previous mining contract. During the course of the contract, Cleco Power and SWEPCO determined that the GDP-IPD index did not appropriately reflect the increase in mining costs caused by sharp increases in diesel fuel and electricity costs associated with the mining operation. Because of this disconnect between the GDP-IPD index and actual mining costs, a significant amount of mining costs was being deferred by Cleco Power.

In 2006, Cleco Power recognized that there was a possibility it may not recover all or part of the lignite mining costs it had deferred. On November 15, 2006, Cleco Power and SWEPCO submitted a joint application to the LPSC requesting

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approval for Cleco Power to recover its existing deferral balance, and eliminate any future benchmarking of lignite mining costs. In December 2007, the LPSC approved a settlement agreement between Cleco Power, SWEPCO and the LPSC Staff authorizing Cleco Power to recover the existing deferred mining cost balance, including interest, over approximately 11.5 years. The settlement also established a new benchmark utilizing the contract’s escalators to assure a minimum 2% savings to customers compared to the costs under the prior mining contract. Under the settlement, the benchmarking was scheduled to end after April 2011. Cleco Power and SWEPCO also agreed to commit to continued operation of the mining operation through 2016 as long as the operation of the mine was considered prudent. Cleco Power did not record any additional deferred fuel costs under the new benchmarking method.

In September 2009, in connection with its approval of the Oxbow Lignite Mine acquisition, the LPSC agreed to discontinue benchmarking and the corresponding potential to defer future lignite mining costs while preserving the recovery of the legacy deferred fuel balance previously authorized. At December 31, 2009, and 2008, Cleco Power had $24.2 million and $26.8 million, respectively, in deferred costs remaining uncollected.

Advanced Metering Infrastructure

In October 2009, Cleco Power received notification of its selection to receive a $20.0 million grant from the DOE to deploy advanced metering infrastructure technology for Cleco Power’s 277,000 customers. Cleco Power applied to the DOE under a small grant process, which capped the grant award at $20.0 million. The DOE selected 100 smart-grid initiatives out of approximately 400 applications for funding under the smart-grid investment grant program. The grant program is a part of the American Recovery and Reinvestment Act of 2009, an economic stimulus package passed by Congress in February 2009.

Implementing smart-grid technology includes installing smart meters with two-way communication capabilities along with implementing a territory-wide communication network and data management system. Cleco Power’s primary initial benefit is savings gained through operational efficiencies. Another benefit is increased information about customer usage, which will give Cleco Power better distribution system planning data, better response to customer usage questions, and faster detection and restoration of system outages. Future benefits could include providing customers with real-time energy usage information and rate options.

Cleco Power estimates the project will cost $73.0 million, with the DOE grant providing $20.0 million toward the project and Cleco Power providing the remaining $53.0 million. Cleco Power is currently reviewing additional actions the DOE may require, whether the LPSC will allow acceptable treatment, and how Cleco plans to fund the remaining $53.0 million. Cleco Power, therefore, has not yet accepted the DOE grant. If Cleco Power decides to accept the grant and move forward with the project, the project will be expected to be completed in 2012.

Oxbow Lignite Mine Acquisition

In April 2009, Cleco Power entered into an agreement with SWEPCO to purchase Oxbow from NAC. In September 2009, the LPSC approved the joint application authorizing the acquisition of Oxbow. On December 29, 2009, Cleco Power and SWEPCO completed the transaction. Cleco Power’s 50% portion of the purchase price for the lignite reserves was $12.9 million. SWEPCO likewise paid $12.9 million for its 50% interest in the lignite reserves. SWEPCO’s subsidiary, DHLC, acquired the mining equipment and related assets and permits for $15.6 million and will operate the new mine along with its current operations at the Dolet Hills Lignite Mine on similar terms. The recoverable lignite reserves of approximately 100 million tons contained within the Oxbow Mine permit area, together with the reserves from the Dolet Hills Lignite Mine are expected to be sufficient to fuel the Dolet Hills Power Station until at least 2026. The existing Red River Lignite Supply and Transportation Agreement with NAC terminated upon the closing of this transaction.

Teche Blackstart Project

In January 2009, Cleco Power filed an application with the LPSC to improve its blackstart process by purchasing a 33-MW gas turbine to be sited at the Teche Power Station and designated as Teche Unit 4. The purpose of the project is to allow Cleco Power to return its generating system to service more efficiently than is currently possible in the event of a total system shutdown. As part of the Teche Power Station, Teche Unit 4 will be located in a region known as the Acadiana Load Pocket, an area that has experienced considerable growth in recent years. Cleco Power chose to acquire a refurbished gas turbine at considerable cost savings as compared to purchasing a similar new unit. The LDEQ issued an air permit in November 2009. The LPSC application was approved in December 2009.

At December 31, 2009, Cleco Power had incurred $8.9 million of the estimated $31.0 million total expenditures for this project. This estimate includes the necessary upgrades to allow the purchased unit to also function as a generation resource suitable for peaking capacity. Phase I of the project, which included procurement of the gas turbine, has been completed. Phase II, which includes site construction, is expected to begin in March 2010, and the project is expected to be completed in the second quarter of 2011.

Pension Protection Act of 2006

In August 2006, the President signed the Pension Protection Act of 2006. The new law replaces the defined benefit pension plan funding rules with a new funding system that became effective in 2008. Plan contributions are required if assets are less than 100% of liabilities. Pension plans that were not fully funded at the beginning of 2008 were to meet interim targets of 92% in 2008, 94% in 2009, and 96% in 2010.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

Furthermore, the calculation for the pension funding liability was subject to a new methodology beginning in 2008. The new methodology features the yield on investment grade corporate bonds (of the highest quality rating levels) with maturity dates that match the durations of the pension liabilities owed plan participants (broken down into three maturity segments). A temporary extension of the single corporate bond rate remained in effect for plan year 2007.

In December 2008, this Act was amended. The primary amendments include allowing a phase-in of the funding targets, allowing a 24-month asset smoothing and allowing plans to look back to prior year funding percentages to determine restrictions on benefits.

Cleco expects the implementation of the Pension Protection Act, in conjunction with the material 2008 plan portfolio losses, will result in annual pension contributions going-forward that are significantly higher than those estimates calculated in prior years. For a discussion of certain risks related to market conditions, see item 1A, “Risk Factors — Global Economic Downturn.”

New Accounting Standards

For discussion of new accounting standards, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 2 — Summary of Significant Accounting Policies — Recent Authoritative Guidance.”

ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Risk Overview

Market risk inherent in Cleco’s market risk-sensitive instruments and positions includes potential changes arising from changes in interest rates and the commodity market prices of power and natural gas in the industry on different energy exchanges. Cleco is subject to market risk associated with economic hedges relating to open natural gas contracts. Cleco also is subject to market risk associated with its remaining tolling agreement counterparty. For additional information concerning Cleco’s market risk associated with its remaining counterparty, see Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Liquidity and Capital Resources — General Considerations and Credit-Related Risks.”

Cleco uses the authoritative guidance on derivatives and hedging to determine whether the market risk-sensitive instruments and positions are required to be marked-to-market. Generally, Cleco Power’s market risk-sensitive instruments and positions qualify for the normal-purchase, normal-sale exception to mark-to-market accounting since Cleco Power takes physical delivery and the instruments and positions are used to satisfy customer requirements.

Cleco’s exposure to market risk, as discussed below, represents an estimate of possible changes in the fair value or future earnings that would occur, assuming possible future movements in the interest rates and commodity prices of power and natural gas. Management’s views on market risk are not necessarily indicative of actual results, nor do they represent the maximum possible gains or losses. The views do represent, within the parameters disclosed, what management estimates may happen.

Cleco monitors credit risk exposure through reviews of counterparty credit quality, aggregate counterparty credit exposure, and aggregate counterparty concentration levels. Cleco manages these risks by establishing appropriate credit and concentration limits on transactions with counterparties and requiring contractual guarantees, cash deposits or letters of credit from counterparties or their affiliates, as deemed necessary. Cleco Power has agreements in place with various counterparties that authorize the netting of financial transactions and contract payments to mitigate credit risk for transactions entered into for risk management purposes.

Access to capital markets is a significant source of funding for both short- and long-term capital requirements not satisfied by operating cash flows. Recent market conditions have limited the availability and have increased the costs of capital for many companies. The inability to raise capital on favorable terms could negatively affect Cleco’s ability to maintain and expand its businesses. After assessing the current operating performance, liquidity, and credit ratings, management believes that it will have access to the capital markets at prevailing market rates for companies with comparable credit ratings. In November 2009, Moody’s downgraded Cleco Power’s credit rating by one level. This downgrade placed Cleco Power’s credit rating at Moody’s at a level similar to Cleco Power’s credit rating at Standard & Poor’s. Cleco Corporation and Cleco Power pays fees and interest under its bank credit agreements based on the highest rating held. If Cleco Corporation or Cleco Power’s credit rating were to be downgraded by Moody’s and Standard & Poor’s, Cleco Corporation and/or Cleco Power would be required to pay additional fees and higher interest rates under its bank credit agreements. Cleco Power’s collateral for derivatives is based on the lowest rating held. If Cleco Power’s credit ratings were to be downgraded by Standard & Poor’s or Moody’s, Cleco Power would be required to pay additional collateral for derivatives.

Interest Rate Risks

Cleco monitors its mix of fixed- and variable-rate debt obligations in light of changing market conditions and from time to time may alter that mix, for example, refinancing balances outstanding under its variable-rate credit facility with fixed-rate debt. For details, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 6 — Debt.” Calculations of the changes in fair market value and interest expense of the debt securities are made over a one-year period.

Sensitivity to changes in interest rates for fixed-rate obligations is computed by calculating the current fair market value using a net present value model based upon a 1% change in

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

the average interest rate applicable to such debt. Sensitivity to changes in interest rates for variable-rate obligations is computed by assuming a 1% change in the current interest rate applicable to such debt.

As of December 31, 2009, the carrying value of Cleco’s long-term fixed-rate debt was approximately $1.2 billion, with a fair market value of approximately $1.2 billion. There is a $33.9 million difference between the carrying value of the debt and the market value of such debt which is driven by the spread between the stated rate of Cleco’s debt as compared to the current market yield for debt with similar risk profiles, maturities, and terms as Cleco’s debt. Fair value was determined using quoted market prices. Each 1% increase in the average interest rates applicable to such debt would result in a corresponding decrease of approximately $70.7 million in the fair value of these instruments. If these instruments are held to maturity, no change in stated value will be realized.

Cleco had no short-term variable-rate debt as of December 31, 2009.

At December 31, 2009, Cleco Corporation had $95.0 million principal amount of long-term variable-rate debt outstanding under its $150.0 million five-year credit facility at a weighted interest rate of 0.763%. The borrowings under the credit facility are considered long-term as the credit facility does not expire until 2011. The borrowing costs under the facility are equal to LIBOR plus 0.65%, including facility fees. The existing borrowings had 30-day terms and matured on January 15, 2010, and January 29, 2010; $75.0 million of the borrowings were renewed at maturity, rather than repaid. Each 1% increase in the interest rate applicable to such debt would have resulted in a $1.0 million decrease in pre-tax earnings of Cleco.

Cleco Power had an additional $50.0 million long-term variable rate debt outstanding. For more information regarding Cleco Power’s long-term variable-rate debt outstanding and interest rate swap, refer to “— Cleco Power” below.

Commodity Price Risks

Management believes Cleco has controls in place to minimize the risks involved in its financial and energy commodity activities. Independent controls over energy commodity functions consist of a middle office (risk management), a back office (accounting), regulatory compliance staff, as well as monitoring by a risk management committee comprised of officers and the General Manager – Internal Audit, who are approved by Cleco Corporation’s Board of Directors. Risk limits are recommended by the Risk Management Committee and monitored through a daily risk report that identifies the current VaR, current market conditions, and concentration of energy market positions.

During 2005, Cleco Power entered into certain financial hedge transactions it considers economic hedges to mitigate the risk associated with fixed-price power to be provided to a wholesale customer through December 2010. These transactions are derivatives as defined by the authoritative guidance on derivatives and hedging but do not meet the accounting criteria to be considered hedges. These transactions are marked-to-market with the resulting gain or loss recorded on the income statement as a component of operating revenue. At December 31, 2009, the positions had a negative mark-to-market value of $0.4 million, which is a decrease of $0.2 million from the negative mark-to-market value of $0.2 million at December 31, 2008. In addition, these positions resulted in a realized loss of $1.6 million in 2009. In light of these economic hedge transactions, volatility in natural gas prices will likely cause fluctuations in the market value of open natural gas positions and ultimately in Cleco Power’s future earnings.

Cleco Power provides fuel for generation and purchases power to meet the power demands of customers. Cleco Power has entered into positions to mitigate the volatility in customer fuel costs, as encouraged by an LPSC order. Cleco Power’s fuel stabilization policy targets higher levels of minimum hedging percentages and mitigate the volatility in customer fuel costs. The change in positions could result in increased volatility in the marked-to-market amounts for the financial positions. These positions are marked-to-market with the resulting gain or loss recorded on the balance sheet as a component of the accumulated deferred fuel asset or liability and a component of the risk management assets or liabilities. When these positions close, actual gains or losses are deferred and included in the fuel adjustment clause in the month the physical contract settles. Based on market prices at year end, the net mark-to-market impact related to open natural gas positions at December 31, 2009, and 2008, were losses of $24.9 million and $57.4 million, respectively. The majority of these natural gas positions will close over the next twelve months. Deferred losses relating to closed natural gas positions at December 31, 2009, and 2008, totaled $2.6 million and $6.4 million, respectively.

Cleco utilizes a VaR model to assess the market risk of its hedging portfolios, including derivative financial instruments. VaR represents the potential loss in fair value for an instrument from adverse changes in market factors over a defined period of time with a specified confidence level. VaR is calculated daily, using the variance/covariance method with delta approximation, assuming a holding period of one day, and a 95% confidence level for natural gas and power positions. Volatility is calculated daily from historical forward prices using the exponentially weighted moving average method.

Based on these assumptions, the VaR relating to Cleco Power’s hedge transactions for 2009, as well as the VaR at December 31, 2009, and 2008, are summarized in the following table.

	FOR THE YEAR ENDED DECEMBER 31, 2009						AT DECEMBER 31,
(THOUSANDS)	HIGH		LOW		AVERAGE		2009		2008
Economic hedges	$	268.1	$	69.4	$	139.7	$	110.9	$	239.0
Fuel cost hedges	$	7,292.8	$	1,846.0	$	3,879.8	$	2,848.5	$	6,519.0

All open positions were transacted by Cleco Power. The decrease in VaR for economic hedges at December 31, 2009, compared to December 31, 2008, is primarily due to the decrease in forward positions. Under Cleco’s economic hedge VaR model, changes in market value of open positions in excess of $0.2 million over Cleco’s estimated VaR are deemed

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

material. During 2009, the $0.2 million limit was exceeded seven times.

The following table summarizes the market value maturities of open natural gas contracts at December 31, 2009. All contracts were transacted by Cleco Power.

(THOUSANDS)	MATURITY LESS THAN ONE YEAR		MATURITY 1-3 YEARS		MATURITY OVER THREE YEARS		TOTAL FAIR VALUE
Assets	$	50	$	-	$	-	$	50
Liabilities	$	65,589	$	40,661	$	-	$	106,250

For additional information on the market value maturities of contracts, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 5 — Fair Value Accounting.”

Cleco Power

Please refer to “— Risk Overview” above for a discussion of market risk inherent in Cleco Power’s market risk-sensitive instruments.

Cleco Power has entered into various fixed- and variable-rate debt obligations. For details, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 6 — Debt.” Please refer to “— Interest Rate Risks” above for a discussion of how Cleco Power monitors its mix of fixed- and variable-rate debt obligations and the manner of calculating changes in fair market value and interest expense of its debt obligations.

As of December 31, 2009, the carrying value of Cleco Power’s long-term fixed-rate debt was approximately $1.2 billion, with a fair market value of approximately $1.2 billion. There is a $33.9 million difference between the carrying value of the debt and the market value of such debt which is driven by the spread between the stated rate of Cleco Power’s debt as compared to the current market yield for debt with similar risk profiles, maturities, and terms as Cleco Power’s debt. Fair value was determined using quoted market prices. Each 1% increase in the average interest rates applicable to such debt would result in a corresponding decrease of approximately $70.7 million in the fair values of these instruments. If these instruments are held to maturity, no change in stated value will be realized.

Cleco Power had no short-term variable-rate debt as of December 31, 2009.

At December 31, 2009, Cleco Power had $50.0 million of long-term variable-rate debt outstanding with an interest rate of 3.00% plus one-month LIBOR. Each 1% increase in the interest rate applicable to such debt would cause a $0.5 million decrease in the pre-tax earnings of Cleco Power. During 2009, Cleco Power locked in an interest rate swap, effective concurrent with issuing the $50.0 million variable-rate debt, for the notional amount of the debt requiring a monthly net settlement between Cleco Power’s fixed 1.84% and the swap counterparty’s floating payment of the one-month LIBOR. Each 1% increase in the interest rate applicable to the interest rate swap would cause a $0.5 million increase in the pre-tax earnings of Cleco Power.

At December 31, 2009, Cleco Power had no borrowings outstanding under its $275.0 million five-year credit facility.

Please refer to “— Commodity Price Risks” above for a discussion of controls, transactions, VaR, and market value maturities associated with Cleco Power’s energy commodity activities.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

Report of Independent Registered Public Accounting Firm

To the Shareholders and Board of

Directors of Cleco Corporation:

In our opinion, the consolidated financial statements listed in the index appearing under Item 15(a)(1) present fairly, in all material respects, the financial position of Cleco Corporation (the “Company”) and its subsidiaries at December 31, 2009 and 2008, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2009 in conformity with accounting principles generally accepted in the United States of America. In addition, in our opinion, the financial statement schedules listed in the index appearing under Item 15(a)(2) present fairly, in all material respects, the information set forth therein when read in conjunction with the related consolidated financial statements. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2009, based on criteria established in Internal Control - Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). The Company’s management is responsible for these financial statements and financial statement schedules, for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in Management's Report on Internal Control Over Financial Reporting appearing under Item 9A. Our responsibility is to express opinions on these financial statements, on the financial statement schedules, and on the Company's internal control over financial reporting based on our integrated audits. We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the financial statements are free of material misstatement and whether effective internal control over financial reporting was maintained in all material respects. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.

As discussed in Note 2 to the consolidated financial statements, the Company changed the manner in which it accounts for uncertain tax positions in 2007.

A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

/s/ PricewaterhouseCoopers LLP

New Orleans, Louisiana

February 25, 2010

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

Report of Independent Registered Public Accounting Firm

To the Member and Board of

Managers of Cleco Power LLC:

In our opinion, the consolidated financial statements listed in the index appearing under Item 15 (a)(1) present fairly, in all material respects, the financial position of Cleco Power LLC and its subsidiary (the “Company”) at December 31, 2009 and 2008, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2009 in conformity with accounting principles generally accepted in the United States of America. In addition, in our opinion, the financial statement schedule listed in the index appearing under Item 15 (a)(2) presents fairly, in all material respects, the information set forth therein when read in conjunction with the related consolidated financial statements. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2009, based on criteria established in Internal Control - Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). The Company's management is responsible for these financial statements and financial statement schedule, for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in Management's Report on Internal Control Over Financial Reporting appearing under Item 9A. Our responsibility is to express opinions on these financial statements, on the financial statement schedule, and on the Company's internal control over financial reporting based on our audits (which was an integrated audit in 2009). We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the financial statements are free of material misstatement and whether effective internal control over financial reporting was maintained in all material respects. Our audits of the financial statements included examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.

As discussed in Note 2 to the consolidated financial statements, the Company changed the manner in which it accounts for uncertain tax positions in 2007.

/s/ PricewaterhouseCoopers LLP

New Orleans, Louisiana

February 25, 2010

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

CLECO CORPORATION

Consolidated Statements of Income

	FOR THE YEAR ENDED DECEMBER 31,
(THOUSANDS, EXCEPT SHARE AND PER SHARE AMOUNTS)	2009			2008			2007
Operating revenue
Electric operations	$	808,646		$	1,032,970		$	988,193
Other operations		33,651			36,768			35,285
Affiliate revenue		11,461			10,460			7,138
Total operating revenue		853,758			1,080,198			1,030,616
Operating expenses
Fuel used for electric generation		261,456			235,706			273,954
Power purchased for utility customers		216,906			471,261			385,247
Other operations		109,060			99,028			102,479
Maintenance		51,300			47,089			49,498
Depreciation		78,204			77,876			79,904
Taxes other than income taxes		29,947			34,471			41,975
Loss (gain) on sales of assets		76			(110	)		15
Total operating expenses		746,949			965,321			933,072
Operating income		106,809			114,877			97,544
Interest income		1,512			5,417			11,754
Allowance for other funds used during construction		73,269			64,953			32,955
Equity (loss) income from investees		(17,423	)		(5,542	)		93,148
Other income		5,581			1,263			29,531
Other expense		(2,807	)		(7,970	)		(4,405	)
Interest charges
Interest charges, including amortization of debt expenses, premium and discount, net of capitalized interest		77,228			72,042			51,111
Allowance for borrowed funds used during construction		(26,173	)		(19,642	)		(13,145	)
Total interest charges		51,055			52,400			37,966
Income before income taxes		115,886			120,598			222,561
Federal and state income tax expense		9,579			18,457			70,772
Net income		106,307			102,141			151,789
Preferred dividends requirements, net of tax		46			46			458
Net income applicable to common stock	$	106,261		$	102,095		$	151,331
Average shares of common stock outstanding
Basic		60,187,894			59,990,229			58,976,052
Diluted		60,498,205			60,214,640			59,717,528
Basic earnings per share
Net income applicable to common stock	$	1.77		$	1.70		$	2.55
Diluted earnings per share
Net income applicable to common stock	$	1.76		$	1.70		$	2.54
Cash dividends paid per share of common stock	$	0.900		$	0.900		$	0.900
The accompanying notes are an integral part of the consolidated financial statements.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

CLECO CORPORATION

Consolidated Balance Sheets

	AT DECEMBER 31,
(THOUSANDS)	2009			2008
Assets
Current assets
Cash and cash equivalents	$	145,193		$	97,483
Restricted cash		29,941			62,311
Customer accounts receivable (less allowance for doubtful accounts of $1,173 in 2009 and $1,632 in 2008)		29,550			40,677
Accounts receivable – affiliate		12,129			3,428
Other accounts receivable		28,878			34,209
Taxes receivable		15,449			13,663
Unbilled revenue		21,975			19,713
Fuel inventory, at average cost		80,038			57,221
Material and supplies inventory, at average cost		41,410			37,547
Risk management assets		2,854			368
Accumulated deferred federal and state income taxes, net		6,799			-
Accumulated deferred fuel		35,059			69,154
Cash surrender value of company-/trust-owned life insurance policies		30,269			22,934
Prepayments		3,571			3,751
Regulatory assets – other		9,914			2,553
Other current assets		896			1,367
Total current assets		493,925			466,379
Property, plant and equipment
Property, plant and equipment		2,144,491			2,015,269
Accumulated depreciation		(999,204	)		(948,581	)
Net property, plant and equipment		1,145,287			1,066,688
Construction work in progress		1,101,743			978,598
Total property, plant and equipment, net		2,247,030			2,045,286
Equity investment in investees		251,617			249,144
Prepayments		5,096			6,067
Restricted cash		26,510			40,671
Regulatory assets and liabilities – deferred taxes, net		264,343			174,804
Regulatory assets – other		201,381			158,206
Intangible asset		157,098			167,826
Other deferred charges		47,847			32,821
Total assets	$	3,694,847		$	3,341,204
The accompanying notes are an integral part of the consolidated financial statements.

(Continued on next page)

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

CLECO CORPORATION

Consolidated Balance Sheets (Continued)

	AT DECEMBER 31,
(THOUSANDS)	2009			2008
Liabilities and shareholders’ equity
Liabilities
Current liabilities
Long-term debt due within one year	$	11,478		$	63,546
Accounts payable		111,358			117,337
Retainage		813			12,734
Accounts payable – affiliate		2,370			8,229
Customer deposits		34,195			27,155
Interest accrued		11,880			16,787
Accumulated current deferred taxes, net		-			64,838
Risk management liability		13,767			30,109
Regulatory liabilities - other		33,592			392
Deferred compensation		7,091			5,118
Other current liabilities		15,260			14,588
Total current liabilities		241,804			360,833
Deferred credits
Accumulated deferred federal and state income taxes, net		460,894			373,825
Accumulated deferred investment tax credits		9,954			11,286
Postretirement benefit obligations		146,270			155,910
Regulatory liabilities – other		149,638			85,496
Restricted storm reserve		25,434			27,411
Uncertain tax positions		115,643			76,124
Other deferred credits		108,839			82,635
Total deferred credits		1,016,672			812,687
Long-term debt, net		1,320,299			1,106,819
Total liabilities		2,578,775			2,280,339
Commitments and Contingencies (Note 15)
Shareholders’ equity
Preferred stock
Not subject to mandatory redemption, $100 par value, authorized 1,491,900 shares, issued 10,288 shares at December 31, 2009, and 2008, respectively		1,029			1,029
Common shareholders’ equity
Common stock, $1 par value, authorized 100,000,000 shares, issued 60,277,462 and 60,066,345 shares and outstanding 60,259,368 and 60,042,514 shares at December 31, 2009, and 2008, respectively		60,277			60,066
Premium on common stock		399,148			394,517
Retained earnings		667,220			615,514
Treasury stock, at cost 18,094 and 23,831 shares at December 31, 2009, and 2008, respectively		(311	)		(428	)
Accumulated other comprehensive loss		(11,291	)		(9,833	)
Total common shareholders’ equity		1,115,043			1,059,836
Total shareholders’ equity		1,116,072			1,060,865
Total liabilities and shareholders’ equity	$	3,694,847		$	3,341,204
The accompanying notes are an integral part of the consolidated financial statements.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

CLECO CORPORATION

Consolidated Statements of Cash Flows

	FOR THE YEAR ENDED DECEMBER 31,
(THOUSANDS)	2009			2008			2007
Operating activities
Net income	$	106,307		$	102,141		$	151,789
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization		121,436			120,652			82,131
Loss (gain) on sales of property, plant and equipment		76			(110	)		15
Provision for doubtful accounts		1,682			3,826			2,873
Proceeds from sale of bankruptcy settlement claims		-			-			78,200
Return on equity investment in investees		750			5,106			68,702
Loss (income) from equity investments		17,423			5,542			(93,148	)
Unearned compensation expense		6,087			2,540			8,111
Employee stock ownership plan expense		-			-			2,721
Allowance for other funds used during construction		(73,269	)		(64,953	)		(32,955	)
Amortization of investment tax credits		(1,332	)		(1,380	)		(1,435	)
Net deferred income taxes		(5,983	)		5,154			6,180
Deferred fuel costs		7,223			6,444			11,024
Loss (gain) on economic hedges		167			2,213			(1,066	)
Cash surrender value of company-/trust-owned life insurance		(5,180	)		5,334			(1,042	)
Changes in assets and liabilities:
Accounts receivable		8,310			(5,557	)		(12,206	)
Accounts and notes receivable, affiliate		(8,701	)		14,242			15,198
Unbilled revenue		(2,262	)		(1,954	)		623
Fuel, materials and supplies inventory		(26,680	)		(12,282	)		(3,363	)
Prepayments		1,575			1,050			1,111
Accounts payable		11,231			2,806			10,008
Accounts and notes payable, affiliate		(22,796	)		(34,260	)		(11,598	)
Customer deposits		12,906			5,961			5,447
Postretirement benefit obligations		(11,555	)		4,899			(431	)
Regulatory assets and liabilities, net		32,922			43,790			18,532
Other deferred accounts		(46,051	)		(114,855	)		(20,356	)
Retainage payable		(11,921	)		12,709			(12,384	)
Taxes accrued		23,612			1,984			(27,906	)
Interest accrued		(4,138	)		(4,439	)		954
Risk management assets and liabilities, net		4,406			(16,482	)		15,672
Other operating		(1,066	)		(595	)		1,624
Net cash provided by operating activities(1)		135,179			89,526			263,025
Investing activities
Additions to property, plant and equipment		(250,286	)		(335,757	)		(510,192	)
Allowance for other funds used during construction		73,269			64,953			32,955
Proceeds from sale of property, plant and equipment		751			1,894			601
Return of equity investment in investee		850			3,852			96
Equity investment in investees		(45,539	)		(18,522	)		(8,427	)
Premiums paid on company-/trust-owned life insurance		(2,752	)		(1,664	)		(2,232	)
Transfer of cash from (to) restricted accounts		46,531			(85,021	)		6,490
Other investing		-			1,540			-
Net cash used in investing activities(1)		(177,176	)		(368,725	)		(480,709	)

(Continued on next page)

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

CLECO CORPORATION

Consolidated Statements of Cash Flows (Continued)

	FOR THE YEAR ENDED DECEMBER 31,
(THOUSANDS)	2009			2008			2007
Financing activities
Retirement of long-term obligations		(114,846	)		(350,296	)		(50,207	)
Repayment of capital leases		(1,422	)		(116	)		(111	)
Issuance of long-term debt		255,369			651,541			250,000
Deferred financing costs		(1,953	)		(361	)		(2,593	)
Settlement of treasury rate lock		4,696			-			-
Dividends paid on preferred stock		(46	)		(46	)		(458	)
Dividends paid on common stock		(54,221	)		(54,036	)		(53,282	)
Other financing		2,130			983			10,877
Net cash provided by financing activities		89,707			247,669			154,226
Net increase (decrease) in cash and cash equivalents		47,710			(31,530	)		(63,458	)
Cash and cash equivalents at beginning of period		97,483			129,013			192,471
Cash and cash equivalents at end of period	$	145,193		$	97,483		$	129,013
Supplementary cash flow information
Interest paid (net of amount capitalized)	$	84,629		$	52,913		$	52,045
Income taxes (refunded) paid, net	$	(30,309	)	$	40,213		$	87,631
Supplementary noncash investing and financing activities
Accrued additions to property, plant and equipment not reported above	$	3,069		$	16,935		$	30,179
Incurrence of capital lease obligation - barges	$	22,050		$	-		$	-
Return on equity investment in investee	$	-		$	-		$	78,200
Issuance of treasury stock – LTICP	$	117		$	103		$	86
Issuance of common stock – LTICP/ESPP (2)	$	290		$	163		$	22,151
(1) Non-cash activities between the operating and investing sections in the amount of $222.1 million are excluded from the 2008 cash flow statement. These non-cash activities are related to 2008 storm costs and storm financing. There were no similar activities in 2009.
(2) Includes conversion of preferred stock to common stock of $19,063 in 2007.
The accompanying notes are an integral part of the consolidated financial statements.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

CLECO CORPORATION

Consolidated Statements of Comprehensive Income

	FOR THE YEAR ENDED DECEMBER 31,
(THOUSANDS)	2009			2008			2007
Net income	$	106,307		$	102,141		$	151,789
Other comprehensive (loss) income, net of tax:
Net unrealized loss from available-for-sale securities (net of tax benefit of $11 in 2008, and 2007)		-			(73	)		(18	)
Amortization of post-retirement benefit net losses (net of tax benefit of $158 in 2009, $193 in 2008, and $29 in 2007)		(160	)		(215	)		(18	)
Post-retirement benefit (loss) gain incurred during the year (net of tax benefit of $2,553 in 2009, $668 in 2008, and tax expense of $806 in 2007)		(3,403	)		(1,154	)		955
Cash flow hedges:
Net derivatives loss arising during the period (net of tax benefit of $456 in 2009)		(730	)		-			-
Reclassification of interest expense (net of tax expense of $115 in 2009)		184			-			-
Net gain from treasury rate lock (net of tax expense of $1,664 in 2009)		2,660			-			-
Reclassification of interest expense (net of tax benefit of $5 in 2009)		(9	)		-			-
Other comprehensive (loss) income, net of tax		(1,458	)		(1,442	)		919
Comprehensive income, net of tax	$	104,849		$	100,699		$	152,708
The accompanying notes are an integral part of the consolidated financial statements.

Consolidated Statements of Changes in Common Shareholders’ Equity

																	ACCUMULATED
					PREMIUM												OTHER			TOTAL
	COMMON STOCK				ON COMMON			RETAINED			TREASURY STOCK						COMPREHENSIVE			COMMON
(THOUSANDS, EXCEPT SHARE AMOUNTS)	SHARES		AMOUNT		STOCK			EARNINGS			SHARES			COST			LOSS			EQUITY
BALANCE, JANUARY 1, 2007		57,524,498	$	57,524	$	358,707		$	469,824			(31,957	)	$	(616	)	$	(9,310	)	$	876,129
Common stock issued for compensatory plans		2,447,447		2,448		32,933															35,381
Issuance of treasury stock						18						3,601			86						104
Common stock issuance costs						(93	)														(93	)
Dividend requirements, preferred stock, net									(458	)											(458	)
Cash dividends, common stock, $0.900 per share									(53,431	)											(53,431	)
Net income									151,789												151,789
Other comprehensive income, net of tax																		919			919
BALANCE, DECEMBER 31, 2007		59,971,945	$	59,972	$	391,565		$	567,724			(28,356	)	$	(530	)	$	(8,391	)	$	1,010,340
Common stock issued for compensatory plans		94,400		94		2,932															3,026
Issuance of treasury stock						20						4,525			102						122
Dividend requirements, preferred stock, net									(46	)											(46	)
Cash dividends, common stock, $0.900 per share									(54,305	)											(54,305	)
Net income									102,141												102,141
Other comprehensive loss, net of tax																		(1,442	)		(1,442	)
BALANCE, DECEMBER 31, 2008		60,066,345	$	60,066	$	394,517		$	615,514			(23,831	)	$	(428	)	$	(9,833	)	$	1,059,836
Common stock issued for compensatory plans		211,117		211		4,615															4,826
Issuance of treasury stock						16						5,737			117						133
Dividend requirements, preferred stock, net									(46	)											(46	)
Cash dividends, common stock, $0.900 per share									(54,555	)											(54,555	)
Net income									106,307												106,307
Other comprehensive loss, net of tax																		(1,458	)		(1,458	)
BALANCE, DECEMBER 31, 2009		60,277,462	$	60,277	$	399,148		$	667,220			(18,094	)	$	(311	)	$	(11,291	)	$	1,115,043
The accompanying notes are an integral part of the consolidated financial statements.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

CLECO POWER

Consolidated Statements of Income

	FOR THE YEAR ENDED DECEMBER 31,
(THOUSANDS)	2009			2008			2007
Operating revenue
Electric operations	$	808,646		$	1,032,970		$	988,193
Other operations		33,558			36,675			35,176
Affiliate revenue		1,395			2,037			2,050
Total operating revenue		843,599			1,071,682			1,025,419
Operating expenses
Fuel used for electric generation		261,456			235,706			273,954
Power purchased for utility customers		216,906			471,261			385,247
Other operations		99,704			93,288			97,320
Maintenance		47,179			43,030			46,704
Depreciation		77,064			76,420			78,522
Taxes other than income taxes		29,758			31,011			37,658
Loss on sales of assets		70			-			15
Total operating expenses		732,137			950,716			919,420
Operating income		111,462			120,966			105,999
Interest income		1,449			3,943			5,422
Allowance for other funds used during construction		73,269			64,953			32,955
Other income		2,370			1,467			1,793
Other expense		(3,525	)		(2,258	)		(2,318	)
Interest charges
Interest charges, including amortization of debt expenses, premium and discount		84,735			66,925			42,710
Allowance for borrowed funds used during construction		(26,173	)		(19,642	)		(13,145	)
Total interest charges		58,562			47,283			29,565
Income before income taxes		126,463			141,788			114,286
Federal and state income taxes		15,297			27,956			29,613
Net income	$	111,166		$	113,832		$	84,673
The accompanying notes are an integral part of the consolidated financial statements.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

CLECO POWER

Consolidated Balance Sheets

	AT DECEMBER 31,
(THOUSANDS)	2009			2008
Assets
Utility plant and equipment
Property, plant and equipment	$	2,127,536		$	1,999,119
Accumulated depreciation		(987,055	)		(937,568	)
Net property, plant and equipment		1,140,481			1,061,551
Construction work in progress		1,100,295			977,377
Total utility plant, net		2,240,776			2,038,928
Current assets
Cash and cash equivalents		138,113			91,542
Restricted cash		29,941			62,311
Customer accounts receivable (less allowance for doubtful accounts of $1,173 in 2009 and $1,632 in 2008)		29,550			40,677
Other accounts receivable		27,460			34,130
Taxes receivable		-			5,992
Accounts receivable – affiliate		2,836			2,059
Unbilled revenue		21,975			19,713
Fuel inventory, at average cost		80,038			57,221
Material and supplies inventory, at average cost		41,410			37,547
Accumulated deferred federal and state income taxes, net		3,634			-
Risk management assets		2,854			368
Prepayments		3,107			3,099
Regulatory assets – other		9,914			2,553
Accumulated deferred fuel		35,059			69,154
Cash surrender value of life insurance policies		5,845			5,563
Other current assets		350			1,144
Total current assets		432,086			433,073
Prepayments		5,096			6,067
Restricted cash, less current portion		26,413			40,574
Regulatory assets and liabilities – deferred taxes, net		264,343			174,804
Regulatory assets – other		201,381			158,206
Intangible asset		157,098			167,826
Equity investment in investee		12,873			-
Other deferred charges		23,896			22,119
Total assets	$	3,363,962		$	3,041,597
Liabilities and member’s equity
Member’s equity	$	1,009,849		$	929,178
Long-term debt, net		1,225,299			1,076,819
Total capitalization		2,235,148			2,005,997
Current liabilities
Long-term debt due within one year		11,478			63,546
Accounts payable		103,359			109,450
Accounts payable – affiliate		25,940			7,536
Retainage		813			12,734
Customer deposits		34,195			27,155
Taxes accrued		3,438			-
Interest accrued		11,854			16,762
Accumulated deferred taxes, net		-			67,233
Risk management liability		13,767			30,109
Regulatory liabilities – other		33,592			392
Other current liabilities		10,906			10,200
Total current liabilities		249,342			345,117
Commitments and Contingencies (Note 15)
Deferred credits
Accumulated deferred federal and state income taxes, net		451,671			337,148
Accumulated deferred investment tax credits		9,954			11,286
Postretirement benefit obligations		114,700			128,373
Regulatory liabilities – other		149,638			85,496
Restricted storm reserve		25,434			27,411
Uncertain tax positions		75,487			54,306
Other deferred credits		52,588			46,463
Total deferred credits		879,472			690,483
Total liabilities and member’s equity	$	3,363,962		$	3,041,597
The accompanying notes are an integral part of the consolidated financial statements.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

CLECO POWER

Consolidated Statements of Cash Flows

	FOR THE YEAR ENDED DECEMBER 31,
(THOUSANDS)	2009			2008			2007
Operating activities
Net income	$	111,166		$	113,832		$	84,673
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization		88,843			86,035			80,176
Loss on sales of property, plant and equipment		70			-			15
Provision for doubtful accounts		1,682			3,821			2,873
Unearned compensation expense		1,855			143			3,039
Allowance for other funds used during construction		(73,269	)		(64,953	)		(32,955	)
Amortization of investment tax credits		(1,332	)		(1,380	)		(1,435	)
Net deferred income taxes		3,230			14,482			(16,127	)
Deferred fuel costs		7,223			6,444			11,024
Loss (gain) on fuel hedges		167			2,213			(1,066	)
Cash surrender value of company-owned life insurance		(454	)		(427	)		(291	)
Changes in assets and liabilities:
Accounts receivable		9,646			(5,972	)		(12,013	)
Accounts and notes receivable, affiliate		(656	)		15,453			(14,444	)
Unbilled revenue		(2,262	)		(1,954	)		623
Fuel, materials and supplies inventory		(26,680	)		(12,282	)		(3,363	)
Prepayments		1,386			941			1,016
Accounts payable		10,831			942			9,991
Accounts and notes payable, affiliate		17,855			(11,826	)		(15,708	)
Customer deposits		12,906			5,961			5,447
Postretirement benefit obligations		(13,720	)		1,766			343
Regulatory assets and liabilities, net		32,922			43,790			17,758
Other deferred accounts		(37,021	)		(118,075	)		(20,813	)
Retainage payable		(11,921	)		12,709			(12,384	)
Taxes accrued		9,430			(12,950	)		(6,651	)
Interest accrued		(4,140	)		(67	)		358
Risk management assets and liabilities, net		4,406			(16,482	)		15,672
Other operating		(437	)		(86	)		1,833
Net cash provided by operating activities(1)		141,726			62,078			97,591
Investing activities
Additions to property, plant and equipment		(249,252	)		(334,652	)		(509,198	)
Allowance for other funds used during construction		73,269			64,953			32,955
Proceeds from sale of property, plant and equipment		751			1,894			601
Equity investment in investee		(12,873	)		-			-
Premiums paid on company-owned life insurance		(424	)		(424	)		(470	)
Transfer of cash from (to) restricted accounts		46,531			(85,019	)		6,495
Net cash used in investing activities(1)		(141,998	)		(353,248	)		(469,617	)
Financing activities
Retirement of long-term obligations		(114,846	)		(250,296	)		(50,207	)
Repayment of capital leases		(1,422	)		(116	)		(111	)
Issuance of long-term debt		190,369			621,541			250,000
Deferred financing costs		(1,954	)		(361	)		(2,590	)
Contribution from parent		-			-			85,000
Distribution to parent		(30,000	)		-			-
Settlement of treasury rate lock		4,696			-			-
Net cash provided by financing activities		46,843			370,768			282,092
Net increase (decrease) in cash and cash equivalents		46,571			79,598			(89,934	)
Cash and cash equivalents at beginning of period		91,542			11,944			101,878
Cash and cash equivalents at end of period	$	138,113		$	91,542		$	11,944
Supplementary cash flow information
Interest paid (net of amount capitalized)	$	81,508		$	47,840		$	45,026
Income taxes paid	$	4,444		$	2,100		$	67,966
Supplementary non-cash investing and financing information
Accrued additions to property, plant and equipment not reported above	$	3,069		$	16,935		$	30,179
Incurrence of capital lease obligation - barges	$	22,050		$	-		$	-
(1) Non-cash activities between the operating and investing sections in the amount of $222.1 million are excluded from the 2008 cash flow statement. These non-cash activities are related to 2008 storm costs and storm financing. There were no similar activities in 2009.
The accompanying notes are an integral part of the consolidated financial statements.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

CLECO POWER

Consolidated Statements of Comprehensive Income

	FOR THE YEAR ENDED DECEMBER 31,
(THOUSANDS)	2009			2008			2007
Net income	$	111,166		$	113,832		$	84,673
Other comprehensive (loss) income, before tax:
Amortization of post-retirement benefit net losses (net of tax benefit of $322 in 2009, $321 in 2008, and $262 in 2007)		(433	)		(431	)		(390	)
Post-retirement benefit (loss) gain incurred during the year (net of tax benefit of $1,715 in 2009, $162 in 2008, and tax expense of $447 in 2007)		(2,168	)		(333	)		423
Cash flow hedges:
Net derivatives loss arising during the period (net of tax benefit of $456 in 2009)		(730	)		-			-
Reclassification of interest expense (net of tax expense of $115 in 2009)		184			-			-
Net gain from treasury rate lock (net of tax expense of $1,664 in 2009)		2,660			-			-
Reclassification of interest expense (net of tax benefit of $5 in 2009)		(8	)		-			-
Other comprehensive (loss) income, net of tax		(495	)		(764	)		33
Comprehensive income, net of tax	$	110,671		$	113,068		$	84,706
The accompanying notes are an integral part of the consolidated financial statements.

Consolidated Statements of Changes in Member’s Equity

(THOUSANDS)	MEMBER’S EQUITY			ACCUMULATED OTHER COMPREHENSIVE LOSS			TOTAL MEMBER’S EQUITY
BALANCE, JANUARY 1, 2007	$	650,849		$	(4,445	)	$	646,404
Other comprehensive income, net of tax		-			33			33
Contribution from parent		85,000			-			85,000
Net income		84,673			-			84,673
BALANCE, DECEMBER 31, 2007		820,522			(4,412	)		816,110
Other comprehensive loss, net of tax		-			(764	)		(764	)
Net income		113,832			-			113,832
BALANCE, DECEMBER 31, 2008		934,354			(5,176	)		929,178
Other comprehensive loss, net of tax		-			(495	)		(495	)
Distribution to parent		(30,000	)		-			(30,000	)
Net income		111,166			-			111,166
BALANCE, DECEMBER 31, 2009	$	1,015,520		$	(5,671	)	$	1,009,849
The accompanying notes are an integral part of the consolidated financial statements.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

Index to Applicable Notes to the Financial Statements of Registrants

Note 1	The Company	Cleco Corporation and Cleco Power
Note 2	Summary of Significant Accounting Policies	Cleco Corporation and Cleco Power
Note 3	Regulatory Assets and Liabilities	Cleco Corporation and Cleco Power
Note 4	Jointly Owned Generation Units	Cleco Corporation and Cleco Power
Note 5	Fair Value Accounting	Cleco Corporation and Cleco Power
Note 6	Debt	Cleco Corporation and Cleco Power
Note 7	Common Stock	Cleco Corporation and Cleco Power
Note 8	Preferred Stock	Cleco Corporation
Note 9	Pension Plan and Employee Benefits	Cleco Corporation and Cleco Power
Note 10	Income Taxes	Cleco Corporation and Cleco Power
Note 11	Disclosures about Segments	Cleco Corporation
Note 12	Electric Customer Credits	Cleco Corporation and Cleco Power
Note 13	Equity Investment in Investees	Cleco Corporation
Note 14	Operating Leases	Cleco Corporation and Cleco Power
Note 15	Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees	Cleco Corporation and Cleco Power
Note 16	FERC Staff Investigations and LPSC Fuel Audit	Cleco Corporation and Cleco Power
Note 17	Affiliate Transactions	Cleco Corporation and Cleco Power
Note 18	Intangible Asset	Cleco Corporation and Cleco Power
Note 19	Storm Restoration	Cleco Corporation and Cleco Power
Note 20	Calpine Bankruptcy Settlement	Cleco Corporation
Note 21	Accumulated Other Comprehensive Loss	Cleco Corporation and Cleco Power
Note 22	Miscellaneous Financial Information (Unaudited)	Cleco Corporation and Cleco Power
Note 23	Subsequent Events	Cleco Corporation and Cleco Power

Notes to the Financial Statements

Note 1 — The Company

General

Cleco Corporation is a holding company composed of the following:

Cleco Power is an integrated electric utility services subsidiary regulated by the LPSC and FERC, which determine the rates Cleco Power can charge its customers, as well as other regulators. Cleco Power serves approximately 277,000 customers in 107 communities in central and southeastern Louisiana. Cleco Power also engages in energy management activities and owns a 50 percent interest in an entity that owns lignite reserves. Cleco Power owns all of the outstanding membership interests in Cleco Katrina/Rita, a special purpose entity, that is consolidated with Cleco Power in its financial statements.

Midstream is a merchant energy subsidiary regulated by FERC. Midstream owns and operates a merchant power plant (Evangeline) and at December 31, 2009, owned a 50 percent interest in a merchant power plant (Acadia), which it operated on behalf of its partner. For more information on agreements Acadia has entered into with Cleco Power and Entergy Louisiana for the purchase of the Acadia plant, see Note 15 — “Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Acadia Transactions” and Note 23 — “Subsequent Events — Evangeline Transactions” and “— Acadia Transaction.”

§	Cleco Corporation’s other operations consist of a holding company, two transmission interconnection facility subsidiaries, a shared services subsidiary, and an investment subsidiary.

Note 2 — Summary of Significant Accounting Policies

Use of Estimates

Principles of Consolidation

The accompanying consolidated financial statements of Cleco include the accounts of Cleco and its majority-owned subsidiaries after elimination of intercompany accounts and transactions.

Using the authoritative guidance for variable interest entities, Cleco has determined that it is not the primary beneficiary of Evangeline, Perryville, Attala, Acadia, and Oxbow. Cleco determined it was not the primary beneficiary by examining all interests that could absorb expected losses and expected gains. This examination used assumptions about the expected rate of inflation, changes in the market price of natural gas as compared to the market price of electricity, length of

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

contracts, variability of revenue stream as compared to variability of expenses, and maximum exposure to loss. Cleco reports its investment in these entities on the equity method of accounting. As a result, the assets and liabilities of these entities are represented by one line item corresponding to Cleco’s equity investment in these entities. The pre-tax results of operations of these entities are reported as equity income or loss from investees on Cleco Corporation’s Consolidated Statements of Income. For additional information on the operations of these entities, see Note 13 — “Equity Investment in Investees.”

Reclassifications

Certain reclassifications have been made to the 2008 and 2007 financial statements to conform them to the presentation used in the 2009 financial statements. These reclassifications had no effect on Cleco Corporation’s net income applicable to common stock or total common shareholders’ equity or Cleco Power’s net income or total member’s equity.

Statements of Cash Flows

The Consolidated Statements of Cash Flows of Cleco Corporation and the Consolidated Statements of Cash Flows of Cleco Power are prepared using the “indirect method” described in the authoritative guidance for the presentation of the statement of cash flows. This method requires that net income be adjusted to remove the effects of all deferrals and accruals of operating cash receipts and payments and the effects of all investing and financing cash flow items. Derivatives meeting the definition of an accounting hedge are classified in the same category as the item being hedged.

Regulation

Cleco Power maintains its accounts in accordance with the Uniform System of Accounts prescribed for electric utilities by FERC, as adopted by the LPSC. Cleco Power’s retail rates are regulated by the LPSC, and its rates for transmission services and wholesale power sales are regulated by FERC. Cleco Power follows the authoritative guidelines for industry regulated operations, which allows utilities to capitalize or defer certain costs based on regulatory approval, and management’s ongoing assessment that it is probable these items will be recovered through the ratemaking process.

Pursuant to this authoritative guidance, Cleco Power has recorded regulatory assets and liabilities primarily for the effects of income taxes. In addition, Cleco Power has recorded regulatory assets for deferred mining costs, interest costs, estimated future asset removal costs, postretirement plan costs, tree trimming costs, training costs, storm surcredit, fuel and energy purchases, and related hedging gains and losses, and has recorded regulatory liabilities for fuel transportation revenue and recovered construction carrying costs, as a result of rate actions of regulators. For information regarding the regulatory assets and liabilities recorded by Cleco Power, see Note 3 — “Regulatory Assets and Liabilities.”

Any future plan adopted by the LPSC for purposes of transitioning utilities from LPSC regulation to retail competition may affect the regulatory assets and liabilities recorded by Cleco Power if the criteria for the application of the authoritative guidelines for industry regulated operations cannot continue to be met. At this time, Cleco cannot predict whether any legislation or regulation affecting Cleco Power will be enacted or adopted and, if enacted, what form such legislation or regulation may take.

Asset Retirement Obligation

Cleco has recorded asset retirement obligations (liabilities) in accordance with the authoritative guidance. This authoritative guidance requires an entity to record an ARO when there is a legal obligation under existing or enacted law, statute, written or oral contract, or by legal construction under the doctrine of promissory estoppel to incur costs to remove an asset when the asset is retired. These guidelines also require an ARO which is conditional on a future event to be recorded even if the event has not yet occurred.

At the point the liability for asset retirement is incurred, the authoritative guidance requires capitalization of the costs to the related property, plant and equipment asset. For asset retirement obligations existing at the time of adoption, the statement requires capitalization of costs at the level that existed at the point of incurring the liability. These capitalized costs are depreciated over the same period as the related property asset. Cleco Power also defers the current depreciation of the asset retirement cost as a regulatory asset.

Under the authoritative guidance, the initial ARO liability recorded is accreted to its present value each accounting period. Cleco Power defers this accretion as a regulatory asset based on its determination that these costs can be collected from customers. For additional information on Cleco’s AROs, see Note 3 — “Regulatory Assets and Liabilities — Deferred Asset Removal Costs.”

Property, Plant and Equipment

Property, plant and equipment consist primarily of regulated utility generation and energy transmission assets. Regulated assets, utilized primarily for retail operations and electric transmission and distribution, are stated at the cost of construction, which includes certain materials, labor, payroll taxes and benefits, administrative and general costs, and the estimated cost of funds used during construction. Jointly owned assets are reflected in property, plant and equipment at Cleco Power’s share of the cost to construct or purchase the assets. For information on jointly owned assets, see Note 4 — “Jointly Owned Generation Units.”

Cleco’s cost of improvements to property, plant and equipment is capitalized. Costs associated with repairs and major maintenance projects are expensed as incurred. Cleco capitalizes the cost to purchase or develop software for internal use. The amounts of unamortized computer software costs at December 31, 2009, and 2008 were $3.2 million and $3.8 million, respectively. Amortization of capitalized computer software costs charged to expense for the years ending December 31, 2009, 2008, and 2007 was $1.5 million, $3.0 million, and $3.8 million, respectively.

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CLECO POWER	2009 FORM 10-K

Upon retirement or disposition, the cost of Cleco Power’s depreciable plant and the cost of removal, net of salvage value, are charged to accumulated depreciation. For Cleco’s other depreciable assets, upon disposition or retirement, the difference between the net book value of the property and any proceeds received for the property is recorded as a gain or loss on asset disposition on Cleco’s Consolidated Statements of Income. Any cost incurred to remove the asset is charged to expense. Annual depreciation provisions expressed as a percentage of average depreciable property for Cleco Power were 3.22% for 2009, 3.29% for 2008, and 3.31% for 2007.

Depreciation on property, plant and equipment is calculated primarily on a straight-line basis over the useful lives of the assets, as follows:

	YEARS
Utility plant	5-58
Other	5-44

Property, plant and equipment consist of:

	AT DECEMBER 31,
(THOUSANDS)	2009			2008
Regulated utility plants	$	2,126,646		$	1,998,235
Other		17,845			17,034
Total property, plant and equipment		2,144,491			2,015,269
Accumulated depreciation		(999,204	)		(948,581	)
Net property, plant and equipment	$	1,145,287		$	1,066,688

The table below discloses the amounts of plant acquisition adjustments reported in Cleco Power’s property, plant and equipment and the associated accumulated amortization reported in accumulated depreciation. The plant acquisition adjustment primarily relates to the 1997 acquisition of Teche. The acquisition adjustment represents the amount paid by Cleco Power for the assets of Teche in excess of their carrying value.

	AT DECEMBER 31,
(THOUSANDS)	2009		2008
Plant acquisition adjustment	$	5,359	$	5,359
Less accumulated amortization		3,215		2,960
Net plant acquisition adjustment	$	2,144	$	2,399

Deferred Project Costs

Cleco Power defers costs related to the initial stage of a construction project during which time the feasibility of the construction of property, plant and equipment is being investigated. Cleco Power had spent approximately $0.8 million as of December 31, 2009, and December 31, 2008, respectively, for various resource planning projects. These projects are still in the initial stages of development and as a result are classified as other deferred charges on Cleco Power’s Consolidated Balance Sheets.

Inventories

Fuel inventories consist of coal, lignite, petroleum coke, and oil used to generate electricity.

Materials and supplies inventory consists of transmission and distribution line construction and repair material, and generating station and transmission and distribution substation repair materials.

Both fuel and materials and supplies inventories are stated at average cost and are issued from inventory using the average cost of existing inventory. The amount of storeroom operating expenses allocated to inventory for the years ended December 31, 2009, and 2008 was $2.9 million and $2.6 million, respectively. Deferred storeroom operating expenses remaining in materials and supplies inventory as of December 31, 2009, and 2008 were $3.5 million and $4.4 million, respectively.

Accounts Receivable

Accounts receivable are recorded at the invoiced amount and do not bear interest. It is the policy of management to review the outstanding accounts receivable monthly, as well as the bad debt write-offs experienced in the past, and establish an allowance for doubtful accounts. Account balances are charged off against the allowance when management determines it is probable the receivable will not be recovered. As of December 31, 2009, and 2008, the allowance for doubtful accounts amounted to $1.2 million and $1.6 million, respectively. There is no off-balance sheet credit exposure related to Cleco’s customers.

Reserves

Cleco maintains property insurance on generating stations, buildings and contents, and substations. Cleco is self-insured for any damage to transmission and distribution lines. To mitigate the exposure to potential financial loss for damage to lines, Cleco maintains an LPSC-approved reserve, supported by monthly charges to operating expense.

The following table represents Cleco and Cleco Power’s restricted and unrestricted storm reserves.

Cleco

(THOUSANDS)	BALANCE AT BEGINNING OF PERIOD		ADDITIONS		DEDUCTIONS		BALANCE AT END OF PERIOD
Unrestricted Storm Reserve
Years ended December 31,
2009	$	210	$	3,643	$	2,707	$	1,146
2008	$	6,789	$	26,021	$	32,600	$	210
2007	$	2,770	$	7,440	$	3,421	$	6,789

Restricted Storm Reserve (1)
Years ended December 31,
2009	$	27,411	$	825	$	2,801	$	25,435
2008	$	-	$	52,188	$	24,777	$	27,411
(1) None for 2007

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

Cleco Power

(THOUSANDS)	BALANCE AT BEGINNING OF PERIOD		ADDITIONS		DEDUCTIONS		BALANCE AT END OF PERIOD
Unrestricted Storm Reserve
Years ended December 31,
2009	$	210	$	3,643	$	2,707	$	1,146
2008	$	6,789	$	26,021	$	32,600	$	210
2007	$	2,770	$	7,440	$	3,421	$	6,789

Restricted Storm Reserve (1)
Years ended December 31,
2009	$	27,411	$	825	$	2,801	$	25,435
2008	$	-	$	52,188	$	24,777	$	27,411
(1) None for 2007

Cleco also maintains liability and workers’ compensation insurance to mitigate financial losses due to injuries and damages to the property of others. The general liability and workers compensation reserves are immaterial because the balance of these items as of December 31, 2009 together represent 0.2% of total liabilities. Cleco’s insurance covers claims that exceed certain self-insured limits. For claims that do not meet the limits to be covered by insurance, Cleco maintains reserves.

Cash Equivalents

Cleco considers highly liquid, marketable securities, and other similar instruments with original maturity dates of three months or less at the time of purchase to be cash equivalents.

Restricted Cash

Various agreements to which Cleco is subject contain covenants that restrict its use of cash. As certain provisions under these agreements are met, cash is transferred out of related escrow accounts and becomes available for general corporate purposes. At December 31, 2009, and 2008, $56.4 million and $103.0 million of cash, respectively, were restricted. At December 31, 2009, restricted cash consisted of $0.1 million under the Diversified Lands mitigation escrow agreement, $22.2 million reserved at Cleco Power for GO Zone project costs, $25.4 million reserved at Cleco Power for future storm restoration costs, and $8.7 million at Cleco Katrina/Rita restricted for payment of operating expenses, interest, and principal on storm recovery bonds. Restricted cash for Cleco Power at December 31, 2009, decreased $46.5 million compared to December 31, 2008, primarily due to the use of $22.4 million of funds for GO Zone project costs, the release of $14.7 million for the construction of Cleco Power’s solid waste disposal facilities at Rodemacher Unit 3, a $7.5 million net decrease in Cleco Katrina/Rita restricted cash primarily due to the payment of operating expenses, interest, and principal on storm recovery bonds, partially offset by collections, and Cleco Power’s net use of $1.9 million for approved storm damage costs.

Equity Investments

Cleco reports its investment in unconsolidated affiliated companies on the equity method of accounting, as defined in the authoritative guidance on investments. The amounts reported on Cleco’s balance sheet represent assets contributed by Cleco plus Cleco’s share of the net income of the affiliate, less any distributions of earnings (dividends) received from the affiliate. For additional information, see Note 13 — “Equity Investment in Investees.”

Cleco applies the provisions of the authoritative guidance on investments to account for equity method investment impairments. Under this standard, Cleco evaluates at each balance sheet date whether events and circumstances have occurred that indicate a possible other-than-temporary decline in the fair value of the investment and the possible inability to recover the carrying value through operations. Cleco uses estimates of the future cash flows from the investee and observable market transactions in order to calculate fair value and recoverability. An impairment is recognized when an other-than-temporary decline in market value occurs and recovery of the carrying value is not probable. During 2007, Cleco recorded a pre-tax impairment loss of $45.8 million ($28.2 million after tax) on its indirect investment in Acadia. The impairment was recorded on the income from equity investees line item on the income statement. No impairments were recorded for 2009 or 2008. For more information, see Note 13 — “Equity Investment in Investees.”

Effective January 1, 2010, the requirements for consolidation changed. On and after January 1, 2010, the assets, liabilities, revenues, expenses, and cash flows for Evangeline, Attala, and Perryville will be presented in the appropriate line items of the consolidated financial statements. For additional information, see “— Recent Authoritative Guidance” below.

Income Taxes

Cleco accounts for income taxes under the appropriate authoritative guidance. Cleco’s income tax expense and related regulatory assets and liabilities could be affected by changes in its assumptions and estimates and by ultimate resolution of assumptions and estimates with taxing authorities. Cleco files a federal consolidated income tax return for all wholly owned subsidiaries. The LPSC generally requires Cleco Power to flow the state tax benefit of deductions immediately to customers. The LPSC specifically requires that the state tax benefits associated with the deductions related to storm damages be normalized. For additional information on income taxes, see Note 10 — “Income Taxes.”

Investment Tax Credits

Investment tax credits, which were deferred for financial statement purposes, are amortized to income over the estimated service lives of the properties that gave rise to the credits.

Debt Expenses, Premiums, and Discounts

Expenses, premiums, and discounts applicable to debt securities are amortized to income ratably over the lives of the related issues. Expenses and call premiums related to refinanced Cleco Power debt are deferred and amortized over the life of the new issue.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

Revenue and Fuel Costs

Utility Revenue. Revenue from sales of electricity is recognized based upon the amount of energy delivered. The costs of fuel and purchased power used for retail customers currently are recovered from customers through the fuel adjustment clause, based upon fuel costs and amounts of purchased power incurred in prior months. These adjustments are subject to audit and final determination by regulators. Excise taxes and pass-through fees collected on the sale of electricity are not recorded in utility revenue.

Unbilled Revenue. Cleco Power accrues estimated revenue monthly for energy delivered since the latest billings. The monthly estimated unbilled revenue amounts are recorded as revenue and a receivable and are reversed the following month.

Other Revenue. Other revenue is recognized at the time products or services are provided to and accepted by customers. Economic hedges are derivatives and do not meet the criteria to be considered accounting hedges. These transactions are marked-to-market with the resulting gain or loss recorded as a component of other revenue. For additional information on mark-to-market accounting, see “— Risk Management” below.

Equity Income. The results of equity investees are not consolidated with the results of Cleco, but instead are reported as equity investments. Their revenues and expenses are netted and reported on one line item as equity income from investees on Cleco Corporation’s Consolidated Statements of Income. For more information, see Note 13 — “Equity Investment in Investees.”

Cleco Power directly owns 50% of Oxbow. Oxbow’s revenues are primarily derived from royalties associated with lignite mined to supply the Dolet Hill Power Station. Oxbow recognizes revenue when its lignite is mined.

Midstream directly owns all of the equity interest in Evangeline and at December 31, 2009, indirectly owned 50% of Acadia. Evangeline’s revenues are derived from its tolling agreement, which is considered to be an operating lease pursuant to the authoritative guidance for leases. Several revenue provisions within the tolling agreement contain annual fixed escalations, which are required to be recognized straight-line over the life of the tolling agreement instead of when due to be paid by the tolling agreement counterparty. Other provisions, such as penalties and bonuses, are considered to be contingent rents and are recognized when the contingencies are fulfilled. A significant portion of Evangeline’s revenue is derived from its capacity payment, which it receives when the plant is available to produce electricity. Evangeline also recognizes variable revenue from the tolling agreement which depends on the way the plant is dispatched and how much electricity is produced. In June 2009, FASB amended the authoritative guidance on consolidation. For additional information, see “— Recent Authoritative Guidance.”

Acadia’s revenues are primarily derived from the interaction of the natural gas market as compared to the electricity market. Acadia recognizes revenue when it produces and sells electricity into the wholesale market, which generally occurs when market value of electricity is above the cost to produce electricity and transmission services are available.

Cleco Corporation owns 100% of Perryville and Attala. Both companies provide transmission to a single customer. The transmission tariffs charged by both companies are regulated by FERC.

Franchise Fees. Cleco Power collects a consumer fee for one of its franchise agreements. This fee is not recorded on Cleco’s income statement as revenue and expense, but is reflected at gross amounts on Cleco’s balance sheet as a receivable until it is collected and as a payable until the liability is paid. Cleco currently does not have any excise taxes reflected on its income statement.

AFUDC

The capitalization of AFUDC by Cleco Power is a utility accounting practice prescribed by FERC and the LPSC. AFUDC represents the estimated cost of financing construction and is not a current source of cash. Under regulatory practices, a return on and recovery of AFUDC is permitted in setting rates charged for utility services. The composite AFUDC rate, including borrowed and other funds, was 12.3% on a pre-tax basis (7.6% net of tax) for 2009, 12.8% on a pretax basis (7.9% net of tax) for 2008, and 12.2% on a pre-tax basis (7.5% net of tax) for 2007.

Capitalized Interest

Cleco and its subsidiaries, except Cleco Power (see AFUDC above), capitalize interest costs related to longer-term construction projects. Other than AFUDC at Cleco Power, no interest was capitalized in 2009, 2008, or 2007.

Fair Value Measurements and Disclosures

Various accounting pronouncements require certain assets and liabilities to be measured at their fair values. Some assets and liabilities are required to be measured at their fair value each reporting period, while others are required to be measured only one time, generally the date of acquisition or debt issuance. Cleco and Cleco Power are required to disclose the fair value of certain assets and liabilities by one of three levels when required for recognition purposes under GAAP. Other financial assets and liabilities, such as long-term debt, are reported at their carrying values at their date of issuance on the condensed consolidated balance sheets with their fair values disclosed without regard to the three levels. For more information about fair value levels, see Note 5 — “Fair Value Accounting.”

Risk Management

Market risk inherent in Cleco Power’s market risk-sensitive instruments and positions includes potential changes arising from changes in interest rates and the commodity market

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

prices of power and natural gas on different energy exchanges. Cleco’s Energy Market Risk Management Policy authorizes the use of various derivative instruments, including exchange traded futures and option contracts, forward purchase and sales contracts, and swap transactions to reduce exposure to fluctuations in the price of power and natural gas. Cleco uses the authoritative guidance as it relates to derivatives and hedging to determine whether the market risk-sensitive instruments and positions are required to be marked-to-market. Generally, Cleco Power’s market risk-sensitive instruments and positions qualify for the normal-purchase, normal-sale exception to mark-to-market accounting because Cleco Power takes physical delivery and the instruments and positions are used to satisfy customer requirements. Cleco Power has entered into certain financial transactions it considers economic hedges to mitigate the risk associated with the fixed-price power to be provided to a wholesale customer through December 2010. The economic hedges cover approximately 98% of the estimated daily peak hour power sales to the wholesale customer. These transactions are marked-to-market with the resulting gain or loss recorded on the income statement as a component of operating revenue. For the year ended December 31, 2009, and 2008, the following gains and losses related to these economic hedge transactions were recorded in other operations revenue.

	FOR THE YEAR ENDED DECEMBER 31,
(THOUSANDS)	2009			2008
Realized (loss) gain	$	(1,638	)	$	873
Mark-to-market loss		(167	)		(2,213	)
Total loss	$	(1,805	)	$	(1,340	)

Cleco Power has entered into other positions to mitigate the volatility in customer fuel costs. These positions are marked-to-market with the resulting gain or loss recorded on the balance sheet as a component of the accumulated deferred fuel asset or liability and a component of risk management assets or liabilities. When these positions close, actual gains or losses will be included in the fuel adjustment clause and reflected on customers’ bills as a component of the fuel cost adjustment. Based on market prices at December 31, 2009, and 2008, the net mark-to-market impact relating to these positions were losses of $24.9 million and $57.4 million, respectively. The decreased loss is primarily due to the closing of certain natural gas positions. Deferred losses relating to closed natural gas positions totaled $2.6 million and $6.4 million at December 31, 2009, and 2008, respectively.

Cleco Power maintains margin accounts with commodity brokers used to partially fund the acquisition of natural gas futures, options and swap contracts. These contracts/positions are used to mitigate the risks associated with the fixed-price power sales and volatility in customer fuel costs noted above. At December 31, 2009, and 2008, Cleco Power had deposited net collateral of $10.0 million and $16.5 million, respectively, to cover margin requirements relating to open natural gas futures, options and swap positions.

Cleco and Cleco Power maintain a master netting agreement policy and monitor credit risk exposure through review of counterparty credit quality, counterparty credit exposure, and counterparty concentration levels. Cleco manages these risks by establishing appropriate credit and concentration limits on transactions with counterparties and by requiring contractual guarantees, cash deposits, or letters of credit from counterparties or their affiliates, as deemed necessary. Cleco Power has agreements in place with various counterparties that authorize the netting of financial buys and sells and contract payments to mitigate credit risk for transactions entered into for risk management purposes.

In August 2009, Cleco Power entered into a $50.0 million bank loan with variable interest, paid monthly, calculated at 3.00% plus the one-month LIBOR. The loan matures on August 19, 2012. In order to mitigate risk of the future floating interest rates, Cleco Power entered into an interest rate swap in the third quarter of 2009. Based on the notional amount of the bank loan, the swap requires a monthly net settlement between Cleco Power’s fixed payment of 1.84% and the swap counterparty’s floating payment of the one-month LIBOR. The swap matures on May 31, 2012. Under the authoritative guidance for derivatives and hedging, the swap meets the criteria of a cash flow hedge. Changes in the swap’s fair value related to the effective portion of cash flow hedges are recognized in other comprehensive income, whereas changes in the fair value related to the ineffective portion are recognized in earnings. As time passes and settlements are made, the swap’s other comprehensive income fair values are reclassified into earnings as a component of interest expense. For the year ended December 31, 2009, there were $0.3 million of reclassification adjustments from other comprehensive income to interest expense. There was no impact to earnings due to ineffectiveness for the year ended December 31, 2009. For more information on accounting for derivatives, see Note 5 — “Fair Value Accounting.”

Recent Authoritative Guidance

The Registrants adopted, or will adopt, the recent authoritative guidance listed below on their respective effective dates.

In April 2008, FASB amended the factors that should be considered in developing renewal or extension assumptions used to determine the useful life of a recognized intangible asset. This amendment allows an entity to use its own experience in renewing arrangements or to use market assumptions about renewal in determining the useful life of a recognized intangible asset. This amendment also requires additional disclosure about the renewal costs. This amendment is effective for financial statements issued for fiscal years and interim periods beginning after December 15, 2008. The adoption of this amendment did not have an impact on the financial condition or results of operations of the Registrants.

In June 2008, FASB amended the authoritative guidance on earnings per share to determine whether non-vested instruments issued in stock-based payment transactions are participating securities when calculating earnings per share. This amendment states that non-vested stock-based instruments that contain nonforfeitable rights to dividends or dividend equivalents are participating securities and are required

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

to be included in the computation of earnings per share pursuant to the two-class method. This amendment is effective for fiscal years and interim periods beginning after December 15, 2008. Earnings per share for prior periods presented are required to be adjusted retrospectively to conform to this amendment. The implementation of this amendment did not have an impact on the financial condition or results of operations of the Registrants.

In September 2008, FASB amended the authoritative guidance on fair value measurements and disclosures for accounting and disclosure at fair value for liabilities that contain inseparable third-party credit enhancements. This amendment requires issuers of liabilities to exclude the third-party credit enhancement when calculating the fair value of the liability for both recognition and disclosure purposes. Also, proceeds received by the issuer for liabilities within the scope of this amendment represent consideration for both the liability and the credit enhancement and shall be allocated to both the liability and the premium for the credit enhancement. The provisions of this amendment are effective on a prospective basis in the first reporting period beginning on or after December 15, 2008. The implementation of this amendment did not have an impact on the financial condition or results of operations of the Registrants.

In December 2008, FASB amended the authoritative guidance for compensation as it relates to retirement benefits and an employer’s disclosures about plan assets of a defined benefit pension or other postretirement plan. This amendment also includes a technical change that requires a nonpublic entity to disclose net periodic benefit costs for each annual period for which a statement of income is presented. This amendment is effective for the first fiscal year ending after December 15, 2009. Since the adoption of this amendment is a change in disclosure, the adoption will not have any effect on the financial condition or results of operations of the Registrants.

In February 2009, the SEC issued its final rules requiring public companies to provide the SEC with supplemental financial information in interactive data format using eXtensible Business Reporting Language or XBRL. The information will be provided as an exhibit to the related SEC filing. The Registrants are required to include certain financial information in XBRL format in certain SEC filings beginning with the interim fiscal period ending June 30, 2010.

In April 2009, FASB amended the authoritative guidance on business combinations to address application issues raised by preparers, auditors, and members of the legal profession on initial recognition and measurement, subsequent measurement and accounting, and disclosure of assets and liabilities arising from contingencies in a business combination. This amendment applies to all assets acquired and liabilities assumed in a business combination that arise from contingencies that would be within the scope of the contingencies accounting standard if the contingency is not acquired or assumed in a business combination, except for assets and liabilities arising from contingencies that are subject to specific guidance in the business combinations accounting standard. An acquirer is required to develop a systematic and rational basis for subsequently measuring and accounting for assets and liabilities arising from contingencies depending on their nature. An acquirer is required to disclose information that enables users of its financial statements to evaluate the nature and financial effects of a business combination that occurs either during the current reporting period or after the reporting period but before the financial statements are issued. This amendment was effective for assets and liabilities arising from contingencies in business combinations for which the acquisition date is on or after the beginning of the first annual reporting period beginning on or after December 15, 2008. The adoption of this amendment had no impact on the financial condition or results of operations of the Registrants.

In April 2009, FASB amended the other-than-temporary impairment guidance in GAAP for debt securities to make the guidance more operational and to improve the presentation and disclosure of other-than-temporary impairments on debt and equity securities in the financial statements. If the fair value of a debt security is less than its amortized value, this amendment requires companies to assess whether the impairment is recognized depending on a combination of its intent to sell the security and its ability to hold the security until recovery of its amortized cost basis. If an entity intends to sell the debt security or it is more likely than not the entity will be required to sell the security, an other-than-temporary impairment is considered to have occurred and an impairment expense equal to the difference between fair market value and amortized costs should be recognized. If an entity does not intend to sell the security and it is not more likely than not the entity will be required to sell the security, then the entity will only recognize the credit loss as an expense. The amount of loss relating to other factors will be recognized as a reduction in other comprehensive income. This amendment also includes guidance on calculating credit loss and additional disclosures. This amendment is effective for interim and annual reporting periods ending after June 15, 2009. The implementation of this amendment did not have an impact on the financial condition or results of operations of the Registrants.

In April 2009, FASB amended the accounting standard to provide additional guidance for estimating fair value when the volume and level of activity for the asset or liability have significantly decreased. This amendment also includes guidance on identifying circumstances that indicate a transaction is not orderly. This amendment applies to all assets and liabilities within the scope of the fair value accounting standard. When weighing indications of fair value resulting from the use of multiple valuation techniques, a reporting entity shall consider the reasonableness of the range of fair value estimates. The objective is to determine the point within that range that is most representative of fair value under current market conditions. A reporting entity shall evaluate the circumstances to determine whether the transaction is orderly based on the weight of the evidence. In its determinations, a reporting entity need not undertake all possible efforts, but shall not ignore information that is available without undue cost and effort. A

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

reporting entity would be expected to have sufficient information to conclude whether a transaction is orderly when it is party to the transaction. This amendment is effective for interim and annual reporting periods ending after June 15, 2009, and shall be applied prospectively. This amendment does not require disclosures for earlier periods presented for comparative purposes at initial adoption. In periods after initial adoption, this amendment requires comparative disclosures only for periods ending after initial adoption. The implementation of this amendment did not have an impact on the financial condition or results of operations of the Registrants.

In April 2009, FASB amended the accounting standards which require disclosures about fair value of financial instruments for interim reporting periods of publicly traded companies. These amendments apply to all financial instruments within the scope of the authoritative guidance for financial instruments, financial services, and receivables held by publicly traded companies. A publicly traded company is required to include disclosures about the fair value of its financial instruments whenever it issues summarized financial information for interim reporting periods. These amendments are effective for interim reporting periods ending after June 15, 2009 with early adoption permitted for periods ending after March 15, 2009. These amendments do not require disclosures for earlier periods presented for comparative purposes at initial adoption. In periods after initial adoption, these amendments require comparative disclosures only for periods ending after initial adoption. Since the adoption of these amendments is only a change in disclosure, adoption did not have any effect on the financial condition or results of operations of the Registrants.

In June 2009, FASB amended the authoritative guidance on accounting for events occurring subsequent to the balance sheet date, but before the issuance of financial statements. Certain subsequent events would require an entity to make adjustments to the financial statements and disclosure, whereas other events would only require disclosure. Additionally, all entities are required to disclose the date through which they have evaluated subsequent events and whether the date corresponds with the release of their financial statements. This amendment is effective for financial statements issued for fiscal years and interim periods beginning after June 15, 2009. Implementation of this amendment did not have an impact on the financial condition or results of operations of the Registrants.

In June 2009, FASB amended the authoritative guidance on transfer and servicing to improve the relevance, representational faithfulness, and comparability of the information that a reporting entity provides in its financial statements about a transfer of financial assets; the effects of a transfer on its financial position, financial performance, and cash flows; and a transferor’s continuing involvement, if any, in transferred financial assets. This amendment is effective for fiscal years beginning after November 15, 2009. Implementation of this amendment did not have an impact on the financial condition or results of operations of the Registrants.

In June 2009, FASB amended the authoritative guidance on consolidation which requires an enterprise to perform an analysis to determine whether the enterprise’s variable interest or interests give it a controlling financial interest in a variable interest entity. In order to be the primary beneficiary of a variable interest entity, an enterprise must have (a) the power to direct the activities of a variable interest entity that most significantly impact the entity’s economic performance, and (b) the obligation to absorb losses of the entity that could potentially be significant to the variable interest entity or the right to receive benefits from the entity that could potentially be significant to the variable interest entity. Along with these criteria, an enterprise is now required to assess whether it has an implicit financial responsibility to ensure that a variable interest entity operates as designed when determining (a) above. Also, the enterprise is required to perform ongoing reassessments of whether an enterprise is the primary beneficiary of a variable interest entity. The quantitative approach previously required for determining the primary beneficiary has been eliminated. Additional disclosures are now required in order to provide users of financial statements with more transparent information about an enterprise’s involvement in a variable interest entity. This amendment is effective for the first fiscal year beginning after November 15, 2009. The implementation of this amendment on January 1, 2010 required Cleco Corporation to consolidate three wholly owned subsidiaries that had been accounted for using the equity method. Prior to January 1, 2010, Perryville, Attala, and Evangeline are presented in the consolidated financial statements as follows:

§	All entities’ results of operations before taxes as one line item on the consolidated statements of income entitled Equity (loss) income from investees,

§	All entities’ assets and liabilities on the consolidated balance sheets as one line item entitled Equity investment in investees, and

§	All entities’ cash flows in the consolidated statement of cash flows as return on equity investment in investee, return of equity investment in investee and equity investment investee.

On and after January 1, 2010, the entities’ assets, liabilities, revenues, expenses and cash flows will be presented on the appropriate line items of the consolidated financial statements. Cleco has chosen to implement the consolidation prospectively and not retrospectively, therefore the consolidation will not be carried back to comparative prior periods in financial statements issued after implementation. For additional information on Perryville, Attala and Evangeline, see Note 13 — “Equity Investment in Investees.”

In June 2009, FASB amended the authoritative guidance which identified the sources of accounting principles and the framework for selecting them. The Accounting Codification has become the source of authoritative GAAP recognized by FASB to be applied by nongovernmental entities. This amendment was effective for financial statements issued for interim and annual periods ending after September 15, 2009.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

In August 2009, FASB amended the authoritative guidance on fair value measurements and disclosures in order to clarify the fair value of a liability. The best measurement of a liability would be a quoted price in an active market of the liability or an identical liability. If the quoted price of the liability is not available, then an entity could use a quoted price of the liability quoted as an asset, quoted prices of similar liabilities traded as assets, or a valuation technique consistent with the principles contained in the Fair Value Measurements and Disclosures Topic, such as present value. If an asset quote is used, the fair market value should be adjusted for factors specific to an asset that is not applicable to a liability. Regardless of the method used to determine fair value, restrictions on transfer of the liability should not be factored into the valuation of the liability. This amendment is effective for the first reporting period beginning after October 1, 2009. The implementation of this amendment did not have an impact on the financial condition or results of operations of the Registrants.

In September 2009, FASB issued various technical corrections to the Accounting Codification that did not have a material effect on the financial condition or results of operations of the Registrants.

In September 2009, FASB amended the authoritative guidance regarding revenue recognition of arrangements with multiple deliverables. If an arrangement contains multiple deliverables, the selling entity must first determine the best estimate of the selling price of each deliverable. Then the selling entity must allocate the selling price of the entire arrangement based upon the relative best estimate of the selling price of each deliverable. This amendment also contains additional disclosures such as the nature of the arrangement, significant deliverables and general timing. This amendment is effective for arrangements entered into or materially modified in fiscal years beginning on or after June 15, 2010. Management is currently evaluating the impact this amendment will have on the financial condition or results of operations of the Registrants.

In September 2009, FASB amended fair value measurements by providing additional guidance related to measuring the fair value of certain alternative investments, such as interests in hedge funds, private equity funds, real estate funds, venture capital funds, offshore fund vehicles, and fund-of-funds. If certain conditions are met, this amendment allows reporting entities to use net asset value per share to estimate the fair value of these investments as a practical expedient. The amendment also requires disclosures by major category of investment about the attributes of the investments, such as the nature of any restrictions on the investor’s ability to redeem its investments at the measurement date, any unfunded commitments, and the investment strategies of the investees. This amendment is effective for interim and annual periods ending after December 15, 2009, with early application permitted. Implementation of this amendment did not have an impact on the financial condition or results of operations of the Registrants.

Earnings per Average Common Share

The following table shows the calculation of basic and diluted earnings per share.

													FOR THE YEAR ENDED DECEMBER 31,
					2009						2008						2007
(THOUSANDS, EXCEPT SHARES AND PER SHARE AMOUNTS)	INCOME		SHARES		PER SHARE AMOUNT		INCOME		SHARES		PER SHARE AMOUNT		INCOME		SHARES		PER SHARE AMOUNT
Income from continuing operations	$	106,307					$	102,141					$	151,789
Deduct: non-participating stock dividends (4.5% preferred stock)		46						46						46
Deduct: participating preferred stock dividends		-						-						412
Deduct: amount allocated to participating preferred		-						-						698
Basic net income applicable to common stock	$	106,261		60,187,894	$	1.77	$	102,095		59,990,229	$	1.70	$	150,633		58,976,052	$	2.55
Effect of dilutive securities
Add: stock option grants		-		32,050				-		59,429				-		120,503
Add: restricted stock (LTICP)		-		278,261				-		164,982				27		198,646
Add: convertible ESOP preferred stock		-		-				-		-				1,110		422,327
Diluted net income applicable to common stock	$	106,261		60,498,205	$	1.76	$	102,095		60,214,640	$	1.70	$	151,770		59,717,528	$	2.54

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

Stock option grants excluded from the computation of 2009 diluted earnings per share are presented in the table below. These stock option grants were excluded from the computation of 2009 diluted earnings per share because they had exercise prices higher than the average market price. There were no stock option grants excluded from the computation of 2008 or 2007 diluted earnings per share.

	FOR THE YEAR ENDED DECEMBER 31, 2009
	STRIKE PRICE		AVERAGE MARKET PRICE		SHARES
Stock option grants excluded	$	23.31- $ 24.25	$	23.28		57,766

Stock-Based Compensation

For information on Cleco’s stock-based compensation, see Note 7 — “Common Stock — Stock-Based Compensation.”

Note 3 — Regulatory Assets and Liabilities

Cleco Power follows the authoritative guidance of regulated operations, which allows utilities to capitalize or defer certain costs based on regulatory approval and management’s ongoing assessment that it is probable these items will be recovered through the ratemaking process.

Pursuant to the authoritative guidance on regulated industry operations, Cleco Power has recorded regulatory assets and liabilities primarily for the effects of income taxes. In addition, Cleco Power has recorded regulatory assets for deferred mining costs, interest costs, estimated future asset removal costs, postretirement plan costs, tree trimming costs, training costs, storm surcredit, fuel and energy purchases, and related hedging gains and losses, and has recorded regulatory liabilities for fuel transportation revenue and recovered construction carrying costs, as a result of rate actions of regulators.

The deferred mining costs, deferred interest costs, deferred postretirement plan costs, deferred asset removal costs, deferred tree trimming costs, deferred training costs, deferred storm surcredit, lignite mining agreement contingency, and a portion of the deferred construction carrying costs are presented in the line items entitled “Regulatory Assets — Other,” the deferred fuel and purchased power costs and related hedging gains and losses are presented on the line item entitled “Accumulated Deferred Fuel,” the deferred fuel transportation revenue and the remaining deferred construction carrying costs are presented on the line items entitled “Regulatory Liabilities — Other,” on Cleco Corporation’s Consolidated and Cleco Power’s Consolidated Balance Sheets. Under the current regulatory environment, Cleco Power believes these regulatory assets will be fully recoverable; however, if in the future, as a result of regulatory changes or competition, Cleco Power’s ability to recover these regulatory assets would no longer be probable, then to the extent that such regulatory assets were determined not to be recoverable, Cleco Power would be required to write-down such assets. In addition, potential deregulation of the industry or possible future changes in the method of rate regulation of Cleco Power could require discontinuance of the application of these authoritative guidelines. Cleco Power does not earn a return on these regulatory assets through current rates, but is collecting carrying costs on the outstanding deferred costs relating to deferred mining costs and deferred fuel and purchased power.

The following chart summarizes Cleco Power’s regulatory assets and liabilities at December 31, 2009, and 2008.

	AT DECEMBER 31,						REMAINING
(THOUSANDS)	2009			2008			RECOVERY PERIOD
Total federal regulatory asset — income taxes	$	53,902		$	35,447
Total state regulatory asset — income taxes		13,267			16,335
AFUDC		130,338			85,331
AFUDC equity gross up		72,499			44,111
Total investment tax credit		(5,663	)		(6,420	)
Total regulatory assets and liabilities — deferred taxes, net		264,343			174,804
Deferred mining costs		24,215			26,811		9.5 yrs.
Deferred interest costs		7,401			7,779		30 yrs.
Deferred asset removal costs		712			658		40 yrs.
Deferred postretirement plan costs		106,735			112,213			-
Deferred tree trimming costs		13,485			5,915		5 yrs.
Deferred training costs		7,045			2,520		50 yrs.
Deferred storm surcredits, net		7,747			4,863		13 yrs.
Deferred construction carrying costs		40,174			-		5 yrs.
Lignite mining agreement contingency		3,781			-			-
Total regulatory assets - other		211,295			160,759
Deferred fuel transportation revenue		-			(392	)
Deferred construction carrying costs		(183,230	)		(85,496	)	5 yrs.
Deferred fuel and purchased power		35,059			69,154
Total regulatory assets and liabilities, net	$	327,467		$	318,829

Deferred Taxes

Cleco Power has recorded a net regulatory asset related to deferred income taxes in accordance with the authoritative guidance on income taxes. The related regulatory asset or liability recorded represents the effect of tax benefits or detriments that must be flowed through to customers as they are received or paid. Generally, the recovery periods for regulatory assets and liabilities are based on assets’ lives, which are typically 30 years or greater. The amounts deferred are attributable to differences between book and tax recovery periods. At December 31, 2009, and 2008, Cleco Power had regulatory assets and liabilities – deferred taxes, net of $264.3 million and $174.8 million, respectively. The $89.5 million increase from December 31, 2008, was primarily the result of the collection and deferral of carrying costs for Cleco Power’s construction of Rodemacher Unit 3.

Deferred Mining Costs

Cleco Power operates a generating unit jointly owned with SWEPCO that uses lignite as its fuel source.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

were deferred, and could be recovered from retail customers through the fuel adjustment clause only when the actual mining costs are below 98% of the benchmark price. The benchmark price used the GDP-IPD index as a proxy for the numerous escalators in the previous mining contract. During the course of the contract, Cleco Power and SWEPCO determined that the GDP-IPD index did not appropriately reflect the increase in mining costs caused by sharp increases in diesel fuel and electricity costs associated with the mining operation. Because of this disconnect between the GDP-IPD index and actual mining costs, a significant amount of mining costs was being deferred by Cleco Power. At December 31, 2009, and 2008, Cleco Power had $24.2 million and $26.8 million, respectively, in deferred costs remaining uncollected.

In 2006, Cleco Power recognized that there was a possibility it may not recover all or part of the lignite mining costs it had deferred. In November 2006, Cleco Power and SWEPCO submitted a joint application to the LPSC requesting approval for Cleco Power to recover its existing deferral balance, and eliminate any future benchmarking of lignite mining costs. In December 2007, the LPSC approved a settlement agreement between Cleco Power, SWEPCO and the LPSC Staff authorizing Cleco Power to recover the existing deferred mining cost balance, including interest, over approximately 11.5 years. The settlement also established a new benchmark utilizing the contract’s escalators to assure a minimum 2% savings to customers compared to the costs under the prior mining contract. Under the settlement, the benchmarking was scheduled to end after April 2011. Cleco Power and SWEPCO also agreed to commit to continued operation of the mining operation through 2016 as long as the operation of the mine was considered prudent. Cleco Power did not record any additional deferred fuel costs under the new benchmarking method.

On September 30, 2009, in connection with its approval of the Oxbow Lignite Mine acquisition, the LPSC agreed to discontinue benchmarking and the corresponding potential to defer future lignite mining costs while preserving the recovery of the legacy deferred fuel balance previously authorized.

Deferred Interest Costs

Cleco Power’s deferred interest costs include additional deferred capital construction financing costs authorized by the LPSC. At December 31, 2009, and 2008, these costs totaled $7.4 million and $7.8 million, respectively, and are being amortized over the estimated lives of the respective assets constructed.

Deferred Asset Removal Costs

Under the authoritative guidance for asset retirement and environmental obligations, Cleco Power determined that a liability exists for cleanup and closing costs of solid waste facilities associated with its generating stations that use lignite and coal for fuel. Applying these guidelines, Cleco Power determined that a liability exists for costs which may be incurred in the future for removal of asbestos from its general service buildings, the removal of transmission towers on leased rights-of-way and for the abatement of PCBs in transformers.

At December 31, 2009, and 2008, the liability for solid waste facility closure costs at the generating station using lignite is estimated at $0.4 million and is included in other deferred credits. At December 31, 2009, and 2008, Cleco Power’s liability for removal of asbestos is estimated at $0.3 million and also is included in other deferred credits.

Deferred Postretirement Costs

Authoritative guidance on retirement benefits compensation requires companies to recognize the funded status of their postretirement benefit plans as a net liability or asset. The net liability or asset is defined as the difference between the benefit obligation and the fair market value of plan assets. For defined benefit pension plans, the benefit obligation is the projected benefit obligation. Historically, the LPSC has allowed Cleco Power to recover pension plan expense. Cleco Power, therefore, recognizes a regulatory asset based on its determination that these costs can be collected from customers. The amount and timing of the recovery will be based on the changing funded status of the pension plan in future periods. At December 31, 2009, and 2008, Cleco Power had postretirement plan costs deferred as a regulatory asset of $106.7 million and $112.2 million, respectively. For additional information on Cleco’s pension plan and adoption of these authoritative guidelines, see Note 9 — “Pension Plan and Employee Benefits.”

Deferred Tree Trimming Costs

In January 2008, the LPSC approved Cleco Power’s request to establish a regulatory asset for costs incurred to trim, cut, or remove trees that were damaged by Hurricanes Katrina and Rita, but were not addressed as part of the restoration efforts. The regulatory asset is capped at $12.0 million in actual expenditures plus a 12.4% grossed-up rate of return. Recovery of these expenditures was requested in Cleco Power’s base rate application filed in July 2008, and was approved by the LPSC in October 2009. At December 31, 2009, the regulatory asset consisted of $12.0 million of actual expenditures and $1.5 million related to the grossed-up rate of return. On February 12, 2010, Rodemacher Unit 3 commenced commercial operations and Cleco Power began amortizing the regulatory asset over a five-year period.

Deferred Training Costs

In February 2008, the LPSC approved Cleco Power’s request to establish a regulatory asset which is being charged with training costs associated with existing processes and technology for new employees at Rodemacher Unit 3. Recovery of these expenditures was requested in Cleco Power’s base rate application filed in July 2008, and were covered by the retail rate plan which was approved by the LPSC in October 2009. At December 31, 2009, and 2008, Cleco Power had deferred $7.0 million and $2.5 million, respectively, of Rodemacher Unit 3 training costs. On February 12, 2010, Rodemacher Unit 3 commenced commercial operations and Cleco Power began amortizing the regulatory asset over a 50-year period.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

Deferred Storm Surcredit, Net

Cleco Power has recorded a storm surcredit as the result of a settlement with the LPSC that addressed, among other things, the recovery of the storm damages related to Hurricanes Katrina and Rita. In the settlement, Cleco Power was required to implement a surcredit to provide ratepayers with the economic benefit of the carrying charges of all accumulated deferred income tax liabilities due to the storm damage costs at a 12.2% rate of return which was set in LPSC Order No. U-29157A. The accumulated deferred income tax liability includes the tax benefit on deductions for operation and maintenance expenses, casualty loss, and depreciation against taxable income in the year incurred and all subsequent periods. The settlement, through a true-up mechanism, allows the surcredit to be adjusted to reflect the actual tax deductions allowed by the IRS.

Cleco Power also was allowed to record a corresponding regulatory asset in an amount representing the flow back of the carrying charges to ratepayers. This amount is being amortized over the life of the storm recovery bonds. The corresponding regulatory asset will be adjusted through the same surcredit true-up mechanism at the time of a final determination of the tax benefit for storm damage costs by the IRS.

As a result of the settlement with the LPSC, Cleco Power was required to implement a surcredit when funds were withdrawn from the restricted storm reserve. In July and September 2009 and in October 2008, Cleco Power withdrew funds from the restricted storm reserve to pay for storm damages resulting in the establishment of a surcredit. Cleco Power requested and received approval from the LPSC to replenish the restricted storm reserve with the surcredit associated with the storms. At December 31, 2009, and 2008, Cleco Power had $7.7 million and $4.9 million, respectively, in deferred storm surcredit, net.

Deferred Fuel Transportation Revenue

In June 2003, pipeline assets owned by a Cleco Power affiliate, providing transportation of fuel to two Cleco Power generating stations, were sold to Cleco Power. Prior to June 2003, the expenses associated with the pipeline assets were recovered from customers through Cleco Power’s fuel adjustment clause, since these expenses were billed to Cleco Power by the affiliate energy company. Rather than prepare a formal rate filing requesting recovery of the pipeline assets’ cost, in March 2005, Cleco Power requested and the LPSC authorized Cleco Power to recover the cost of the assets until Cleco Power’s next base rate case. In July 2008, Cleco Power filed a request for a new rate plan with the LPSC. The regulatory liability was completely amortized during 2009, before the new RSP became effective.

Deferred Construction Carrying Costs

In February 2006, the LPSC approved Cleco Power’s plans to build Rodemacher Unit 3. Terms of the approval included authorization for Cleco Power to collect from customers an amount equal to 75% of the LPSC-jurisdictional portion of the carrying costs of capital during the construction phase of the unit. In any calendar year during the construction period, the amount collected from customers is not to exceed 6.5% of Cleco Power’s projected retail revenues. Cleco Power began collection of the carrying costs and established a regulatory liability in May 2006. For the twelve-month periods ended December 31, 2009, and 2008, Cleco Power had collected $56.9 million and $54.1 million, respectively, in construction carrying costs.

In October 2009, the LPSC voted unanimously to approve Cleco Power’s retail rate plan. The retail rate plan established that $183.2 million be returned to customers over a five-year period and that Cleco Power will record a regulatory asset for all amounts above the actual amount collected from customers. At December 31, 2009, the regulatory liability and the related regulatory asset were $183.2 million and $40.2 million, respectively. At December 31, 2009, $33.6 million was due to be returned to customers within one year. On February 12, 2010, Rodemacher Unit 3 commenced commercial operations and Cleco Power began amortizing the regulatory asset over a five-year period.

Deferred Fuel and Purchased Power Costs

The cost of fuel used for electric generation and the cost of power purchased for utility customers are recovered through the LPSC-established fuel adjustment clause, which enables Cleco Power to pass on to its customers substantially all such charges. For the year 2009, approximately 95% of Cleco Power’s total fuel cost was regulated by the LPSC, while the remainder was regulated by FERC. Deferred fuel and purchased power costs recorded at December 31, 2009, and 2008, were under-recoveries of $35.1 million and $69.2 million, respectively, and are scheduled to be collected from customers in future months. The $34.1 million decrease in the under-recovered funds was primarily the result of $32.5 million decreased loss in the mark-to-market of open gas positions and a $3.7 million decreased loss on closed natural gas hedge positions. These decreases were partially offset by the deferral of $2.1 million in additional fuel and purchased power costs.

Amended Lignite Mining Agreement Contingency

In April 2009, Cleco Power and SWEPCO entered into a series of transactions to acquire additional lignite reserves and mining equipment from NAC. Cleco Power and SWEPCO each agreed to purchase a 50% ownership interest in Oxbow from NAC for a combined price of $25.7 million. Through mineral lease agreements and ownership of fee land, Oxbow controls approximately 43 million tons of lignite reserves in an area referred to as the Oxbow Mine. In a separate, but related, transaction DHLC agreed to purchase all of the mining equipment located at the Oxbow Mine from NAC. Cleco Power, SWEPCO, and DHLC also entered into the Amended Lignite Mining Agreement which requires DHLC to mine lignite at the existing Dolet Hills Mine along with the Oxbow Mine and deliver the lignite to the Dolet Hills Power Station. The Amended Lignite Mining Agreement requires Cleco Power and SWEPCO to purchase the lignite mined and delivered by DHLC at cost plus a specified management fee. The two

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

mining areas are expected to be sufficient to provide the Dolet Hills Power Station with lignite fuel until at least 2026. In September 2009, the LPSC approved the joint application authorizing the transactions. The transactions closed in December 2009.

Among the provisions of the Amended Lignite Mining Agreement, it is a requirement that if DHLC is unable to pay for loans and lease payments when due, Cleco Power will pay 50% of the amounts due. Any payments under this provision will be considered a prepayment of lignite to be delivered in the future and will be credited to future invoices from DHLC. This provision meets the recognition requirements as a guarantee to an unrelated third party. Cleco Power recognized a liability of $3.8 million upon the closing of the transactions. A regulatory asset of $3.8 million was also recognized due to Cleco Power’s ability to recover prudent fuel costs from customers through the fuel adjustment clause. The liability and related regulatory asset will be derecognized when the Amended Lignite Mining Agreement terminates. The maximum projected payment by Cleco Power under this guarantee is estimated to be $72.5 million; however, the Amended Lignite Mining Agreement does not contain a cap. The projection is based on the forecasted loan and lease obligations to be incurred by DHLC, primarily for purchases of equipment. Cleco Power has the right to dispute the incurrence of loan and lease obligations through the review of the mining plan before the incurrence of such loan and lease obligations.

Note 4 — Jointly Owned Generation Units

Two electric generation units operated by Cleco Power are jointly owned with other utilities. The joint-owners are responsible for their own share of the capital and the operating and maintenance costs of the respective units. Cleco Power recognized $111.9 million, $104.8 million, and $92.3 million as its proportionate share of operating and maintenance expenses associated with these two units, which include fuel costs of $91.9 million, $86.9 million, and $72.0 million, during the years ended December 31, 2009, 2008, and 2007, respectively.

				AT DECEMBER 31, 2009
(DOLLAR AMOUNTS IN THOUSANDS)	RODEMACHER UNIT #2			DOLET HILLS			TOTAL
Utility plant in service	$	86,236		$	288,962		$	375,198
Accumulated depreciation	$	67,449		$	191,074		$	258,523
Ownership		30	%		50	%
Name plate capacity (MW)		523			650
Cleco Power’s ownership interest (MW)		157			325

Note 5 — Fair Value Accounting

The amounts reflected in Consolidated Balance Sheets of Cleco and Cleco Power at December 31, 2009, and 2008, for cash and cash equivalents, accounts receivable, accounts payable, and short-term debt approximate fair value because of their short-term nature. Estimates of the fair value of Cleco and Cleco Power’s long-term debt and Cleco’s nonconvertible preferred stock are based upon the quoted market price for the same or similar issues or by a discounted present value analysis of future cash flows using current rates obtained by Cleco and Cleco Power for debt and by Cleco for preferred stock with similar maturities.

Cleco’s convertible preferred stock relates to establishment of the ESOP. The ESOP borrowed $30.0 million, and subsequently, Cleco Power purchased the loan. The amount of the loan was directly offset by Cleco Power’s guarantee of the loan. The fair value of Cleco’s convertible preferred stock was estimated assuming its conversion into Cleco Corporation common stock at the market price per common share at December 31, 2006, with proceeds from the sale of the common stock used to repay the principal balance of Cleco Power’s loan to the ESOP. The loan was repaid in full in July 2006, and the ESOP preferred stock was converted to Cleco Corporation common stock in the first quarter of 2007.

The estimated fair value of energy market positions is based upon observed market prices when available. When such market prices are not available, management estimates market value at a discrete point in time by assessing market conditions and observed volatility. These estimates are subjective in nature and involve uncertainties. Therefore, actual results may differ from these estimates.

Cleco

					AT DECEMBER 31,
			2009				2008
(THOUSANDS)	CARRYING VALUE		ESTIMATED FAIR VALUE		CARRYING VALUE		ESTIMATED FAIR VALUE
Financial instruments not marked-to-market
Cash and cash equivalents	$	145,193	$	145,193	$	97,483	$	97,483
Restricted cash	$	56,451	$	56,451	$	102,982	$	102,982
Long-term debt, excluding debt issuance costs	$	1,319,540	$	1,353,479	$	1,172,874	$	1,110,171
Preferred stock not subject to mandatory redemption	$	1,029	$	874	$	1,029	$	699

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

										AT DECEMBER 31,
						2009							2008
(THOUSANDS)	ORIGINAL VALUE		OTHER UNREALIZED LOSSES DURING THE PERIOD			ESTIMATED FAIR VALUE		ORIGINAL VALUE		OTHER UNREALIZED LOSSES DURING THE PERIOD			ESTIMATED FAIR VALUE
Financial instruments marked-to-market
Energy market positions
Assets	$	87,149	$	(15,671	)	$	71,197	$	159,432	$	(47,293	)	$	117,851
Liabilities	$	131,692	$	(9,630	)	$	122,062	$	221,083	$	(10,315	)	$	210,768
Interest rate swap liability	$	-	$	(890	)	$	890	$	-	$	-		$	-

Cleco Power

					AT DECEMBER 31,
			2009				2008
(THOUSANDS)	CARRYING VALUE		ESTIMATED FAIR VALUE		CARRYING VALUE		ESTIMATED FAIR VALUE
Financial instruments not marked-to-market
Cash and cash equivalents	$	138,113	$	138,113	$	91,542	$	91,542
Restricted cash	$	56,354	$	56,354	$	102,885	$	102,885
Long-term debt, excluding debt issuance costs	$	1,224,540	$	1,258,479	$	1,142,874	$	1,080,171

										AT DECEMBER 31,
						2009							2008
(THOUSANDS)	ORIGINAL VALUE		OTHER UNREALIZED LOSSES DURING THE PERIOD			ESTIMATED FAIR VALUE		ORIGINAL VALUE		OTHER UNREALIZED LOSSES DURING THE PERIOD			ESTIMATED FAIR VALUE
Financial instruments marked-to-market
Energy market positions
Assets	$	87,149	$	(15,671	)	$	71,197	$	159,432	$	(47,293	)	$	117,851
Liabilities	$	131,692	$	(9,630	)	$	122,062	$	221,083	$	(10,315	)	$	210,768
Interest rate swap liability	$	-	$	(890	)	$	890	$	-	$	-		$	-

The financial instruments not marked-to-market are reported on Cleco’s and Cleco Power’s Consolidated Balance Sheets at carrying value. The financial instruments marked-to-market represent market risk recorded in the financial statements because, to the extent Cleco and Cleco Power have an open position, they are exposed to the risk that fluctuating market prices may adversely affect their financial condition or results of operations upon settlement. Original value represents the fair value of the positions at the time originated.

At December 31, 2009, Cleco and Cleco Power were exposed to concentration of credit risk through their short-term investments classified as cash equivalents and restricted cash. Cleco had $198.2 million ($141.8 million of cash and $56.4 million of restricted cash) in short-term investments in institutional money market funds. If the money market funds failed to perform under the terms of the investment, Cleco would be exposed to a loss of the invested amounts. Cleco Power had $191.2 million ($134.8 million of cash and $56.4 million of restricted cash) in short-term investments in institutional money market funds. If the money market funds failed to perform under the terms of the investments, Cleco Power would be exposed to a loss of the invested amounts. Collateral on these types of investments is not required by either Cleco or Cleco Power. In order to mitigate potential credit risk, Cleco and Cleco Power have established guidelines for short-term investments. Money market funds must have at least $1.0 billion in assets under management; must have been in existence for not less than two years; must have portfolios not comprised of more than 50% of securities issued by foreign entities; and must be rated in the top two ratings’ categories by at least one nationally recognized rating agency. Commercial paper must be issued by a company with headquarters in the U.S. and rated not less than A1 by Standard & Poor’s or P1 by Moody’s. For split-rated issuers, the second rating must not be lower than either A2 or P2; the issuer’s long-term debt must be rated not lower than A by Standard & Poor’s or A2 by Moody’s; and the issuer cannot be on negative credit watch. Investments in commercial paper rated A2 by Standard & Poor’s or P2 by Moody’s may be made if approved by the appropriate level of management.

Cleco Power was exposed to concentration of credit risk through its energy marketing assets. At December 31, 2009, Cleco Power had energy marketing assets with an estimated fair value of $71.2 million. These energy marketing assets represent open natural gas purchase positions, primarily financial hedge transactions. Cleco Power entered into these positions to mitigate the volatility in the cost of fuel purchased for utility generation and the risk associated with the fixed-price power that is being provided to a wholesale customer through December 2010. If the counterparties to these assets fail to perform under the terms of the investment, Cleco Power would be exposed to a loss of $71.2 million. For information about credit risk management and how these risks are mitigated on energy marketing assets, see Note 2 — “Summary of Significant Accounting Policies — Risk Management.”

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

Interest Rate Swap

In August 2009, Cleco Power entered into a $50.0 million bank loan with variable interest, paid monthly, and calculated at 3.00% plus the one-month LIBOR. The loan matures on August 19, 2012. In order to mitigate risk of the future floating interest rates, Cleco Power entered into an interest rate swap with JPMorgan Chase Bank, N.A in the third quarter of 2009. Based on the notional amount of the bank loan, the swap requires a monthly net settlement between Cleco Power’s fixed payment of 1.84% and the swap counterparty’s floating payment of the one-month LIBOR. The swap matures on May 31, 2012. Both the bank loan and the swap were effective the same day and require monthly payments near the end of the month. From the inception of the loan to December 31, 2009, Cleco Power recognized net interest expense equal to an annual rate of 4.84% on the bank loan. Since both the bank loan and the swap require payments near the end of the month, the cash payments are materially close to the interest expense recognized.

The swap is considered a derivative and is carried on the balance sheet at its fair value. Its fair value is calculated by the present value of the fixed payments as compared to expected future LIBOR rates. Since future LIBOR rates are not available for each month until termination, quoted LIBOR rates from an active exchange for observable time periods were used to create a forward “LIBOR curve” for all months until termination. Because of the inputs and common techniques used to calculate fair value, the swap valuation is considered Level 2.

The swap meets the criteria of a cash flow hedge under the authoritative guidance as it relates to derivatives and hedging. Changes in the swap’s fair value related to the effective portion are recognized in other comprehensive income, whereas changes in the fair value related to the ineffective portion are recognized in earnings. As time passes and settlements are made, the swap’s other comprehensive income fair values are reclassified into earnings as a component of interest expense. For the year ended December 31, 2009, there were $0.3 million of reclassification adjustments from other comprehensive income to interest expense. There was no impact to earnings due to ineffectiveness for the year ended December 31, 2009.

Fair Value Measurements and Disclosures

Entities are required to classify assets and liabilities measured at their fair value according to three different levels depending on the inputs used in determining fair value.

§	Level 1 – unadjusted quoted prices in active, liquid markets for the identical asset or liability;

§	Level 2 – quoted prices for similar assets and liabilities in active markets or other inputs that are observable for the asset or liability, including inputs that can be corroborated by observable market data, observable interest rate yield curves and volatilities;

§	Level 3 – unobservable inputs based upon the entities’ own assumptions.

The tables below disclose for Cleco and Cleco Power the fair value of financial assets and liabilities measured on a recurring basis and within the scope of the authoritative guidance for fair value measurements and disclosures.

Cleco

	CLECO CONSOLIDATED FAIR VALUE MEASUREMENTS AT REPORTING DATE USING:
(THOUSANDS)	AT DECEMBER 31, 2009		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)		AT DECEMBER 31, 2008		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)
Asset Description
Energy market derivatives	$	141	$	-	$	141	$	-	$	3,687	$	-	$	3,687	$	-
Institutional money market funds		198,155		-		198,155		-		204,789		-		204,789		-
Total	$	198,296	$	-	$	198,296	$	-	$	208,476	$	-	$	208,476	$	-

	CLECO CONSOLIDATED FAIR VALUE MEASUREMENTS AT REPORTING DATE USING:
(THOUSANDS)	AT DECEMBER 31, 2009		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)		AT DECEMBER 31, 2008		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)
Liability Description
Energy market derivatives	$	25,441	$	8,106	$	17,335	$	-	$	61,295	$	13,757	$	47,538	$	-
Interest rate swap		890		-		890		-		-		-		-		-
Total	$	26,331	$	8,106	$	18,225	$	-	$	61,295	$	13,757	$	47,538	$	-

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

Cleco Power

	CLECO POWER FAIR VALUE MEASUREMENTS AT REPORTING DATE USING:
(THOUSANDS)	AT DECEMBER 31, 2009		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)		AT DECEMBER 31, 2008		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)
Asset Description
Energy market derivatives	$	141	$	-	$	141	$	-	$	3,687	$	-	$	3,687	$	-
Institutional money market funds		191,155		-		191,155		-		198,989		-		198,989		-
Total	$	191,296	$	-	$	191,296	$	-	$	202,676	$	-	$	202,676	$	-

	CLECO POWER FAIR VALUE MEASUREMENTS AT REPORTING DATE USING:
(THOUSANDS)	AT DECEMBER 31, 2009		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)		AT DECEMBER 31, 2008		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)
Liability Description
Energy market derivatives	$	25,441	$	8,106	$	17,335	$	-	$	61,295	$	13,757	$	47,538	$	-
Interest rate swap		890		-		890		-		-		-		-		-
Total	$	26,331	$	8,106	$	18,225	$	-	$	61,295	$	13,757	$	47,538	$	-

The derivative assets and liabilities are classified as either current or non-current depending on when the positions close. All energy market derivative current assets and current liabilities are reported as a net current risk management asset or liability. All energy market derivative non-current assets and non-current liabilities are reported net in other deferred charges or other deferred credits. Net presentation is appropriate due to the right of offset included in the master netting agreements. On the balance sheet, the net current and net non-current derivative positions are netted with the applicable margin deposits. At December 31, 2009, a net current risk management asset of $2.9 million represented current deferred options. At December 31, 2009, a net current risk management liability of $13.8 million represented the current derivative positions of $22.9 million reduced by current margin deposits of $9.1 million. The non-current liability derivative positions of $2.4 million reduced by non-current margin deposits of $0.9 million were recorded in other deferred credits. The institutional money market funds were reported on the Cleco Consolidated balance sheet in cash and cash equivalents, current restricted cash, and non-current restricted cash in the amounts of $141.8 million, $29.9 million, and $26.5 million, respectively. At Cleco Power, cash and cash equivalents, current restricted cash, and restricted non-current cash were $134.8 million, $29.9 million, and $26.4 million, respectively, as of December 31, 2009.

Cleco utilizes different valuation techniques for fair value calculations. In order to measure the fair value for Level 1 assets and liabilities, Cleco obtains the closing price from published indices in active markets for the various instruments and multiplies this price by the appropriate number of instruments held. Level 2 fair values for assets and liabilities are determined by obtaining the closing price from published indices in active markets for instruments that are similar to Cleco’s assets and liabilities. The fair value obtained is then discounted to the current period using a U.S. Treasury published interest rate as a proxy for a risk-free rate of return. For some options, Cleco uses the Black-Scholes model using observable and available inputs to calculate the fair value, consistent with the income approach. These techniques have been applied consistently from fiscal period to fiscal period. Level 3 fair values allow for situations in which there is little, if any, market activity for the asset or liability at the measurement date. Cleco had no Level 3 assets or liabilities at December 31, 2009, or 2008.

Derivatives and Hedging

A disclosure amendment to the authoritative guidance on derivatives and hedging which requires entities to provide greater transparency in interim and annual financial statements became effective for financial statements issued for fiscal years and interim periods beginning after November 15, 2008. This amendment required enhanced disclosures about a company’s derivative activities and how the related hedged items affect a company’s financial position, financial performance, and cash flows. Cleco is required to provide qualitative disclosures about derivative fair value, gains and losses, and credit-risk-related contingent features in derivative agreements.

The following table presents the fair values of derivative instruments and their respective line item as recorded on the Consolidated Balance Sheets of Cleco and Cleco Power at December 31, 2009:

	DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
	LIABILITY DERIVATIVES
(THOUSANDS) AT DECEMBER 31, 2009	BALANCE SHEET LINE ITEM	FAIR VALUE
Commodity contracts
Economic hedges:
Current	Risk management liability, net	$	(405	)
Fuel cost hedges:
Current	Risk management liability, net		(22,502	)
Long-term	Other deferred credits		(2,394	)
Total		$	(25,301	)

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

The following table presents the effect of derivatives not designated as hedging instruments on Cleco and Cleco Power’s Consolidated Statements of Income for year ended December 31, 2009:

(THOUSANDS)	LOSS IN INCOME OF DERIVATIVES LINE ITEM	AMOUNT OF LOSS RECOGNIZED IN INCOME ON DERIVATIVES YEAR ENDED DECEMBER 31, 2009
Commodity contracts
Economic hedges	Other operations revenue	$	1,805	(1)
Fuel cost hedges(2)	Fuel used for electric generation		92,609
Total		$	94,414
(1)For the year ended December 31, 2009, Cleco recognized $0.2 million of mark-to-market losses related to economic hedges.
(2)In accordance with the authoritative guidance for regulated operations, an additional $24.9 million of unrealized losses and $2.6 million of deferred losses associated with fuel cost hedges are reported in Accumulated Deferred Fuel on the balance sheet. As gains and losses are realized in future periods, they will be recorded as Fuel Used for Electric Generation on the Income Statement. For more information, see Note 3 — “Regulatory Assets and Liabilities — Deferred Fuel and Purchased Power Costs.”

At December 31, 2009, Cleco had 15.2 million MMBtus hedged for natural gas fuel costs, which is approximately 28% of the estimated natural gas requirements for a two-year period. Cleco had an additional 0.4 million MMBtus hedged through 2010, resulting from economic hedges, which is approximately 88% of the estimated daily peak-hour sales to a wholesale customer.

The following table presents the fair values of derivatives designated as hedging instruments and their respective line item as recorded on the Consolidated Balance Sheets of Cleco and Cleco Power at December 31, 2009:

	DERIVATIVES DESIGNATED AS HEDGING INSTRUMENTS
	LIABILITY DERIVATIVES
(THOUSANDS) AT DECEMBER 31, 2009	BALANCE SHEET LINE ITEM	FAIR VALUE
Interest rate swap
Cash flow hedges:
Current	Other current liabilities	$	638
Long-term	Other deferred credits		252
Total		$	890

The following table presents the effect of derivatives designated as hedging instruments on Cleco and Cleco Power’s Consolidated Statements of Income for the year ended December 31, 2009:

(THOUSANDS)	AMOUNT OF (LOSS) GAIN RECOGNIZED IN OCI YEAR ENDED DECEMBER 31, 2009			LOCATION OF (LOSS) GAIN RECLASSIFIED FROM ACCUMULATED OCI INTO INCOME (EFFECTIVE PORTION)	AMOUNT OF (LOSS) GAIN RECLASSED FROM ACCUMULATED OCI INTO INCOME (EFFECTIVE PORTION) YEAR ENDED DECEMBER 31, 2009
Interest rate swap	$	(1,186	)	Interest charges	$	(299	)
Treasury rate lock	$	4,324		Interest charges	$	14

Cleco and Cleco Power recorded a reduction to interest expense of $0.4 million related to the ineffectiveness of hedges for the year ended December 31, 2009. At December 31, 2009, Cleco Power expects $0.2 million of the effective portion of the treasury rate lock cash flow hedge to be reclassed from accumulated OCI to a reduction in interest charges over the next twelve months. The short-term liability associated with the mark-to-market of the interest rate swap is $0.6 million and is expected to be reclassified as an increase to interest charges over the next twelve months. This amount may change based on the market value of the interest rate swap over the next year. For additional information on the interest rate swap, see “— Interest Rate Swap.” For additional information on the treasury rate lock, see “— Note 6 — Debt.”

Note 6 — Debt

Cleco

Cleco’s total indebtedness as of December 31, 2009, and 2008, was as follows.

	AT DECEMBER 31,
(THOUSANDS)	2009			2008
Cleco Power’s senior notes, 5.375%, due 2013	$	75,000		$	75,000
Cleco Power’s senior notes, 4.95%, due 2015		50,000			50,000
Cleco Power’s senior notes, 6.65%, due 2018		250,000			250,000
Cleco Power’s senior notes, 6.50%, due 2035		295,000			150,000
Cleco Power’s pollution control revenue bonds, 5.875%, due 2029, callable after September 1, 2009		61,260			61,260
Cleco Power’s solid waste disposal facility bonds, 4.70%, due 2036, callable after November 1, 2016		60,000			60,000
Cleco Power’s solid waste disposal facility bonds, 5.25%, due 2037, mandatory tender on March 1, 2013		60,000			60,000
Cleco Power’s solid waste disposal facility bonds, 6.00%, due 2038, mandatory tender on October 1, 2011		32,000			32,000
Cleco Power’s GO Zone bonds, 7.00%, due 2038, mandatory tender on December 1, 2011		100,000			100,000
Cleco Katrina/Rita’s storm recovery bonds, 4.41%, due 2020		99,454			113,000
Cleco Katrina/Rita’s storm recovery bonds, 5.61%, due 2023		67,600			67,600
Total bonds		1,150,314			1,018,860
Cleco Power’s medium-term notes, 6.52%, due 2009		-			50,000
Total medium-term notes		-			50,000
Cleco Power’s bank term loan, variable rate, due 2012		50,000			-
Total bank term loans		50,000			-
Cleco Power’s insured quarterly notes
6.05%, due 2012, callable after June 1, 2004		-			49,567
6.125%, due 2017, callable after March 1, 2005		24,226			24,447
Total insured quarterly notes		24,226			74,014
Cleco Corporation’s credit facility draws		95,000			30,000
Total credit facility draws		95,000			30,000
Capital leases
Barges, ending December 31, 2013		20,751			-
Mobile computers, ending December 31, 2010		123			239
Less: amount due within one year		(1,636	)		(116	)
Capital lease – long-term		19,238			123
Gross amount of long-term debt		1,338,778			1,172,997
Less: amount due within one year		(11,478	)		(63,546	)
Less: unamortized premium and discount, net		(7,001	)		(2,632	)
Total long-term debt, net	$	1,320,299		$	1,106,819

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

The amounts payable under long-term debt agreements for each year through 2014 and thereafter are listed below.

(THOUSANDS)		2010				2011				2012				2013				2014				THEREAFTER
Amounts payable under long-term debt agreements		$	11,478			$	107,269			$	63,108			$	148,969			$	14,876			$	973,840

At December 31, 2009, and 2008, Cleco had no outstanding short-term debt. Cleco had $11.5 million and $63.5 million of long-term debt due within one year at December 31, 2009, and 2008, respectively.

During 2009, Cleco Power entered into a capital lease for barges in order to transport petroleum coke and limestone to Rodemacher Unit 3. The initial term of the lease agreement will terminate December 31, 2013, at which time, Cleco Power will have the option to renew the lease agreement for a second five-year term. For more information on the barge lease, see Note 15 — “Litigation, Other Commitment and Contingencies, and Disclosures about Guarantees — Other Contingencies — Fuel Transportation Agreement.”

The mobile computer capital lease in Cleco’s total indebtedness chart is for computers with local area network capabilities and has a lease term of five years. The mobile computers can be purchased at the end of the lease term. The lease payments are due at the beginning of each month. The monthly lease payment is derived by multiplying the total acquisition costs by 1.92% for a full month and 0.06% per day for a partial month.

The amounts payable under the capital lease agreements for the next five years are listed below.

(THOUSANDS)		2010				2011				2012				2013				2014				THEREAFTER
Amounts payable under the capital lease agreement		$	1,636			$	1,666			$	1,844			$	2,021			$	2,225			$	11,482

Cleco Power

Cleco Power’s total indebtedness as of December 31, 2009, and 2008, was as follows.

	AT DECEMBER 31,
(THOUSANDS)	2009			2008
Senior notes, 5.375%, due 2013	$	75,000		$	75,000
Senior notes, 4.95%, due 2015		50,000			50,000
Senior notes, 6.65%, due 2018		250,000			250,000
Senior notes, 6.50%, due 2035		295,000			150,000
Pollution control revenue bonds, 5.875%, due 2029, callable after September 1, 2009		61,260			61,260
Solid waste disposal facility bonds, 4.70%, due 2036, callable after November 1, 2016		60,000			60,000
Solid waste disposal facility bonds, 5.25%, due 2037, mandatory tender on March 1, 2013		60,000			60,000
Solid waste disposal facility bonds, 6.00%, due 2038, mandatory tender on October 1, 2011		32,000			32,000
GO Zone bonds, 7.00%, due 2038, mandatory tender on December 1, 2011		100,000			100,000
Cleco Katrina/Rita’s storm recovery bonds, 4.41%, due 2020		99,454			113,000
Cleco Katrina/Rita’s storm recovery bonds, 5.61%, due 2023		67,600			67,600
Total bonds		1,150,314			1,018,860
Medium-term notes, 6.52%, due 2009		-			50,000
Total medium-term notes		-			50,000
Cleco Power’s bank term loan, variable rate, due 2012		50,000			-
Total bank term loans		50,000			-
Insured quarterly notes
6.05%, due 2012, callable after June 1, 2004		-			49,567
6.125%, due 2017, callable after March 1, 2005		24,226			24,447
Total insured quarterly notes		24,226			74,014
Capital leases
Barges, ending December 31, 2013		20,751			-
Mobile computers, ending December 31, 2010		123			239
Less: amount due within one year		(1,636	)		(116	)
Capital lease – long-term		19,238			123
Gross amount of long-term debt		1,243,778			1,142,997
Less: amount due within one year		(11,478	)		(63,546	)
Less: unamortized premium and discount, net		(7,001	)		(2,632	)
Total long-term debt, net	$	1,225,299		$	1,076,819

The amounts payable under long-term debt agreements for each year through 2014 and thereafter are listed below.

(THOUSANDS)		2010				2011				2012				2013				2014				THEREAFTER
Amounts payable under long-term debt agreements		$	11,478			$	12,269			$	63,108			$	148,969			$	14,876			$	973,840

At December 31, 2009, and 2008, Cleco Power had no outstanding short-term debt. At December 31, 2009, Cleco Power had $11.5 million of long-term debt due within one year, compared to $63.5 million long-term debt due within one year at December 31, 2008.

In August 2009, Cleco Power redeemed all $49.5 million principal amount of its outstanding 6.05% insured quarterly notes due June 2012. The notes were replaced with a one-month LIBOR plus 3.00% floating rate bank term loan maturing on August 19, 2012. In July 2009, Cleco Power locked in a $50.0 million interest rate swap arrangement related to this loan. This swap was effective on August 19, 2009 and will

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

mature on May 31, 2012. For additional information, see Note 5 — “Fair Value Accounting — Interest Rate Swap.”

In November 2009, Cleco Power issued $145.0 million aggregate principal amount of senior unsecured notes, as additional notes of a class of $150.0 million senior notes issued in November 2005. The interest rate for the notes is 6.50%, and the aggregate $295.0 million of the notes mature on December 1, 2035. The net proceeds from the $145.0 million issuance were used for general corporate purposes, including financing a portion of the construction costs related to the Acadiana Load Pocket transmission project.

Also in November 2009, Cleco Power settled the treasury rate lock that was entered into in October 2009. The reference rate, based on the 30-year treasury note yield, on the date of settlement of the treasury rate lock was 4.378%, which resulted in Cleco Power receiving $4.7 million from the counterparty. The treasury rate lock is considered a derivative instrument that qualifies as a cash flow hedge for accounting purposes. While the treasury rate lock meets the definition of highly effective, it did contain some ineffectiveness relating to the discount period of the treasury rate lock (30 years) as compared to the discount period used to calculate the senior note issuance discount (26 years). Cleco Power recorded the ineffective portion, $0.4 million, as a reduction in interest expense. The remaining effective portion, $4.3 million, was recorded as an increase in accumulated other comprehensive income. The $4.3 million in accumulated other comprehensive income will be reclassified as a reduction to interest expense over the remaining 26-year life of the senior notes.

During 2009, Cleco Power entered into a capital lease for barges in order to transport petroleum coke and limestone to Rodemacher Unit 3. The initial term of the lease agreement will terminate December 31, 2013, at which time, Cleco Power will have the option to renew the lease agreement for a second five-year term. For more information on the barge lease, see Note 15 — “Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Other Contingencies — Fuel Transportation Agreement.”

The mobile computer capital lease in Cleco Power’s total indebtedness chart is for computers with local area network capabilities and has a lease term for five years. The mobile computers can be purchased at the end of the lease term. The lease payments are due at the beginning of each month. The monthly lease payment is derived by multiplying the total acquisition costs by 1.92% for a full month and 0.06% per day for a partial month.

The amounts payable under the capital lease agreements for the next five years are listed below.

(THOUSANDS)		2010				2011				2012				2013				2014				THEREAFTER
Amounts payable under the capital lease agreement		$	1,636			$	1,666			$	1,844			$	2,021			$	2,225			$	11,482

Credit Facilities

Cleco has two separate revolving credit facilities, one for Cleco Corporation and one for Cleco Power, with a maximum aggregate capacity of $425.0 million.

Cleco Corporation has a revolving five-year credit facility with a maximum capacity of $150.0 million that matures in 2011. Cleco Corporation’s borrowing costs under this facility are equal to LIBOR plus 0.65%, including facility fees. This facility provides for working capital and other needs. If Cleco Power defaults under the Cleco Power facility, then Cleco Corporation would be considered in default under the Cleco Corporation facility. At December 31, 2009, there was $95.0 million outstanding under Cleco Corporation’s credit facility. The weighted average interest rate was 0.763% at December 31, 2009, for outstanding borrowings under this credit facility.

In August 2009, Cleco Corporation and the lenders under its $150.0 million five-year credit facility amended the credit facility to increase the threshold in a representation that the present value of all accumulated benefit obligations under Cleco’s pension plan is allowed to exceed the fair market value of the assets of the plan. At December 31, 2008, the present value of all accumulated benefit obligations under the pension plan exceeded the fair market value of the plan assets by approximately $61.4 million. In connection with the amendment, the lenders under the credit facility waived each event of default relating to the breach of the representation from December 31, 2008, to the date of the amendment. In connection with the waiver and amendment, Cleco Corporation paid the lenders approximately $0.1 million, which fees are included in interest expense for the year ended December 31, 2009. Off-balance sheet commitments entered into by Cleco Corporation with third parties for certain types of transactions between those parties and Cleco’s subsidiaries, other than Cleco Power, reduce the amount of credit available to Cleco Corporation under the facility by an amount equal to the stated or determinable amount of the primary obligation. At December 31, 2009, the $150.0 million of capacity was reduced by outstanding credit facility borrowings of $95.0 million and off-balance sheet commitments of $15.0 million, leaving available capacity of $40.0 million. An uncommitted line of credit with a bank in an amount up to $10.0 million also is available to support Cleco Corporation’s working capital needs.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

Cleco Power has a revolving credit facility with a maximum capacity of $275.0 million that matures in 2011. This facility provides for working capital and other needs. Cleco Power’s borrowing cost under this facility is equal to LIBOR plus 0.50%, including facility fees. At December 31, 2009, there were no outstanding draws under Cleco Power’s credit facility. At December 31, 2009, Cleco Power was in compliance with the covenants in this credit facility. In August 2009, Cleco Power and the lenders under its $275.0 million five-year credit facility amended the credit facility to increase the threshold in a representation that the present value of all accumulated benefit obligations under Cleco’s pension plan is allowed to exceed the fair market value of the assets of the plan. At December 31, 2008, the present value of all accumulated benefit obligations under the pension plan exceeded the fair market value of the plan assets by approximately $61.4 million. In connection with the amendment, the lenders under the credit facility waived each event of default relating to the breach of the representation from December 31, 2008, to the date of the amendment. In connection with the waiver and amendment, Cleco Power paid the lenders approximately $0.1 million, which fees are included in interest expense for the year ended December 31, 2009. An uncommitted line of credit with a bank in an amount up to $10.0 million also is available to support Cleco Power’s working capital needs.

Note 7 — Common Stock

Stock-Based Compensation

At December 31, 2009, Cleco had two stock-based plans, ESPP and the LTICP. Substantially all employees, excluding officers and general managers, may choose to participate in the ESPP and purchase a limited amount of common stock at a discount through a stock option agreement. Options or restricted shares of stock, known as non-vested stock as defined by the authoritative guidance on stock-based compensation, common stock equivalents, and stock appreciation rights may be granted to certain officers, key employees, or directors of Cleco Corporation and its subsidiaries pursuant to the LTICP.

The fair market value of non-vested stock was recorded as compensation expense during the service periods, which are generally three years, after which the restrictions lapse, and assuming obtainment of vesting requirements was probable. All stock-based compensation cost is measured at the grant date, based on the fair value of the award, and is recognized as an expense in the income statement over the grant’s requisite service period. Awards that vest pro rata during the requisite service period that contain only a service condition could be viewed not as one award, but instead as multiple awards with separate vesting schedules and are defined as having a graded vesting schedule. Cleco has elected to view grants with graded vesting schedules as one award and recognize the related compensation expense on a straight-line basis over the requisite service period. The ESPP’s discount rate is 5%, substantially all employees can participate in the ESPP, and the plan does not contain optionality features beyond those listed by the authoritative guidance on stock-based compensation. Cleco is not required to recognize a fair-value expense related to the ESPP.

Cleco adopted the modified prospective method for stock-based compensation, which requires compensation expense to be recorded for all non-vested options and non-vested stock beginning in the first quarter of adoption. This cost was based on the grant-date fair value. The cost for all stock-based awards, represents the grant-date fair value. Cleco Corporation and Cleco Power reported pre-tax compensation expense for their stock-based compensation plans as shown in the following table.

	CLECO						CLECO POWER
							FOR THE YEAR ENDED DECEMBER 31,
(THOUSANDS)	2009		2008		2007		2009		2008		2007
Equity classification
Non-vested stock	$	2,084	$	1,585	$	2,928	$	549	$	394	$	1,293
Stock options (1)		51		55		38		-		-		(4	)
Non-forfeitable dividends (1)		-		-		27		-		-		16
Total	$	2,135	$	1,640	$	2,993	$	549	$	394	$	1,305
Liability classification
Common stock equivalent units	$	3,545	$	1,494	$	1,530	$	1,306	$	501	$	617
Company funded participants income tax obligations		-		-		3,295		-		-		1,852
Total	$	3,545	$	1,494	$	4,825	$	1,306	$	501	$	2,469
Total pre-tax compensation expense	$	5,680	$	3,134	$	7,818	$	1,855	$	895	$	3,774
Tax benefit	$	2,186	$	1,206	$	1,740	$	714	$	345	$	739
(1)For the years ended December 31, 2009, 2008, and 2007 compensation expense charged against income for non-forfeitable dividends paid on non-vested stock not expected to vest and stock options was $0.1 million.

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

As required by the authoritative guidance on stock-based compensation, the amount of stock-based compensation capitalized in property, plant and equipment for the years ended December 31, 2009, and 2008, was $2.0 million and $0.9 million, respectively.

Cash received from options exercised under all stock-based compensation plans for the years ended December 31, 2009, and 2008, were $2.1 million and $1.0 million, respectively. The associated tax benefit for options exercised for each of the years ended December 31, 2009, and 2008 was $0.1 million. No cash was paid to settle equity instruments granted under the stock-based compensation plans for the years ended December 31, 2009 or 2008.

Stock-Based Plan Descriptions and Share Information

Stock Options

LTICP stock options may be granted to certain officers, key employees, or directors of Cleco. The directors’ stock options have an exercise price calculated by averaging the high and low stock price on the grant date rounded to the nearest one-eighth, are immediately exercisable, and expire after ten years. The employees’ stock options have an exercise price calculated by averaging the high and low stock price on the grant date rounded to the nearest one-eighth, vest one-third each year, beginning on the third anniversary of the grant date, and expire after ten years. The estimated fair value was calculated using the Black-Scholes option pricing model and was included in the pro forma disclosures. The fair market values of LTICP stock options granted in 2007 were measured on the grant date using the Black-Scholes option-pricing model with the following weighted-average assumptions. There were no stock options granted in 2009 or 2008.

	AT DECEMBER 31,2007
Expected term (in years) (1)		7.0
Volatility (2)	27.0% to 30.4%
Expected dividend yield		4.1	%
Risk-free interest rate		4.5	%
Weighted average fair value (Black-Scholes value)	$	4.81
(1)The expected term was determined using an SEC safe harbor method due to the small number of recipients of these options.
(2)The volatility rate is based on historical stock prices over an appropriate period, generally equal to the expected term.

A summary of LTICP stock option activity during the year ended December 31, 2009, is presented below.

	SHARES			WEIGHTED-AVERAGE EXERCISE PRICE		WEIGHTED-AVERAGE REMAINING CONTRACTUAL TERM (YEARS)		AGGREGATE NTRINSIC VALUE(THOUSANDS)
Outstanding at January 1, 2009		420,240		$	20.64		14.49	$	997
Exercised		(111,923	)	$	19.08
Forfeited		(4,634	)	$	24.12
Expired		(17,500	)	$	20.69
Outstanding at December 31, 2009		286,183		$	21.20		13.04	$	1,755
Exercisable at December 31, 2009		235,683		$	20.96		15.09	$	1,502

The total intrinsic value of options exercised during the years ended December 31, 2009, 2008, and 2007 was $0.4 million, $0.2 million, and $2.8 million, respectively.

Non-Vested Stock and Common Stock Equivalent Units

In 2007, 2008, and 2009, Cleco granted non-vested stock and common stock equivalent units (CEUs) to certain employees. The non-vested stock is classified as equity since the grant can only be settled in shares of Cleco Corporation common stock. The recipients of the non-vested stock can vote the shares; however, dividends are not paid until the end of the service period and only in proportion to the non-vested stock that actually vests. The CEUs granted are classified as liabilities since the grant is currently settled in cash. Recipients of the CEUs will receive a dividend equivalent under the same terms as the dividends paid on the non-vested stock. In order to vest, both instruments require the satisfaction of a service requirement and a market-based requirement. Recipients of both types of instruments are eligible to receive opportunity instruments if certain market-based measures are exceeded.

At December 31, 2009, the number of target and opportunity restricted shares and CEUs previously granted for which restrictions had not lapsed totaled 729,724. Cleco also grants to employees and directors non-vested stock with only a service period requirement. These grants require the satisfaction of a pre-determined service period in order for the shares to vest. During the vesting period, the employees and directors can vote and receive dividends on the shares. At December 31, 2009, the number of shares of non-vested stock previously granted with only a service period requirement for which the period had not ended was 112,101.

The fair value of shares of non-vested stock granted in 2009, 2008, and 2007 under the LTICP is estimated on the date of grant, and the CEUs granted in 2009, 2008, and 2007 under the LTICP are marked-to-market using the Monte Carlo simulation model with the assumptions listed in the following table.

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CLECO POWER	2009 FORM 10-K

										AT DECEMBER 31,
				2009						2008						2007
	NON-VESTED STOCK			CEUs			NON-VESTED STOCK			CEUs			NON-VESTED STOCK			CEUs
Expected term (in years) (1)		3.0			3.0			3.0			3.0			3.0			3.0
Volatility of Cleco stock (2)		28.6	%		29.9	%		20.8	%		28.3	%		18.6	%		20.4	%
Correlation between Cleco stock volatility and peer group		62.5	%		62.5	%		52.1	%		61.4	%		35.2	%		49.5	%
Expected dividend yield		3.9	%		4.1	%		3.6	%		4.1	%		3.6	%		3.3	%
Weighted average fair value (Monte Carlo model)	$	25.93		$	30.81		$	25.85		$	22.73		$	26.16		$	35.02
(1) The expected term was based on the service period of the award.
(2)The volatility rate is based on historical stock prices over an appropriate period, generally equal to the expected term.

A summary of non-vested stock activity during the year ended December 31, 2009, is presented in the following table.

	SHARES			WEIGHTED-AVERAGE GRANT-DATE FAIR VALUE		UNITS			WEIGHTED-AVERAGE FAIR VALUE
	NON-VESTED STOCK					CEUs
Non-vested at January 1, 2009		188,805		$	24.34		109,717		$	27.82
Granted		97,149		$	25.27		74,253		$	25.93
Vested		(49,350	)	$	26.19		(49,350	)	$	40.52
Forfeited		(1,539	)	$	26.01		(1,539	)	$	35.82
Non-vested at December 31, 2009		235,065		$	24.33		133,081		$	30.85

The fair value of shares of non-vested stock which vested during the years ended December 31, 2009, 2008, and 2007 was $2.6 million, $2.4 million, and $3.7 million, respectively.

During the years ended December 31, 2009, 2008, and 2007, Cleco did not significantly modify any of the terms of outstanding awards. In all periods presented, Cleco has recognized stock-based compensation expense for these provisions, which is known as the non-substantive vesting period approach. The grants of non-vested stock to employees in January 2009, 2008, and 2007 did not contain the accelerated vesting provisions included in the prior years’ grants.

A maximum of 3,200,000 shares of Cleco Corporation common stock could be granted under the 2000 LTICP. As of December 31, 2009, there were 1,133,703 shares remaining under the 2000 LTICP. On December 31, 2009, the 2000 LTICP expired in accordance with its terms, and no further grants or awards will be made under that plan. Grants and awards made under the 2000 LTICP will remain outstanding in accordance with its existing terms. At December 31, 2009, there were stock options to purchase 286,183 shares of Cleco Corporation common stock and 368,146 shares of non-vested Cleco Corporation common stock outstanding under the 2000 LTICP. On January 1, 2010, the 2010 LTICP became effective. A maximum of 2,250,000 shares of Cleco Corporation common stock can be granted under the 2010 LTICP. Equity instruments awarded to employees and directors historically have come from issuing new shares of common stock. As of December 31, 2009, there were 117,695 non-vested share-based compensation arrangements granted under the LTICP that are expected to vest over an average period of 1.6 years. The total unrecognized before-tax compensation cost was $2.6 million for non-vested stock-based compensation arrangements granted under the LTICP.

Retained Earnings Restrictions

Various debt agreements contain covenants that restrict the amount of retained earnings that may be distributed as dividends to common shareholders. The most restrictive covenant requires Cleco Corporation’s total indebtedness to be less than or equal to 65% of total capitalization. At December 31, 2009, approximately $401.7 million of retained earnings were unrestricted.

Shareholder Rights Plan

In July 2000, Cleco Corporation’s Board of Directors adopted the Shareholder Rights Plan (Rights Plan). Under the Rights Plan, the holders of common stock as of August 14, 2000, received a dividend of one right for each share of common stock held on that date. In the event an acquiring party accumulates 15% or more of Cleco Corporation’s common stock, the rights would, in essence, allow the holder to purchase Cleco Corporation’s common stock at half the current fair market value. Cleco Corporation generally would be entitled to redeem the rights at $.01 per right at any time until the tenth day following the time the rights become exercisable. The rights expire on July 30, 2010.

Employee Stock Purchase Plan

In January 2000, Cleco Corporation’s Board of Directors adopted the ESPP. Shareholders approved the plan in April 2000, and the plan was implemented on October 1, 2000.

Regular, full-time, and part-time employees of Cleco Corporation and its participating subsidiaries, except officers, general managers, and employees who own 5% or more of Cleco Corporation’s stock, may participate in the ESPP. An eligible employee enters into an option agreement to become a participant in the ESPP. Under the agreement, the employee authorizes payroll deductions in an amount not less than $10 but not more than $350 each pay period. Payroll deductions are accumulated during a calendar quarter and

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applied to the purchase of common stock at the end of each quarter, which is referred to as an “offering period.” Pending the purchase of common stock, payroll deductions remain as general assets of Cleco. No trust or other fiduciary account has been established in connection with the ESPP. At the end of each offering period, payroll deductions are automatically applied to the purchase of shares of common stock. The number of shares of common stock purchased is determined by dividing each participant’s payroll deductions during the offering period by the option price of a share of common stock.

A maximum of 734,000 shares of common stock may be purchased under the ESPP, subject to adjustment for changes in the capitalization of Cleco Corporation. The Compensation Committee of Cleco Corporation’s Board of Directors administers the ESPP. The Compensation Committee and the Board of Directors each possess the authority to amend the ESPP, but shareholder approval is required for any amendment that increases the number of shares covered by the ESPP. In January 2009, the Board of Directors approved and authorized an additional 50,000 shares of common stock to be reserved for issuance under the DRIP Feature of the ESPP. As of December 31, 2009, there were 464,703 shares of common stock left to be purchased under the ESPP.

Common Stock Repurchase Program

In 1991, the Board of Directors authorized management to repurchase up to $30.0 million of common stock. At December 31, 2009, approximately $16.1 million of common stock was available for repurchase under this authorization. Purchases are made on a discretionary basis at times and in amounts as determined by management, subject to market conditions, legal requirements, and other factors. The purchases may not be announced in advance and may be made in the open market or in privately negotiated transactions. Cleco Corporation did not purchase any common stock under the repurchase authorization in 2009, 2008, or 2007. There is no expiration date for the program.

Note 8 — Preferred Stock

Within the ESOP, each share of Cleco Corporation 8.125% Convertible Preferred Stock Series of 1991 (ESOP preferred stock) was convertible into 9.6 shares of Cleco Corporation common stock (Cleco common stock). The annual dividend rate on a share of ESOP preferred stock was generally the higher of $8.125 per share or 9.6 times the annual dividend rate for a share of Cleco common stock.

The amount of total capitalization reflected in Cleco Corporation’s Consolidated Financial Statements has been reduced by an amount of deferred compensation expense related to the shares of convertible preferred stock that have not yet been allocated to ESOP participants. For the years 2008 and 2009, no income tax benefit was recorded in Cleco Corporation’s Consolidated Financial Statements.

In March 2007, in order to comply with provisions of the Pension Protection Act of 2006, 190,372 shares of ESOP preferred stock were converted into 1.8 million shares of Cleco common stock. The ESOP trustee holds the newly converted shares of Cleco common stock on behalf of the 401(k) Plan participants. After such conversion, no shares of ESOP preferred stock remain outstanding.

As a result of this conversion, total shareholders’ equity reported on Cleco Corporation’s Consolidated Balance Sheets at December 31, 2007, did not change. Cleco Corporation recorded a $19.1 million reduction in preferred stock with a corresponding increase in common shareholders’ equity.

Upon involuntary liquidation of their stock, preferred shareholders are entitled to receive par value for shares held before any distribution is made to common shareholders. Upon voluntary liquidation, preferred shareholders are entitled to receive the redemption price per share applicable at the time such liquidation occurs, plus any accrued dividends.

Information about the components of preferred stock capitalization is presented in the following table.

	BALANCE					BALANCE				BALANCE				BALANCE
	JAN. 1,					DEC. 31,				DEC. 31,				DEC. 31,
(THOUSANDS, EXCEPT SHARE AMOUNTS)	2007		CHANGE			2007		CHANGE		2008		CHANGE		2009
Cumulative preferred stock, $100 par value
Not subject to mandatory redemption 4.50%	$	1,029	$	-		$	1,029	$	-	$	1,029	$	-	$	1,029
Convertible, Series of 1991, Variable rate		19,063		(19,063	)		-		-		-		-		-
Preferred stock not subject to mandatory redemption	$	20,092	$	(19,063	)	$	1,029	$	-	$	1,029	$	-	$	1,029
Cumulative preferred stock, $100 par value
Number of shares
Authorized		1,491,900		-			1,491,900		-		1,491,900		-		1,491,900
Issued and outstanding		200,922		(190,634	)		10,288		-		10,288		-		10,288
Cumulative preferred stock, $25 par value
Number of shares authorized (None outstanding)		3,000,000		-			3,000,000		-		3,000,000		-		3,000,000

CLECO CORPORATION
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The 4.5% cumulative preferred stock not subject to mandatory redemption has an optional redemption price of $101 per share.

Note 9 — Pension Plan and Employee Benefits

The authoritative guidance for compensation of retirement benefits requires companies to set their measurement date to correspond with their fiscal year end, eliminating the option to use an earlier measurement date. The measurement date provision is effective for fiscal years ending after December 15, 2008. Cleco’s measurement date currently is the same as its fiscal year end; therefore, the measurement date provision had no impact on the Registrants.

Pension Plan and Other Benefits Plan

Most employees hired before August 1, 2007 are covered by a non-contributory, defined benefit pension plan. Benefits under the plan reflect an employee’s years of service, age at retirement, and highest total average compensation for any consecutive five calendar years during the last 10 years of employment with Cleco Corporation. Cleco Corporation’s policy is to base its contributions to the employee pension plan upon actuarial computations utilizing the projected unit credit method, subject to the IRS’s full funding limitation. During 2009, $18.8 million of discretionary contributions were made to the pension plan for the 2008 plan year. Cleco Power expects to be required to make approximately $70.0 million in additional contributions to the pension plan over the next five years, including $4.8 million in 2010. The required contributions are driven by liability funding target percentages set by law which could cause the required contributions to be uneven among the years. The ultimate amount and timing of the contributions will be affected by changes in the discount rate, changes in the funding regulations, and actual returns on fund assets. Cleco Power is considered the plan sponsor, and Support Group is considered the plan administrator.

Cleco Corporation’s retirees and their dependents are eligible to receive medical, dental, vision, and life insurance benefits (other benefits). Cleco Corporation recognizes the expected cost of these benefits during the periods in which the benefits are earned.

The employee pension plan and other benefits obligation plan assets and funded status at December 31, 2009, and 2008, are presented in the following table.

	PENSION BENEFITS						OTHER BENEFITS
(THOUSANDS)	2009			2008			2009			2008
Change in benefit obligation
Benefit obligation at beginning of year	$	278,442		$	248,660		$	34,054		$	32,551
Service cost		7,010			5,879			1,414			1,412
Interest cost		16,454			15,856			2,140			1,981
Plan participants’ contributions		-			-			1,157			1,087
Actuarial loss		6,351			20,333			4,022			77
Expenses paid		(990	)		(1,029	)		-			-
Medicare D		-			-			-	(1)		252
Benefits paid		(11,739	)		(11,257	)		(3,578	)		(3,306	)
Benefit obligation at end of year		295,528			278,442			39,209			34,054
Change in plan assets
Fair value of plan assets at beginning of year		185,562			251,957			-			-
Actual return on plan assets		29,434			(60,109	)		-			-
Employer contributions		18,800			6,000			-			-
Expenses paid		(990	)		(1,029	)		-			-
Benefits paid		(11,739	)		(11,257	)		-			-
Fair value of plan assets at end of year		221,067			185,562			-			-
Unfunded status	$	(74,461	)	$	(92,880	)	$	(39,209	)	$	(34,054	)
(1)No Medicare D reimbursement was received in 2009; $213 was received in January 2010.

The employee pension plan accumulated benefit obligation at December 31, 2009, and 2008, is presented in the following table.

	PENSION BENEFITS
(THOUSANDS)	2009		2008
Accumulated benefit obligation	$	261,817	$	246,931

The authoritative guidelines for compensation of retirement benefits require the disclosure of the net actuarial gains/losses, transition obligations/assets, and prior period service costs included in other comprehensive income as a result of being included as a component of net periodic benefit costs. The following table presents those items for the employee pension plan and other benefits plan at December 31, 2009, and 2008.

	PENSION BENEFITS					OTHER BENEFITS
(THOUSANDS)	2009			2008		2009			2008
Net actuarial loss (gain) occurring during year	$	(3,619	)	$	100,619	$	4,022		$	77
Net actuarial loss amortized during year	$	1,930		$	-	$	(896	)	$	(926	)
Transition obligation occurring during year	$	-		$	-	$	-		$	-
Transition obligation amortized during year	$	-		$	-	$	20		$	20
Prior service credit occurring during year	$	-		$	-	$	-		$	-
Prior service credit amortized during year	$	71		$	71	$	2,065		$	2,065

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The authoritative guidelines also require the disclosure of the net gains/losses, transition obligations/assets, and prior period service costs/credits in accumulated other comprehensive income that have not been recognized as components of net periodic benefit costs and the amounts expected to be recognized in 2010. The following table presents those items for the employee pension plan and other benefits plans for December 31, 2008, 2009, and 2010.

			PENSION BENEFITS						OTHER BENEFITS
(THOUSANDS)	2008		2009		2010		2008		2009		2010
Net actuarial loss	$	113,057	$	107,508	$	3,102	$	10,106	$	13,231	$	1,001	(1)
Transition obligation	$	-	$	-	$	-	$	114	$	94	$	20	(2)
Prior service credit	$	844	$	773	$	71	$	4,291	$	2,227	$	2,021	(3)
(1)Net of the estimated Medicare Part D subsidy of $288. (2)Net of the estimated Medicare Part D subsidy of $0. (3)Net of the estimated Medicare Part D subsidy of $397.

The components of net periodic pension and other benefits cost for 2009, 2008, and 2007 are as follows.

				PENSION BENEFITS									OTHER BENEFITS
(THOUSANDS)	2009			2008			2007			2009			2008			2007
Components of periodic benefit costs
Service cost	$	7,010		$	5,879		$	7,747		$	1,414		$	1,412		$	1,400
Interest cost		16,454			15,856			15,525			2,140			1,981			1,832
Expected return on plan assets		(19,464	)		(20,178	)		(18,980	)		-			-			-
Transition obligation		-			-			-			20			20			20
Prior period service credit (cost)		(71	)		(71	)		845			(2,065	)		(2,065	)		(2,065	)
Net loss		1,930			-			1,961			897			926			928
Net periodic benefit cost	$	5,859		$	1,486		$	7,098		$	2,406		$	2,274		$	2,115

Since Cleco Power is the pension plan sponsor and the related trust holds the assets, the prepaid benefit cost of the pension plan is reflected at Cleco Power. The liability of Cleco Corporation’s other subsidiaries is transferred, with a like amount of assets, to Cleco Power monthly. The expense of the pension plan related to Cleco Corporation’s other subsidiaries for the years ended December 31, 2009, 2008, and 2007 was $1.8 million, $1.5 million, and $2.0 million, respectively.

Cleco Corporation is the plan sponsor for the other benefit plans. There are no assets set aside in a trust, and the liabilities are reported on the individual subsidiaries’ financial statements. At December 31, 2009 and 2008, the current portion of the other benefits liability for Cleco was $2.8 million and $2.6 million, respectively. At December 31, 2009 and 2008, the current portion of the other benefits liability for Cleco Power was $2.7 million and $2.4 million, respectively. The expense related to other benefits reflected in Cleco Power’s Consolidated Statements of Income for the years ended December 31, 2009, 2008, and 2007 was $2.4 million, $2.2 million, and $2.1 million, respectively, net of Medicare Part D subsidy of $0.3 million, $0.3 million, and $0.3 million, respectively. Cleco Power’s allocated amount of the other benefit liability was $30.6 million and $26.4 million at December 31, 2009, and 2008, respectively.

The measurement date used to determine the pension and other postretirement benefits is December 31. The assumptions used to determine the benefit obligation and the periodic costs are as follows.

	PENSION BENEFITS		OTHER BENEFITS
	2009	2008	2009	2008
Weighted-average assumptions used to determine the benefit obligation as of December 31:
Discount rate	5.91%	6.01%	5.29%	6.27%
Rate of compensation increase	4.45%	4.54%	N/A	N/A

		PENSION BENEFITS			OTHER BENEFITS
	2009	2008	2007	2009	2008	2007
Weighted-average assumptions used to determine the net benefit cost (income) for the year ended December 31:
Discount rate	6.01%	6.48%	5.90%	6.27%	6.18%	5.90%
Expected return on plan assets	7.80%	8.40%	8.40%	N/A	N/A	N/A
Rate of compensation increase	4.45%	4.54%	4.56%	N/A	N/A	N/A

The expected return on plan assets was determined by examining the risk profile of each target category as compared to the expected return on that risk, within the parameters determined by the retirement committee. The result was also compared to the expected rate of return of other comparable plans. In assessing the risk as compared to return profile, historical returns as compared to risk was considered. The historical risk compared to returns was adjusted for the expected future long-term relationship between risk and return. The adjustment for the future risk compared to returns was, in part, subjective and not based on any measurable or observable events.

Employee pension plan assets may be invested in publicly traded domestic common stocks, including Cleco Corporation common stock; U.S. Government, federal agency and corporate obligations; an international equity fund, commercial real estate funds; a hedge fund-of-funds; and pooled temporary investments. Investments in securities (obligations of U.S. Government and U.S. Government Agencies, corporate debt, common/collective trust funds, mutual funds, common stocks, and preferred stock) traded on a national securities exchange

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are valued at the last reported sales price on the last business day of the year.

Real estate funds and the pooled separate accounts are stated at estimated market value based on appraisal reports prepared annually by independent real estate appraisers (members of the American Institute of Real Estate Appraisers). The estimated market value of recently acquired properties is assumed to approximate cost.

The hedge fund-of-funds is stated at fair value based upon financial statements and other financial information reported by the management of the underlying funds. In January 2009, the relationship with the hedge fund-of-funds manager was restructured to redemption status only.

The authoritative guidance for fair value measurements and disclosures requires entities to classify assets and liabilities measured at their fair value according to three different levels, depending on the inputs used in determining fair value.

§	Level 1 – unadjusted quoted prices in active, liquid markets for the identical asset or liability;

§	Level 2 – quoted prices for similar assets and liabilities in active markets or other inputs that are observable for the asset or liability, including inputs that can be corroborated by observable market data, observable interest rate yield curves and volatilities;

§	Level 3 – unobservable inputs based upon the entities own assumptions.

The table below discloses the pension plan’s fair value of financial assets measured on a recurring basis and within the scope of the authoritative guidance for fair value measurements and disclosures.

(THOUSANDS)	AT DECEMBER 31, 2009		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)
Asset Description
Cash and cash equivalents	$	9,679	$	-	$	9,679	$	-
Common stock		27,096		-		27,096		-
Preferred stock		10,234		-		1,124		9,110
Obligations of U.S. Government and U.S. Government Agencies		24,763		-		24,763		-
Mutual funds		70,612		70,555		57		-
Common/collective trust fund		36,727		283		36,271		173
Real estate funds		4,517		-		-		4,517
Hedge fund-of-funds		6,529		-		-		6,529
Corporate debt		33,737		-		33,737		-
Total	$	223,894	$	70,838	$	132,727	$	20,329

		Net liability for pending transactions	$ (3,238)
		Interest accrual	411
		Total net assets	$ 221,067

Level 3 valuations are derived from other valuation methodologies including pricing models, discounted cash flow models and similar techniques. Level 3 valuations incorporate subjective judgments and consider assumptions including capitalization rates, discounts rates, cash flows and other factors that are not observable in the market.

The following is a reconciliation of the beginning and ending balances of the pension plan’s preferred stock, common/collective trust fund, real estate funds, and hedge fund-of-funds measured at fair value on a recurring basis using significant unobservable inputs (Level 3) during the year ended December 31, 2009.

(THOUSANDS)	PREFERRED STOCK			COMMON/ COLLECTIVE TRUST			REAL ESTATE FUNDS			HEDGE FUND OF FUNDS			TOTAL
December 31, 2008	$	12,992		$	149		$	5,741		$	12,223		$	31,105
Realized (loss) gain		-			-			-			(27	)		(27	)
Unrealized (loss) gain		(4,333	)		30			(1,224	)		499			(5,028	)
Purchases, issuances, and settlements, net		451			(6	)		-			(6,166	)		(5,721	)
December 31, 2009	$	9,110		$	173		$	4,517		$	6,529		$	20,329

The market-related value of plan assets differs from the fair value of plan assets by the amount of deferred asset gains or losses. Actual asset returns that differ from the expected return on plan assets are deferred and recognized in the market-related value of assets on a straight-line basis over a five-year period. For 2009, the return on plan assets was 16.0% compared to an expected long-term return of 7.8%. The 2008 return on pension plan assets was (26.9)% compared to an expected long-term return of 8.4%.

As of December 31, 2009, the pension plan held no shares of Cleco Corporation common stock. None of the plan participants’ future annual benefits is covered by insurance contracts. As a result of the significant 2008 market declines, the pension plan portfolio experienced significant losses during 2008 that resulted in a significant decrease in the funded status of the plan for 2008. These losses, in conjunction with funding requirements, may lead to increased or earlier contributions than previously anticipated. In December 2008, Cleco became aware that, through its hedge fund-of-funds manager, a portion of its pension plan assets were invested in the Madoff feeder fund investment, Ascot Fund Limited. The total losses associated with this fund were approximately $0.7

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million. In January 2009, Cleco Power elected to liquidate the holdings of the hedge fund-of-funds manager. Proceeds from the hedge fund-of-funds manager will be reallocated to the plan’s other equity managers.

Cleco Corporation’s retirement committee has established investment performance objectives of the pension plan assets. Over a three- to five-year period, the objectives are for the pension plan’s annualized total return to:

§	Exceed the assumed rate of return on plan assets;

Exceed the annualized total return of a customized index consisting of a mixture of Standard & Poor’s 500 Index; Russell Mid Cap Value Index; Morgan Stanley Capital International Europe, Australia, Far East Index; Lehman Brothers U.S. Universal Index; and the median real estate manager performance in the Hewitt Investment Group open end real estate universe; and

§	Rank in the upper 50 percent of a universe of composite pension funds.

In order to meet the objectives and to control risk, the retirement committee has established guidelines that the investment managers must follow.

Domestic Equity Portfolios

§	Equity holdings of a single company must not exceed 10% of the manager’s portfolio.

§	A minimum of 25 stocks should be owned.

§	Equity holdings in a single sector should not exceed the lesser of three times the sector’s weighting in the Standard & Poor’s 500 Index or 35% of the portfolio.

International Equity Portfolios

§	Equity holdings of a single company should not exceed 5% of the manager’s portfolio.

§	A minimum of 30 stocks should be owned.

§	Equity holdings in a single sector should not exceed 35%.

§	Currency hedging decisions are at the discretion of the investment manager.

Debt Portfolios

§	At least 85% of the debt securities should be investment grade securities (BBB- by Standard & Poor’s or Baa3 by Moody’s) or higher.

§	Bond purchases should be limited to readily marketable securities.

Real Estate Portfolios

§	Real estate funds should be invested primarily in direct equity positions, with debt and other investments representing less than 25% of the fund.

§	Leverage should be less than 70% of the market value of the fund.

§	Investments should be focused on existing income-producing properties, with land and development properties representing less than 40% of the fund.

Hedge Fund-of-Funds

§	The fund should be invested in a minimum of 20 individual partnerships.

§	No individual partnership should exceed 10% of the fund-of-funds.

The fund should be diversified across several different “styles” of partnerships, including event-driven strategies, fixed income arbitrage and trading, and other arbitrage strategies. The fund generally should not be invested in emerging markets, short-term only, traditional Commodity Trading Advisor’s or derivative-only strategies.

Fund managers were allowed limited use of derivatives, subject to policies and guidelines established by the committee and to the following restrictions:

§	Derivatives may be used only if the vehicle is deemed by the manager to be more attractive than a similar investment in the underlying cash market; or if the vehicle is being used to manage risk of the portfolio.

§	The derivatives may not be used in a speculative manner or to leverage the portfolio.

§	The derivatives may not be used as short-term trading vehicles.

Investment managers shall alert the Retirement Committee, in writing, before engaging in strategies which use derivatives. The written communication shall include the nature and purpose of the strategy, a quantification of the magnitude of the program in absolute dollar terms, an outline of the methods to be used to monitor the program, and an outline of the process to be followed in reporting on commitments relative to established guidelines and on the success of the proposed strategy.

Due to the nature of the hedge fund-of-funds, its manager was exempt from the above derivative policy.

The Retirement Committee has established the following investment asset allocation target percentages for the pension plan assets.

	PERCENT OF TOTAL PLAN ASSETS*
	MINIMUM	TARGET	MAXIMUM
Equity
Domestic	39%	47%	55%
International	13%	18%	23%
Total equity	60%	65%	70%
Debt securities	18%	23%	28%
Real estate	4%	7%	10%
Hedge fund-of-funds	2%	5%	8%
Cash equivalents	0%	0%	5%
*Minimums and maximums within subcategories not intended to equal total for category.

The estimated impact of future Medicare subsidies reduced the January 1, 2009, and 2008, accumulated postretirement benefit obligation by $6.2 million and $5.8 million, respectively, and reduced the other benefit costs for the twelve months ended December 31, 2009, and 2008, as follows.

103

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

	AT DECEMBER 31,
(THOUSANDS)	2009			2008
Components of other benefit costs:
Reduction in service cost	$	149		$	139
Reduction in interest cost		335			299
Reduction in net loss amortization		303			304
Reduction in prior period service cost amortization		(397	)		(397	)
Reduction in net other benefit cost	$	390		$	345

The assumed health care cost trend rates used to measure the expected cost of other benefits was $9.0% in 2010, 2009, and 2008. The rate declines to 5.0% by 2028 and remains at 5.0% thereafter. Assumed health care cost trend rates have a significant effect on the amount reported for the health care plans. A one-percentage point change in assumed health care cost trend rates would have the following effects on other benefits.

	ONE-PERCENTAGE POINT
(THOUSANDS)	INCREASE		DECREASE
Effect on total of service and interest cost components	$	32	$	104
Effect on postretirement benefit obligation	$	340	$	1,401

The projected benefit payments and projected receipts pursuant to Medicare Part D subsidy, the employee pension plan, and other benefits obligation plan for each year through 2014 and the next five years thereafter are listed below.

(THOUSANDS)	2010		2011		2012		2013		2014		NEXT FIVE YEARS
Pension plan	$	12,206	$	12,657	$	13,221	$	13,910	$	14,687	$	89,622
Other benefits obligation plan, gross	$	3,228	$	3,455	$	3,646	$	3,841	$	4,112	$	23,261
Medicare Part D subsidy receipts	$	312	$	353	$	403	$	457	$	501	$	3,154

SERP

Certain Cleco executive officers are covered by the SERP. The SERP is a non-qualified, non-contributory, defined benefit pension plan. Benefits under the plan reflect an employee’s years of service, age at retirement, and the sum of the highest base salary paid out of the last five calendar years and the average of the three highest bonuses paid during the 60 months prior to retirement, reduced by benefits received from any other defined benefit pension plan, SERP Plan or Cleco contributions under the enhanced 401(k) Plan to the extent such contributions exceed the limits of the 401(k) Plan. Cleco Corporation does not fund the SERP liability, but instead pays for current benefits out of the general funds available. Cleco Power has formed a Rabbi Trust designated as the beneficiary for life insurance policies issued on the SERP participants. Proceeds from the life insurance policies are expected to be used to pay the SERP participants’ life insurance benefits, as well as future SERP benefit payments. However, since SERP is a non-qualified plan, the assets of the trust could be used to satisfy general creditors of Cleco Power in the event of insolvency. All SERP benefits are paid out of the general cash available of the respective companies from which the officer retired. No contributions to the SERP were made during the three-year period ended December 31, 2009. Cleco Power is considered the plan sponsor, and Support Group is considered the plan administrator.

The SERP’s funded status at December 31, 2009, and 2008, is presented in the following table.

	SERP BENEFITS
(THOUSANDS)	2009			2008
Change in benefit obligation
Benefit obligation at beginning of year	$	33,223		$	29,757
Service cost		1,608			1,395
Interest cost		2,015			1,898
Actuarial loss		1,935			1,744
Benefits paid		(1,554	)		(1,571	)
Benefit obligation at end of year	$	37,227		$	33,223

The SERP’s accumulated benefit obligation at December 31, 2009, and 2008, is presented in the following table.

	SERP BENEFITS
(THOUSANDS)	2009		2008
Accumulated benefit obligation	$	34,122	$	30,180

The authoritative guidelines on compensation for retirement benefits require the disclosure of the net actuarial gains/losses, transition obligations/assets, and prior period service costs included in other comprehensive income as a result of being amortized as a component of net periodic benefit costs. The following table presents those items for the SERP at December 31, 2009, and 2008.

	SERP BENEFITS
(THOUSANDS)	2009		2008
Net actuarial loss occurring during year	$	1,935	$	1,745
Net actuarial loss amortized during year	$	777	$	656
Prior service cost amortized during year	$	54	$	54

The authoritative guidelines on compensation for retirement benefits also require the disclosure of the net gains/losses, transition obligations/assets, and prior period service costs/credit in accumulated other comprehensive income that have not been recognized as components of net periodic benefit costs and the amounts expected to be recognized in 2010. The following table presents those items for SERP for December 31, 2010, 2009, and 2008.

			SERP BENEFITS
(THOUSANDS)	2010		2009		2008
Net actuarial loss	$	884	$	12,015	$	10,858
Prior service cost	$	54	$	441	$	494

The components of the net SERP cost for 2009, 2008, and 2007 are as follows.

			SERP BENEFITS
(THOUSANDS)	2009		2008		2007
Components of periodic benefit costs
Service cost	$	1,608	$	1,395	$	1,435
Interest cost		2,015		1,898		1,778
Prior period service cost amortization		54		54		54
Net loss amortization		777		656		1,016
Net periodic benefit cost	$	4,454	$	4,003	$	4,283

104

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

The measurement date used to determine the SERP benefits is December 31. The assumptions used to determine the benefit obligation and the periodic costs are as follows.

	SERP
	2009	2008
Weighted-average assumptions used to determine the benefit obligation as of December 31:
Discount rate	5.78%	6.15%
Rate of compensation increase	5.00%	5.00%

		SERP
	2009	2008	2007
Weighted-average assumptions used to determine the net benefit cost (income) for the year ended December 31:
Discount rate	6.15%	6.48%	5.90%
Rate of compensation increase	5.00%	5.00%	5.00%

The liabilities of the SERP are reported on the individual subsidiaries’ financial statements. At December 31, 2009 and 2008, the current portion of the SERP liability for Cleco was $1.8 million and $1.7 million, respectively. At December 31, 2009 and 2008, the current portion of the SERP liability for Cleco Power was $0.6 million. The expense related to the SERP reflected on Cleco Power’s Consolidated Statements of Income for the years ended December 31, 2009, 2008, and 2007 was $1.1 million, $1.0 million, and $1.1 million, respectively. Cleco Power’s allocated amount of the SERP liability was $12.9 million and $12.1 million at December 31, 2009, and 2008, respectively.

The projected benefit payments for the SERP for each year through 2014 and the next five years thereafter are listed below.

(THOUSANDS)		2010				2011				2012				2013				2014				NEXT FIVE YEARS
SERP		$	1,787			$	2,028			$	2,147			$	2,389			$	2,424			$	14,301

401(k)/ESOP Plan

Most employees are eligible to participate in the 401(k) Plan, which was amended in April 1991 to include a leveraged ESOP. The ESOP was established with 300,000 convertible preferred shares which served as Cleco Corporation’s match to employees’ 401(k) Plan contributions and funded dividend payments on allocated shares. By late March 2006, substantially all of the ESOP preferred shares were fully allocated to current and former 401(k) Plan participants. Beginning January 2007, Cleco Corporation made matching contributions and funded dividend reinvestments with Cleco Corporation common stock. In March 2007, the ESOP trustee converted all outstanding 190,372 shares of ESOP preferred stock into 1.8 million shares of Cleco Corporation common stock. Beginning January 2008, Cleco Corporation made matching contributions and funded dividend reinvestments with cash.

The table below contains information about the 401(k) Plan and the ESOP.

	FOR THE YEAR ENDED DECEMBER 31,
(THOUSANDS)	2009		2008		2007
401(k) Plan expense	$	3,751	$	3,427	$	2,774
Dividend requirements to ESOP on convertible preferred stock	$	-	$	-	$	412

Cleco Power is the plan sponsor for the 401(k) Plan. The expense of the 401(k) Plan related to Cleco Corporation’s other subsidiaries was $1.0 million, $1.0 million, and $0.7 million for the years ended December 31, 2009, 2008, and 2007, respectively. The expense related to the dividend requirements of the ESOP on convertible preferred stock is reflected on Cleco Corporation’s Consolidated Statements of Income for the year ended December 31, 2007.

Note 10 — Income Taxes

Cleco

For the years ended December 31, 2009, 2008, and 2007, income tax expense was less than the amount computed by applying the statutory federal rate to income before tax. The differences are as follows.

	FOR THE YEAR ENDED DECEMBER 31,
(THOUSANDS, EXCEPT FOR %)	2009			2008			2007
Income before tax	$	115,886		$	120,598		$	222,561
Statutory rate		35.0	%		35.0	%		35.0	%
Tax at federal statutory rate	$	40,560		$	42,209		$	77,897
Increase (decrease):
Plant differences, including AFUDC flowthrough	$	(30,212	)	$	(27,208	)	$	(14,498	)
Amortization of investment tax credits	$	(1,332	)	$	(1,380	)	$	(1,435	)
State tax expense	$	4,763		$	7,506		$	12,549
Other	$	(4,200	)	$	(2,670	)	$	(3,741	)
Total taxes	$	9,579		$	18,457		$	70,772
Effective Rate		8.3	%		15.3	%		31.8	%

Information about current and deferred income tax expense is as follows.

	FOR THE YEAR ENDED DECEMBER 31,
(THOUSANDS)	2009			2008			2007
Current federal income tax expense	$	16,080		$	9,931		$	58,227
Deferred federal income tax (benefit) expense		(9,880	)		(1,850	)		3,617
Amortization of accumulated deferred investment tax credits		(1,332	)		(1,380	)		(1,435	)
Total federal income tax expense		4,868			6,701			60,409
Current state income tax expense		814			4,751			7,799
Deferred state income tax expense		3,897			7,005			2,564
Total state income tax expense		4,711			11,756			10,363
Total federal and state income tax expense		9,579			18,457			70,772
Items charged or credited directly to stockholders’ equity
Federal deferred		(1,200	)		(751	)		(500	)
State deferred		(194	)		(121	)		(81	)
Total tax benefit from items charged directly to stockholders’ equity		(1,394	)		(872	)		(581	)
Total federal and state income tax expense	$	8,185		$	17,585		$	70,191

105

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

The balance of accumulated deferred federal and state income tax assets and liabilities at December 31, 2009, and 2008, was comprised of the tax effect of the following.

				AT DECEMBER 31,
(THOUSANDS)	2009			2008
Depreciation and property basis differences	$	(463,833	)	$	(405,967	)
Fuel costs		(13,215	)		(24,102	)
Mark-to-market		3,068			21,961
Deferred carrying charges		55,033			32,104
SERP – other comprehensive income		8,840			7,446
Regulated operations regulatory asset (liability)		(75,363	)		(68,587	)
Postretirement benefits other than pension		9,068			25,233
Other		22,307			(26,751	)
Accumulated deferred federal and state income taxes	$	(454,095	)	$	(438,663	)

A portion of the deferred tax assets are the result of capital loss carryforwards which, if utilized, will result in tax benefits of $7.4 million. If the capital loss carryforwards are not utilized, $4.1 million will expire in 2011, $1.5 million will expire in 2013, and $1.8 million will expire in 2014. In addition, Cleco has a deferred tax asset resulting from new market tax credit carryforwards of $26.8 million that, if not utilized, will expire in 2029.

Management considers it more likely than not that all deferred tax assets will be realized. Consequently, deferred tax assets have not been reduced by a valuation allowance.

Cleco Power

Income tax expense is less than the amount computed by applying the statutory rate to income before tax, as follows.

	FOR THE YEAR ENDED DECEMBER 31,
(THOUSANDS, EXCEPT FOR %)	2009			2008			2007
Income before tax	$	126,463		$	141,788		$	114,286
Statutory rate		35.0	%		35.0	%		35.0	%
Tax at federal statutory rate	$	44,262		$	49,625		$	40,000
Increase (decrease):
Plant differences, including AFUDC flowthrough	$	(30,212	)	$	(27,208	)	$	(14,498	)
Amortization of investment tax credits	$	(1,332	)	$	(1,380	)	$	(1,435	)
State tax expense	$	5,131		$	8,243		$	8,784
Other	$	(2,552	)	$	(1,324	)	$	(3,238	)
Total tax expense	$	15,297		$	27,956		$	29,613
Effective Rate		12.1	%		19.7	%		25.9	%

Information about current and deferred income tax expense is as follows.

	FOR THE YEAR ENDED DECEMBER 31,
(THOUSANDS)	2009			2008			2007
Current federal income tax expense	$	11,920		$	10,274		$	42,099
Deferred federal income tax expense (benefit)		912			5,920			(15,762	)
Amortization of accumulated deferred investment tax credits		(1,332	)		(1,380	)		(1,435	)
Total federal income tax expense		11,500			14,814			24,902
Current state income tax expense		1,480			4,580			5,076
Deferred state income tax expense (benefit)		2,317			8,562			(365	)
Total state income tax expense		3,797			13,142			4,711
Total federal and state income taxes	$	15,297		$	27,956		$	29,613
Items charged or credited directly to stockholders’ equity
Federal deferred		(620	)		(416	)		(159	)
State deferred		(100	)		(67	)		(26	)
Total tax benefit from items charged directly to stockholders’ equity		(720	)		(483	)		(185	)
Total federal and state income tax expense	$	14,577		$	27,473		$	29,428

The balance of accumulated deferred federal and state income tax assets and liabilities at December 31, 2009, and 2008, was comprised of the tax effect of the following.

				AT DECEMBER 31,
(THOUSANDS)	2009			2008
Depreciation and property basis differences	$	(427,524	)	$	(360,932	)
Fuel costs		(13,228	)		(24,102	)
Mark-to-market		2,851			21,744
Deferred carrying charges		55,044			32,104
SERP - other comprehensive income		4,960			4,239
Regulated operations regulatory asset (liability)		(75,363	)		(68,587	)
Postretirement benefits other than pension		(2,832	)		11,860
Other		8,055			(20,707	)
Accumulated deferred federal and state income taxes	$	(448,037	)	$	(404,381	)

Management considers it more likely than not that all deferred tax assets will be realized. Consequently, deferred tax assets have not been reduced by a valuation allowance.

Uncertain Tax Positions

Effective January 1, 2007, Cleco adopted the provisions of the authoritative guidance on accounting for uncertain tax positions. With this adoption, Cleco classified all interest related to uncertain tax positions as a component of interest payable and interest expense. The total amount of interest associated with tax positions at December 31, 2009, 2008, and 2007, recognized on Cleco Corporation’s Consolidated Balance Sheets was $40.5 million, $26.3 million, and $18.3 million, respectively. The total amount of interest associated with tax positions at December 31, 2009, 2008, and 2007, recognized on Cleco Power’s Balance Sheets was $22.2 million, $15.9 million, and $10.3 million, respectively. The total amount of interest expense related to uncertain tax positions for the years ended December 31, 2009, 2008, and 2007, recognized on

106

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

the income statements of Cleco Corporation was $8.2 million, $3.2 million, and $4.1 million, respectively. The total amount of interest expense related to uncertain tax positions for the years ended December 31, 2009, 2008, and 2007, recognized on the income statements of Cleco Power was $3.3 million, $0.8 million, and $0.1 million, respectively. The total liability for unrecognized tax benefits for Cleco Corporation and Cleco Power at December 31, 2009, 2008, and 2007 is shown in the following table:

Cleco

(THOUSANDS)	LIABILITY FOR UNRECOGNIZED TAX BENEFITS
Balance at January 1, 2007	$	62,319
Reduction for tax positions of current period		(3,176	)
Additions for tax positions of prior years		32,074
Reduction for tax positions of prior years		(14,965	)
Reduction for lapse of statute of limitations		-
Balance at December 31, 2007	$	76,252
Reduction for tax positions of current period		(4,367	)
Additions for tax positions of prior years		13,033
Reduction for tax positions of prior years		-
Reduction for lapse of statute of limitations		-
Balance at December 31, 2008	$	84,918
Reduction for tax positions of current period		(15,126	)
Additions for tax positions of prior years		59,443
Reduction for tax positions of prior years		-
Reduction for lapse of statute of limitations		-
Balance at December 31, 2009	$	129,235

Cleco Power

(THOUSANDS)	LIABILITY FOR UNRECOGNIZED TAX BENEFITS
Balance at January 1, 2007	$	30,857
Reduction for tax positions of current period		(3,276	)
Additions for tax positions of prior years		32,074
Reduction for tax positions of prior years		(9,563	)
Reduction for lapse of statute of limitations		-
Balance at December 31, 2007	$	50,092
Reduction for tax positions of current period		(2,589	)
Additions for tax positions of prior years		13,033
Reduction for tax positions of prior years		-
Reduction for lapse of statute of limitations		-
Balance at December 31, 2008	$	60,536
Reduction for tax positions of current period		(11,499	)
Additions for tax positions of prior years		35,323
Reduction for tax positions of prior years		-
Reduction for lapse of statute of limitations		-
Balance at December 31, 2009	$	84,360

In the first quarter of 2008, Cleco and the IRS agreed to apply industry-wide guidelines as the basis for settling a potential dispute regarding the amount of indirect overhead costs required to be capitalized for tax purposes. Based on acceptance of the settlement guidelines, Cleco recorded, in the first quarter of 2008, an estimated interest benefit of approximately $2.1 million.

The federal income tax years that remain subject to examination by the IRS are 2001 through 2008. The Louisiana state income tax years that remain subject to examination by the Louisiana Department of Revenue are 2000 through 2008.

During the twelve months ended December 31, 2009, there were no decreases in unrecognized tax benefits relating to settlements or a lapse of the applicable statute of limitation. Cleco is currently under audit by the IRS which has proposed adjustments to tax for issues such as depreciable tax lives, deductible storm costs, and deductible indirect overhead costs. Cleco estimates that it is reasonably possible that the balance of unrecognized tax benefits as of December 31, 2009 could decrease by a maximum of $55.0 million in the next twelve months as a result of reaching a settlement with the IRS. The settlement could involve the payment of additional taxes, the adjustment of deferred taxes, and/or the recognition of tax benefits. Cleco does not expect that any of these changes will have a material impact on its annual effective tax rate.

Note 11 — Disclosures about Segments

Cleco

Cleco’s reportable segments are based on its method of internal reporting, which disaggregates business units by first-tier subsidiary. Cleco’s reportable segments are Cleco Power and Midstream. The reconciling items in the following tables consist of the holding company, a shared services subsidiary, two transmission interconnection facilities, and an investment subsidiary.

Each reportable segment engages in business activities from which it earns revenue and incurs expenses. Segment managers report periodically to Cleco’s Chief Executive Officer (the chief operating decision-maker) with discrete financial information and, at least quarterly, present discrete financial information to Cleco Corporation’s Board of Directors. Each reportable segment prepared budgets for 2009 that were presented to and approved by Cleco Corporation’s Board of Directors.

The financial results of Cleco’s segments are presented on an accrual basis. Management evaluates the performance of its segments and allocates resources to them based on segment profit and the requirements to implement new strategic initiatives and projects to meet current business objectives. Material intercompany transactions occur on a regular basis. These intercompany transactions relate primarily to joint and common administrative support services provided by Support Group. For information on these services, see Note 17 — “Affiliate Transactions.”

107

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

SEGMENT INFORMATION

2009 (THOUSANDS)	CLECO POWER		MIDSTREAM			RECONCILING ITEMS			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	808,646	$	-		$	-		$	-		$	808,646
Other operations		33,558		1			102			(10	)		33,651
Affiliate revenue		23		8,748			2,690			-			11,461
Intercompany revenue		1,372		-			43,618			(44,990	)		-
Operating revenue, net	$	843,599	$	8,749		$	46,410		$	(45,000	)	$	853,758
Depreciation expense	$	77,064	$	177		$	963		$	-		$	78,204
Interest charges	$	58,562	$	7,408		$	(9,717	)	$	(5,198	)	$	51,055
Interest income	$	1,449	$	-		$	5,261		$	(5,198	)	$	1,512
Equity (loss) income from investees	$	-	$	(19,339	)	$	1,916		$	-		$	(17,423	)
Federal and state income tax expense (benefit)	$	15,297	$	(11,027	)	$	5,309		$	-		$	9,579
Segment profit (loss)(1)	$	111,166	$	(17,730	)	$	12,871		$	-		$	106,307
Additions to long-lived assets	$	235,385	$	55		$	980		$	-		$	236,420
Equity investment in investees	$	12,873	$	223,652		$	15,093		$	(1	)	$	251,617
Total segment assets	$	3,363,962	$	270,713		$	383,058		$	(322,886	)	$	3,694,847
(1) Reconciliation of segment profit to consolidated profit:	Segment profit								$	106,307
	Unallocated items:
	Preferred dividends requirements									46
	Net income applicable to common stock								$	106,261

2008 (THOUSANDS)	CLECO POWER		MIDSTREAM			RECONCILING ITEMS			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	1,032,970	$	-		$	-		$	-		$	1,032,970
Other operations		36,675		1			104			(12	)		36,768
Affiliate revenue		29		7,920			2,511			-			10,460
Intercompany revenue		2,008		-			41,615			(43,623	)		-
Operating revenue, net	$	1,071,682	$	7,921		$	44,230			(43,635	)	$	1,080,198
Depreciation expense	$	76,420	$	307		$	1,149		$	-		$	77,876
Interest charges	$	47,283	$	6,978		$	5,130		$	(6,991	)	$	52,400
Interest income	$	3,943	$	-		$	8,463		$	(6,989	)	$	5,417
Equity (loss) income from investees	$	-	$	(7,037	)	$	1,495		$	-		$	(5,542	)
Federal and state income tax expense	$	27,956	$	(7,182	)	$	(2,317	)	$	-		$	18,457
Segment profit (loss) (1)	$	113,832	$	(10,017	)	$	(1,674	)	$	-		$	102,141
Additions to long-lived assets	$	321,407	$	64		$	1,041		$	-		$	322,512
Equity investment in investees	$	-	$	234,273		$	14,871		$	-		$	249,144
Total segment assets	$	3,041,597	$	250,882		$	324,232		$	(275,507	)	$	3,341,204
(1) Reconciliation of segment profit to consolidated profit:	Segment profit								$	102,141
	Unallocated items:
	Preferred dividends requirements									46
	Net income applicable to common stock								$	102,095

108

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

2007 (THOUSANDS)	CLECO POWER		MIDSTREAM		RECONCILING ITEMS		ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	988,193	$	-	$	-	$	-		$	988,193
Other operations		35,176		16		108		(15	)		35,285
Affiliate revenue		42		5,050		2,046		-			7,138
Intercompany revenue		2,008		-		43,063		(45,071	)		-
Operating revenue, net	$	1,025,419	$	5,066	$	45,217	$	(45,086	)	$	1,030,616
Depreciation expense	$	78,522	$	306	$	1,076	$	-		$	79,904
Interest charges	$	29,565	$	19,053	$	8,265	$	(18,917	)	$	37,966
Interest income	$	5,422	$	1,047	$	24,197	$	(18,912	)	$	11,754
Equity income from investees	$	-	$	91,581	$	1,567	$	-		$	93,148
Federal and state income tax expense	$	29,613	$	36,585	$	4,712	$	(138	)	$	70,772
Segment profit (1)	$	84,673	$	59,317	$	7,799	$	-		$	151,789
Additions to long-lived assets	$	492,445	$	10	$	984	$	-		$	493,439
Equity investment in investees	$	-	$	249,758	$	8,342	$	1		$	258,101
Total segment assets	$	2,306,482	$	265,918	$	459,139	$	(324,916	)	$	2,706,623
(1) Reconciliation of segment profit to consolidated profit:	Segment profit						$	151,789
	Unallocated items:
	Preferred dividends requirements							458
	Net income applicable to common stock						$	151,331

Cleco Power

Cleco Power is a vertically integrated, regulated electric utility operating within Louisiana and is viewed as one unit by management. Discrete financial reports are prepared only at the company level. This approach is consistent with the standards applicable to segment reporting as defined by the authoritative guidance on segment reporting.

Note 12 — Electric Customer Credits

Beginning in 1996, the amount of Cleco Power’s yearly retail earnings has been subject to the terms of a RSP established by Cleco Power and the LPSC in a 1996 earnings review settlement. The 1996 RSP establishes a target return on common equity and requires all or a portion of regulated earnings for each yearly review period above the targeted regulatory rate of return on equity to be credited to Cleco Power’s customers.

The terms of the 1996 RSP were approved by the LPSC in July 2006, and became effective October 1, 2006, in accordance with Cleco Power’s request to extend the RSP to the commercial operation date of Rodemacher Unit 3, which was February 12, 2010. The 2006 RSP allowed Cleco Power the opportunity to earn a maximum regulated return on equity of 11.65%. This maximum return was based on a return on equity of 11.25%, with any regulated earnings between 11.25% and 12.25% shared between shareholders and customers in a 40/60 ratio. All regulated earnings over 12.25% will be returned to customers. The amount of credits due customers, if any, is determined by Cleco Power and the LPSC annually, based on results for each 12-month period ended September 30. The current RSP terms require the credits to be included on customers’ bills the following summer.

The terms of the original 1996 LPSC RSP settlement, effective through September 30, 2006, allowed Cleco Power to retain all regulated earnings up to a 12.25% return on equity, and to share equally with customers, as credits on their bills, all regulated earnings between 12.25% and 13% return on equity. All regulated earnings above a 13% return on equity were credited to customers. This effectively allowed Cleco Power the opportunity to realize a regulatory rate of return up to 12.625%.

Cleco’s reported earnings for the 12-month period ended December 31, 2006, increased due to reversals of previously accrued credits of $4.7 million.

The $4.7 million reversal of previously accrued credits mentioned above was the result of two events. The first event was the April 2006 settlement of issues raised in the LPSC’s review of Cleco Power’s RSP filings for the 12-month periods ended September 30, 2002, 2003, and 2004. Based on the terms of the settlement, Cleco Power reversed previously accrued customer credits of $3.2 million in the first quarter of 2006, and refunded $1.3 million as credits on customers’ September 2006 utility bills. In this proceeding, the LPSC also reserved the right to further review Cleco Power’s calculation of working capital included in the filings. Cleco Power reached an agreement of the working capital issue with the LPSC, reversed previously accrued customer credits of $0.3 million in December 2006, and refunded an additional $3.2 million of previously accrued credits to customers in March 2007.

The second event was the April 2006 filing by Cleco Power of its required RSP monitoring report for the 12-month period ended September 30, 2005. Based on the reassessment of amounts filed in this monitoring report, the results of the Staff’s review as discussed above, and projections for the year 2006, Cleco Power reversed in the first quarter of 2006, an additional $1.2 million of customer credits previously accrued for the 12-months ended September 30, 2005, and 2006.

The Staff completed the review of Cleco Power’s RSP monitoring reports for the 12-month periods ended September 30, 2005 and 2006, during 2007. The Staff’s reports indicated that no customer refunds were due for these periods based on the filings. In January 2008, Cleco Power filed its monitoring report for the 12-month period ended September 30, 2007.

In November 2009, the Staff completed their review of the September 30, 2007 monitoring report. The Staff’s reports

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indicated that no customer refunds were due for this period based on the filings.

In June 2009, Cleco Power filed its monitoring report for the 12-month period ended September 30, 2008. In January 2010, the Staff completed its review and indicated no customer refunds were due for this period. In January 2010, Cleco Power also filed its monitoring report for the 12-month period ended September 30, 2009, and Cleco Power anticipates the LPSC will complete its review in the first quarter of 2010.

Cleco Power’s Consolidated Balance Sheets at December 31, 2009, and 2008 reflect the following accruals for estimated electric customer credits.

	AT DECEMBER 31,
(THOUSANDS)	2009		2008
Provision for rate refund	$	2	$	2
Other deferred credits		-		1,933
Total customer credits	$	2	$	1,935

The amounts reported under the line item other deferred credits relate to potential fuel audit issues and currently are not due. All customer credits relating to Cleco Power’s RSP were recorded as a reduction in revenue due to the nature of the credits. The accruals were based upon the original 1996 settlement, the modified terms of the RSP extension, the 2004 resolution of the 2001 through 2002 fuel audit, annual issues as agreed to between Cleco and the LPSC, and Cleco’s assessment of issues that remain outstanding.

In February 2006, the LPSC approved Cleco Power’s request to recover storm restoration costs incurred for Hurricanes Katrina and Rita. As part of this approval, the LPSC required that effective during the interim recovery period (Phase I), which began with the May 2006 billing cycle, Cleco Power’s portion of the shared regulated earnings between the 12.25% and 13.00% allowed return on equity (between 11.25% and 12.25% effective October 1, 2006) be credited against outstanding Hurricanes Katrina and Rita storm restoration costs, rather than being shared between shareholders and customers. In September 2007, as a result of Phase II of the LPSC Staff’s review of storm restoration costs, the LPSC approved a settlement agreement between Cleco Power and the LPSC Staff allowing recovery of essentially all of Cleco Power’s Hurricanes Katrina and Rita storm costs. As part of the agreement, Cleco Power will continue to forgo its share of any excess earnings calculated according to the term of the current RSP (unless modified in a subsequent base rate proceeding). As of December 31, 2009, Cleco Power had not credited any earnings against storm restoration costs. For information concerning this agreement, see Note 3 — “Regulatory Assets and Liabilities.”

Note 13 — Equity Investment in Investees

Cleco reports its investment in Acadia, Evangeline, and certain other subsidiaries on the equity method of accounting. Under the equity method, the assets and liabilities of these entities are reported as equity investment in investees on Cleco Corporation’s Consolidated Balance Sheets. The revenue and expenses (excluding income taxes) of these entities are netted and reported as equity income or loss from investees on Cleco Corporation’s Consolidated Statements of Income.

Equity investment in investees at December 31, 2009, represents primarily Midstream’s $178.4 million investment in Acadia, owned 50% by APH and 50% by Cajun, and its $45.3 million investment in Evangeline, owned 100% by Midstream. Equity investment in investees also represents a $12.9 million investment in Oxbow, owned 50% by Cleco Power and 50% by SWEPCO, along with a $7.4 million investment in Attala and a $7.7 million investment in Perryville, both owned 100% by Cleco Corporation. Equity investments which are less than 100% owned by Cleco Innovations LLC represent less than $0.1 million of the total balance.

The following table presents the equity (loss) income from each investment accounted for using the equity method.

				FOR THE YEAR ENDED DECEMBER 31,
(THOUSANDS)	2009			2008			2007
Acadia	$	(17,243	)	$	(11,217	)	$	80,344
Evangeline		(2,096	)		4,180			11,237
Other subsidiaries 100% owned by Cleco Corporation		1,908			1,496			1,546
Subsidiaries less than 100% owned by Cleco Corporation		8			(1	)		21
Total equity (loss) income	$	(17,423	)	$	(5,542	)	$	93,148

For the year ended December 31, 2007, APH’s equity income included net proceeds of $78.2 million from the settlement of the Calpine bankruptcy claims. It also included $60.0 million of priority distributions received at the closing of the sale of CAH’s 50% equity ownership interest in Acadia, partially offset by a $45.8 million other-than-temporary impairment of the carrying value of the investment in Acadia at the APH level. For more information on these claims, see Note 20 — “Calpine Bankruptcy Settlement.”

In accordance with the authoritative guidance on consolidations, Cleco reported its investments in Evangeline, Perryville, and Attala on the equity method of accounting and reflected net operating results in the equity income (loss) from investees’ line during 2009 and prior years presented. Effective January 1, 2010, the requirements for consolidation changed. On and after January 1, 2010, the assets, liabilities, revenues, expenses, and cash flows of these entities will be presented in the appropriate line items of the consolidated financial statements.

Acadia

At December 31, 2009, since Acadia was owned 50% by APH and 50% by Cajun, APH was not the primary beneficiary, and Acadia was accounted for as an equity method investment. Cleco’s assessment of its maximum exposure to loss related to Acadia at December 31, 2009, consisted of its equity investment of $178.4 million. The table below presents the components of Midstream’s equity investment in Acadia.

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INCEPTION TO DATE (THOUSANDS)	AT DECEMBER 31, 2009
Contributed assets (cash and land)	$	275,956
Net income		143,200
Impairment of investment		(45,847	)
Capitalized interest and other		19,722
Less: non-cash distribution		78,200
Less: cash distributions		136,464
Total equity investment in investee	$	178,367

The $78.2 million non-cash distribution is the distribution of the CES claim from Acadia to APH. The cash distributions of $136.5 million were used to pay interest and repay principal on a loan from Cleco Corporation relating to this investment. Midstream’s equity, as reported on the balance sheet of Acadia at December 31, 2009, was $204.5 million. The difference between the $204.5 million and the equity investment in investee of $178.4 million as shown in the previous table is $26.1 million, and consists of the $45.8 million other-than-temporary impairment of APH’s investment in Acadia, partially offset by $19.7 million of interest capitalized on funds contributed by Acadia.

The table below contains summarized financial information for Acadia.

	AT DECEMBER 31,
(THOUSANDS)	2009		2008
Current assets	$	10,800	$	5,413
Property, plant and equipment, net		403,622		405,565
Total assets	$	414,422	$	410,978
Current liabilities	$	5,437	$	1,380
Partners’ capital		408,985		409,598
Total liabilities and partners’ capital	$	414,422	$	410,978

				FOR THE YEAR ENDED DECEMBER 31,
(THOUSANDS)	2009			2008			2007
Operating revenue	$	50,546		$	74,002		$	63,549
Gain on settlement		-			-			170,200
Operating expenses		74,207			96,681			87,266
Other (expense) income		(10,825	)		(71	)		63
(Loss) income before taxes	$	(34,486	)	$	(22,750	)	$	146,546

Other expense at December 31, 2009, includes $10.8 million of property, plant and equipment retirements and removals.

Income taxes recorded on APH’s financial statements related to Midstream’s 50% ownership interest in Acadia were benefits of $9.7 million and $7.4 million for the years ended December 31, 2009, and 2008, respectively, and $34.3 million expense for the year ended December 31, 2007. The 2007 income tax expense at APH was primarily due to the settlement of Acadia’s pre-petition unsecured claims against CES and Calpine.

In 2009, Cleco Power announced Acadia was selected as the winning bidder in Cleco Power’s 2007 long-term request for capacity beginning in 2010. Cleco Power will own and operate one of Acadia’s two 580-MW units and will also operate the other unit on behalf of Acadia or a future owner. At December 31, 2009, the carrying value of the unit and the related materials and supplies inventory were considered assets held for sale. No gain or loss had been recorded, as the fair value less the costs to sell were greater than the carrying value, and the transaction had not yet been completed.

Cleco Power and the parties executed the definitive agreements in 2009, and received LPSC and FERC approvals for the transaction in January 2010 and February 2010, respectively. Beginning in January 2010, Acadia operated the plant and served Cleco Power under a tolling agreement covering 50% of the Acadia Power Station. The tolling agreement was approved by the LPSC in October 2009 and by FERC in December 2009. The tolling agreement was terminated when the transaction closed in February 2010. For more information regarding the Cleco Power transaction, see Note 23 — “Subsequent Events — Acadia Transaction.”

In October 2009, Acadia and Entergy Louisiana announced that definitive agreements had been executed whereby Entergy Louisiana would acquire 50% of Acadia or one of its two 580-MW units. The carrying value of this unit and the related material and supplies inventory are also considered assets held for sale. No gain or loss has been recorded, as the fair value less the costs to sell are greater than the carrying value, and the transaction has not yet been completed. The transaction is anticipated to be completed in late 2010 or early 2011.

The agreements provide that, beginning in May 2010, Acadia will serve Entergy Louisiana under a tolling agreement covering 50% of Acadia until the transaction is completed. Until May 2010, this portion of Acadia’s output is being sold through an energy management services agreement with a third party marketer. Both the asset sale and interim tolling agreement require regulatory approval. Cleco Power will continue to operate both units at Acadia after the Entergy Louisiana transaction is completed.

In connection with these transactions and in exchange for reasonable consideration, APH has agreed to indemnify, upon the closing of the transactions, Cajun and its affiliates against 100% of Acadia’s liabilities and other obligations related to both the Cleco Power and Entergy Louisiana transactions.

Evangeline

Since its inception, Cleco has had 100% ownership and voting interest of Evangeline. Through an analysis of variable interests, such as Cleco’s investment, the long-term debt, the tolling counterparty, and the potential to absorb expected losses and gains, Cleco has determined that it is not the primary beneficiary. At December 31, 2009, the determination was driven by several factors such as:

§	The tolling counterparty was at risk to absorb market losses and gains, which are primarily determined by the relative price of electricity and natural gas.

§	The debt was non-recourse to Cleco; therefore, the debt-holders main security is the underlying assets of Evangeline.

§	Cleco’s risk of loss was limited to its investment plus the $15.0 million letter of credit issued on behalf of the tolling counterparty.

§	The size of Evangeline’s debt compared to the size of Cleco’s investment at risk.

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Since Cleco was not the primary beneficiary, Evangeline was accounted for as an equity method investment.

Cleco’s current assessment of its maximum exposure to loss related to Evangeline at December 31, 2009, consists of its equity investment of $45.3 million and $15.0 million of possible draws on the letter of credit Cleco has posted on Evangeline’s behalf, for a total of $60.3 million. The following table presents the components of Midstream’s equity investment in Evangeline.

INCEPTION TO DATE (THOUSANDS)	AT DECEMBER 31, 2009
Contributed assets (cash)	$	49,961
Net income		149,503
Less: non-cash distributions		25,125
Less: cash distributions		129,054
Total equity investment in investee	$	45,285

The following tables contain summarized financial information for Evangeline.

	AT DECEMBER 31,
(THOUSANDS)	2009			2008
Current assets	$	20,727		$	25,836
Accounts receivable - affiliate		12			1
Property, plant and equipment, net		183,208			180,051
Other assets		47,915			42,528
Total assets	$	251,862		$	248,416
Current liabilities		26,960		$	19,984
Accounts payable - affiliate		819			1,242
Long-term debt, net		153,564			161,762
Other liabilities		80,957			74,461
Member’s deficit		(10,438	)		(9,033	)
Total liabilities and member’s deficit	$	251,862		$	248,416

				FOR THE YEAR ENDED DECEMBER 31,
(THOUSANDS)	2009			2008			2007
Operating revenue	$	59,852		$	59,978		$	59,307
Operating expenses		25,943			31,921			22,792
Depreciation		5,535			5,371			5,232
(Loss) gain on disposal of assets		(2	)		1			(1,293	)
Interest charges		28,675			17,918			20,077
Other (expense) income		(1,793	)		(589	)		1,324
(Loss) income before taxes	$	(2,096	)	$	4,180		$	11,237

The difference between the equity investment in investee and member’s deficit shown in the tables above is due to income tax items being reported in the corresponding tax accounts on Midstream’s financial statements, rather than the equity investment account.

Cleco Corporation had posted a $15.0 million letter of credit on behalf of the Evangeline Tolling Agreement counterparty. The letter of credit could be drawn in the event Evangeline defaulted on the tolling agreement.

Evangeline’s restricted cash at December 31, 2009, and 2008, was $30.1 million and $25.0 million, respectively. This cash is restricted under Evangeline’s Senior Secured bond indenture.

Interest charges at December 31, 2009, include a $12.1 million adjustment for items related to uncertain tax positions.

Income taxes recorded on Midstream’s financial statements related to Midstream’s 100% ownership interest in Evangeline were a benefit of $0.7 million for the year ended December 31, 2009, and expense of $1.0 million and $4.0 million for the years ended December 31, 2008, and 2007, respectively.

Prior to November 9, 2007, all of the capacity and output of the power plant had been tolled to Williams, which paid Evangeline certain fixed and variable amounts. In November 2007, The Williams Companies, Inc. assigned all of its rights and interests in its tolling agreement with Evangeline to Bear Energy. In May 2008, JPMorgan Chase & Co. completed the acquisition of The Bear Stearns Companies Inc., the parent company of Bear Energy. In September 2008, Bear Energy was merged into JPMVEC. On February 22, 2010, Evangeline and JPMVEC terminated the Evangeline Tolling Agreement and executed the Evangeline 2010 Tolling Agreement. As a result, Cleco Corporation’s obligation under the standby letter of credit issued to JPMVEC was terminated. For more information regarding the Evangeline Tolling Agreement, see Note 15 — “Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Risks and Uncertainties” and Note 23 — “Subsequent Events — Evangeline Transactions.”

Oxbow

In December 2009, Cleco Power purchased 50% of Oxbow from NAC for $12.9 million. Oxbow will provide lignite reserves to fuel the Dolet Hills Power Station. DHLC will operate the mine.

Since Oxbow is owned 50% by Cleco Power and 50% by SWEPCO, Cleco Power is not the primary beneficiary, and Oxbow is accounted for as an equity method investment. Cleco’s current assessment of its maximum exposure to loss related to Oxbow at December 31, 2009, consists of its equity investment of $12.9 million. The table below presents the components of Cleco Power’s equity investment in Oxbow.

INCEPTION TO DATE (THOUSANDS)	AT DECEMBER 31, 2009
Purchase price	$	12,873
Total equity investment in investee	$	12,873

(THOUSANDS)	AT DECEMBER 31,2009
Current assets	$	976
Property, plant and equipment, net		24,770
Total assets	$	25,746
Partners’ capital	$	25,746
Total liabilities and partners’ capital	$	25,746

There was no 2009 income statement activity for Oxbow.

Other Subsidiaries 100% owned by Cleco Corporation

The information about these entities is aggregated because their method of operation, size, and risk are materially similar. Both entities own transmission assets, provide transmission services to one customer under a long-term contract at a FERC-approved cost of service rate, and are capitalized with 100% equity.

Through an analysis of variable interests, such as Cleco’s investment and the single counterparty that has a long-term lease of the facilities, Cleco has determined that it is not the

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primary beneficiary of either entity. The determination is driven by several factors such as:

§	Each entity has only one customer under the long-term agreements accounted for as direct financing leases.

§	Both entities can only charge FERC-approved tariffs.

§	Both entities have the ability to change the tariff if actual expenses are materially different than expected expenses.

§	The lease counterparty is required to make lease payments regardless of the use of the assets.

§	Cleco’s risk of loss is limited to its investment.

Since Cleco is not the primary beneficiary, the investments in Perryville and Attala are accounted for as equity method investments.

Cleco’s current assessment of its maximum exposure to loss with respect to Perryville and Attala at December 31, 2009, consists of its equity investment of $15.1 million. The following table presents the components of Cleco Corporation’s equity investment in Perryville and Attala.

INCEPTION TO DATE (THOUSANDS)	AT DECEMBER 31, 2009
Contributed assets (cash)	$	132,960
Net income		56,073
Less: non-cash distributions		20,963
Less: cash distributions		152,988
Total equity investment in investee	$	15,082

The following tables contain summarized financial information for Perryville and Attala.

			AT DECEMBER 31,
(THOUSANDS)	2009		2008
Current assets	$	5,361	$	4,905
Other assets		13,815		14,166
Total assets	$	19,176	$	19,071
Current liabilities	$	132	$	9
Accounts payable - affiliate		79		2
Other liabilities		822		484
Member’s equity		18,143		18,576
Total liabilities and member’s equity	$	19,176	$	19,071

			FOR THE YEAR ENDED DECEMBER 31,
(THOUSANDS)	2009		2008			2007
Operating revenue	$	1,959	$	1,976		$	1,833
Operating expenses		586		479			279
Other income (expense)		34		-			(3	)
Interest income (expense)		501		(1	)		(5	)
Income before taxes	$	1,908	$	1,496		$	1,546

The difference between the equity investment in investee and member’s equity shown in the tables above is due to income tax items being reported in the corresponding tax accounts on Cleco Corporation’s financial statements, rather than the equity investment account.

The transmission assets utilized by Perryville and Attala are accounted for as direct financing leases and are included in other assets in the summarized financial information above.

Interest income for the year ended December 31, 2009, includes $0.5 million of interest related to amended tax returns.

Income tax expense recorded on Cleco’s financial statements related to Cleco Corporation’s 100% interest in Perryville and Attala was $0.7 million, $0.6 million, and $0.6 million for the years ended December 31, 2009, 2008, and 2007, respectively.

Note 14 — Operating Leases

The following is a schedule of operating leases that Cleco maintains in the ordinary course of business activities. The majority of Cleco’s operating leases are for line construction and operating vehicles and for railcars for coal deliveries, both utilized by Cleco Power. The remaining leases provide for office and operating facilities and office equipment. These leases have various terms and expiration dates. The following table is a summary of expected operating lease payments for Cleco Corporation and Cleco Power for the years indicated.

			YEAR ENDING DECEMBER 31,
	CLECO		CLECO
(THOUSANDS)	CORPORATION		POWER		TOTAL
2010	$	158	$	9,354	$	9,512
2011		158		8,759		8,917
2012		73		7,514		7,587
2013		5		6,978		6,983
2014		5		1,333		1,338
Thereafter		4		6,829		6,833
Total operating lease payments	$	403	$	40,767	$	41,170

Cleco’s operating leases for line construction and maintenance vehicles have a term of seven years with an additional one-year renewal. The lease payment is determined by taking the equipment’s original cost multiplied by the adjusted rental factor. Contingent rents are based on the change in the LIBOR rate at May 15, 2001, compared to December 31, 2009, 2008, and 2007. For the years ended December 31, 2009, 2008, and 2007, lease expenses of $1.4 million, $1.5 million, and $1.6 million, respectively, were recognized. Contingent rents were less than $0.1 million for the years ended December 31, 2009, 2008, and 2007, respectively.

The railcar leases are divided into two groups. The first group has 120 railcars, and the lease expires on March 31, 2021. The second group of railcars has 121 cars, and the lease expires on March 31, 2017. Cleco Power pays a monthly rental fee per car. For each of the years ended December 31, 2009, 2008, and 2007, an operating lease expense of $1.1 million was recognized. The railcar leases do not contain contingent rent payments.

Cleco’s operating leases for vehicles, office and operating facilities, and office equipment have lease terms from three to ten years. The monthly lease payment is determined by summing the monthly equipment amortization with the lowest monthly interest rate multiplied by the amortized value. Contingent rents are calculated by comparing the difference between the lowest rate at December 1984 to the lowest rate at December 2009, 2008, and 2007. For the years ended December 31, 2009, 2008, and 2007, lease expenses of $6.5

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million, $1.8 million, and $1.3 million, respectively, were recognized. For the years ended December 31, 2009, 2008, and 2007, contingent rents were $0.5 million, $0.2 million, and less than $0.1 million, respectively.

On November 14, 2008, Cleco Power was notified by GE Capital Commercial, Inc. that it was electing to terminate the lease agreement pertaining to company vehicles and other equipment. Pursuant to the terms of the lease agreement, the termination date was effective January 13, 2009, sixty days from the date of notice. Cleco Power had one year from the termination date to enter into a new operating lease with a third party and/or negotiate the sale of such equipment. The purchase of vehicles and equipment under the lease agreement was finalized in November 2009. For more information regarding operating leases, see Note 15 — “Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Other Contingencies — CBL Capital Corporation.”

Note 15 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees

Litigation

On June 22, 2005, the City of Alexandria, Louisiana (the City), a current wholesale municipal customer of Cleco Power, filed a lawsuit in Ninth Judicial District Court against Cleco Corporation, Cleco Power, and certain other subsidiaries. The lawsuit alleged unspecified damages as a result of certain sales made to the City, revenue derived by Cleco using the City’s power generating facilities under contracts with the City, and other alleged improper conduct, including, without limitation, allegations that Cleco fraudulently mishandled the management of the City’s power requirements under the contracts. The lawsuit was removed to the U.S. District Court for the Western District of Louisiana. On February 23, 2010, the Alexandria City Council approved a settlement of the case which included a $3.0 million litigation expense reimbursement to the City and a new five-year, energy-only power supply agreement. The supply agreement may be extended, at Cleco Power’s option, for two additional one-year terms. If the City performs its obligations under the new power supply agreement, then Cleco will pay a one-time $6.5 million performance bonus at the end of the five-year term to the City. The court dismissed the case with prejudice on February 24, 2010.

In October 2007, Cleco received a Special Notice for Remedial Investigation and Feasibility Study from the EPA. The special notice requested that Cleco Corporation and Cleco Power, along with many other listed potentially responsible parties, enter into negotiations with the EPA for the performance of a Remedial Investigation and Feasibility Study at an area known as the Devil’s Swamp Lake just northwest of Baton Rouge, Louisiana. The EPA has identified Cleco as one of many companies sending PCB wastes for disposal to the site. The Devil’s Swamp Lake site has been proposed to be added to the National Priorities List (NPL) based on the release of PCBs to fisheries and wetlands located on the site. The EPA has yet to make a final determination on whether to add Devil’s Swamp Lake to the NPL. The EPA and a number of PRPs met in January 2008, for an organizational meeting to discuss the background of the site. The PRPs began discussing a potential proposal to the EPA in February 2008. Negotiations among the PRPs and the EPA are ongoing in regard to the remedial investigation and feasibility study at the Devil’s Swamp site, with little progress having been made since the January 2008 meeting. The PRPs alleged to have disposed PCBs at the site have proposed a tentative cost sharing formula with the facility owner to fund the remedial investigation. The response to the proposal has been pending for months. Since this investigation is in the preliminary stages, management is unable to determine whether the costs associated with possible remediation of the facility site will have a material adverse effect on the Registrants’ results of operations, financial condition, and cash flows.

On December 11, 2009, a complaint was filed in the U.S. District Court for the Western District of Louisiana on behalf of eight current employees and four former employees alleging that Cleco discriminated against each of them on the basis of race. Each is seeking various remedies provided under applicable statutes prohibiting racial discrimination in the workplace, and together, the plaintiffs seek monetary compensation exceeding $35.0 million. Management believes this lawsuit will not have a material adverse effect on the Registrants’ financial condition, results of operations, or cash flows.

Cleco is involved in regulatory, environmental, and legal proceedings before various courts, regulatory commissions, and governmental agencies regarding matters arising in the ordinary course of business. Some of these proceedings, such as fuel review and environmental issues, could involve substantial amounts. Management regularly analyzes current information and, as necessary, provides accruals for probable liabilities on the eventual disposition of these matters. Management believes the disposition of these matters will not have a material adverse effect on the Registrants’ financial condition, results of operations, or cash flows.

Off-Balance Sheet Commitments and Disclosures about Guarantees

Cleco Corporation and Cleco Power have entered into various off-balance sheet commitments, in the form of guarantees and standby letters of credit, in order to facilitate their activities and the activities of Cleco Corporation’s subsidiaries and equity investees (affiliates). Cleco Corporation and Cleco Power also have agreed to contractual terms that require them to pay third parties if certain triggering events occur. These contractual terms generally are defined as guarantees in the authoritative guidance.

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affiliates, or may have contracted with them at terms less favorable to its affiliates.

The off-balance sheet commitments are not recognized on Cleco’s Consolidated Balance Sheets, because it has been determined that Cleco’s affiliates are able to perform these obligations under their contracts and that it is not probable that payments by Cleco will be required. Some of these commitments reduce borrowings available to Cleco Corporation under its credit facility pursuant to the terms of the credit facility. Cleco’s off-balance sheet commitments as of December 31, 2009, are summarized in the following table, and a discussion of the off-balance sheet commitments follows the table. The discussion should be read in conjunction with the table to understand the impact of the off-balance sheet commitments on Cleco’s financial condition.

							AT DECEMBER 31, 2009
							REDUCTIONS TO THE
							AMOUNT AVAILABLE
							TO BE DRAWN ON
	FACE				NET		CLECO CORPORATION’S
(THOUSANDS)	AMOUNT		REDUCTIONS		AMOUNT		CREDIT FACILITY
Cleco Corporation
Guarantee issued to Entergy companies for performance obligations of Perryville	$	177,400	$	135,000	$	42,400	$	-
Obligations under standby letter of credit issued to the Evangeline Tolling Agreement counterparty		15,000		-		15,000		15,000
Guarantee issued to Entergy Mississippi on behalf of Attala		500		-		500		-
Cleco Power
Obligations under standby letter of credit issued to the Louisiana Department of Labor		3,525		-		3,525		-
Total	$	196,425	$	135,000	$	61,425	$	15,000

Prior to February 22, 2010, if Evangeline failed to perform certain obligations under its tolling agreement, Cleco Corporation would have been required to make payments to the Evangeline Tolling Agreement counterparty. Cleco Corporation’s obligation under the Evangeline commitment was in the form of a standby letter of credit from investment grade banks and was limited to $15.0 million. Ratings triggers did not exist in the Evangeline Tolling Agreement. Evangeline met its obligations under the tolling agreement and Cleco Corporation was not required to make payments to the counterparty. The letter of credit was issued under Cleco Corporation’s credit facility and therefore reduced the amount that could be borrowed under the credit facility. On February 22, 2010, Evangeline entered into the Evangeline 2010 Tolling Agreement and as a result this letter of credit was terminated. For additional information, see Note 23 — “Subsequent Events — Evangeline Transactions.”

The State of Louisiana allows employers of certain financial net worth to self-insure their workers’ compensation benefits. Cleco Power has a certificate of self-insurance from the Louisiana Office of Workers’ Compensation and is required to post a $3.5 million letter of credit, an amount equal to 110% of the average losses over the previous three years, as surety.

The following table summarizes the expected termination date of the guarantees and standby letters of credit discussed above.

							AT DECEMBER 31, 2009
			AMOUNT OF COMMITMENT EXPIRATION PER PERIOD
	NET								MORE
	AMOUNT		LESS THAN						THAN
(THOUSANDS)	COMMITTED		ONE YEAR		1-3 YEARS		3-5 YEARS		5 YEARS
Guarantees	$	42,900	$	-	$	-	$	-	$	42,900
Standby letters of credit		18,525		3,525		-		-		15,000
Total commercial commitments	$	61,425	$	3,525	$	-	$	-	$	57,900

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In its bylaws, Cleco Corporation has agreed to indemnify directors, officers, agents and employees who are made a party to a pending or completed suit, arbitration, investigation, or other proceeding whether civil, criminal, investigative or administrative, if the basis of inclusion arises as the result of acts conducted in the discharge of their official capacity. Cleco Corporation has purchased various insurance policies to reduce the risks associated with the indemnification. In its Operating Agreement, Cleco Power provides for the same indemnification as described above with respect to its managers, officers, agents, and employees.

Generally, neither Cleco Corporation nor Cleco Power has recourse that would enable them to recover amounts paid under their guarantee or indemnification obligations. The one exception is the insurance contracts associated with the indemnification of directors, managers, officers, agents, and employees. There are no assets held as collateral for third parties that either Cleco Corporation or Cleco Power could obtain and liquidate to recover amounts paid pursuant to the guarantees.

Long-Term Purchase Obligations

Cleco Corporation had no unconditional long-term purchase obligations at December 31, 2009. Cleco Power has several unconditional long-term purchase obligations related to the purchase of coal, petroleum coke, limestone, energy capacity, and energy delivery facilities. The aggregate amount of payments required under such obligations at December 31, 2009, is as follows.

YEAR ENDING DECEMBER 31,	(THOUSANDS)
2010	$	57,923
2011		58,842
2012		47,992
2013		44,077
2014		16,660
Total long-term purchase obligations	$	225,494

Payments under these agreements for the years ended December 31, 2009, 2008, and 2007 were $43.5 million, $31.6 million, and $27.8 million, respectively.

Other Contingencies

General Electric Services Corporation

Cleco Power has entered into an operating lease agreement with General Electric Equipment Services Corporation for leasing railcars in order to transport coal to Rodemacher Unit 2. The lease contains a provision for early termination, along with an associated termination fee. The termination provision can only be exercised in December 2010. If exercised by Cleco Power, the termination fee would be approximately $1.3 million. At this time, Cleco Power has no plans to early terminate this lease, which expires in March 2017.

CBL Capital Corporation

Cleco Power entered into an operating lease agreement with CBL Capital Corporation, which was acquired by GE Capital Commercial, Inc. (GE Capital). This was a master leasing agreement for company vehicles and other equipment. On November 14, 2008, Cleco Power was notified by GE Capital that it was electing to terminate the lease. Pursuant to the terms of the lease agreement, the termination date was effective January 13, 2009. Cleco Power had one year from the termination date to enter into a new operating lease with a third party and/or negotiate the purchase of such equipment for the unamortized balance. The purchase of vehicles and equipment under the lease agreement was finalized in November 2009 for approximately $5.7 million.

New Market Tax Credits

In August 2008, Cleco Corporation acquired a 99.9% membership interest in U.S. Bank New Market Tax Credit Fund 2008-1 LLC (the Fund). The Fund was formed by U.S. Bancorp Community Development Corporation (USBCDC). The purpose of the Fund is to invest in projects located in qualified active low-income communities that are underserved by typical debt capital markets. These investments will generate new market tax credits and historical rehabilitation tax credits.

In December 2009, the operating agreement was amended to allow the Fund to invest in projects entitled to receive energy credits of approximately $80.0 million. In connection with the 2009 amendment, USBCDC, through its parent U.S. Bank, will guarantee an internal rate of return target based on a stipulated utilization of credits by the Fund.

The tax credits serve to reduce the federal income tax obligations of Cleco Corporation. Cleco Corporation will make $298.7 million of equity contributions to the Fund and receive approximately $304.7 million of net tax benefits from the Fund over the life of the investment. The following table shows future equity contributions.

(THOUSANDS)	CONTRIBUTION
2010	$	35,871
2011		39,469
2012		34,916
2013		32,640
2014		11,295
Thereafter		116,558
Total	$	270,749

Of the $270.7 million, $35.9 million is due to be paid within the next twelve months. The investment and associated debt are presented on the balance sheet, net in other deferred credits due to the right of offset.

The equity contribution does not contain a stated rate of interest. Cleco has recorded the liability and investment at its calculated fair value within the framework of the authoritative guidance. In order to calculate the fair value, management used an imputed rate of interest assuming that Cleco obtained financing of a similar nature from a third party. The imputed rate was used in a net present value model in order to calculate the fair value of the remaining portion of the delayed equity contributions. The table below contains the disclosures required by the authoritative guidelines for equity investments with an imputed interest.

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(THOUSANDS)
Equity contributions, imputed interest rate 6%
Principal payment schedule above:	$	270,749
Less: unamortized discount		59,689
Total	$	211,060

The gross investment amortization expense is recognized over a ten-year period using the cost method in accordance with the authoritative guidance for investments.

Fuel Transportation Agreement

Cleco Power has entered into an agreement that meets the accounting definition of a capital lease for barges in order to transport petroleum coke and limestone to Rodemacher Unit 3. The 42 dedicated barges were delivered in January and February 2009.

The lease rate contains a fixed fee of $225 per day per barge and a variable component of $75 adjusted by Producer Price Index (PPI) annually for executory costs. If the barges are idle, the lessor is required to attempt to sublease the barges to third parties, with the revenue reducing Cleco Power’s lease payment. During the year ended December 31, 2009, Cleco Power paid approximately $4.3 million in lease payments and did not receive any revenue from subleases.

The initial term of this agreement is five years and unless renewed, the agreement will terminate on December 31, 2013. Cleco Power has an option to renew this agreement for a second five-year term in full or in part and, at its option, purchase any or all of the dedicated barges. If Cleco Power does not renew this agreement for the renewal term, then the lessor has the option to require Cleco Power to purchase any or all of the barges. If Cleco Power purchases the barges on December 31, 2013, the purchase price of all 42 barges will be $21.7 million.

This agreement contains a provision for early termination upon the occurrence of any one of four cancellation events.

The following is an analysis of the leased property under capital leases by major classes:

			AT DECEMBER 31,
CLASSES OF PROPERTY (THOUSANDS)	2009		2008
Barges	$	22,050	$	-
Other		555		555
Total capital leases		22,605		555
Less: accumulated amortization		2,537		342
Net capital leases	$	20,068	$	213

The amount listed as Other in the chart above includes a capital lease agreement for miscellaneous equipment by Cleco Power. This lease terminates on December 31, 2010.

The following is a schedule by years of future minimum lease payments under capital leases together with the present value of the net minimum lease payments as of December 31, 2009.

(THOUSANDS)
Years ending December 31,
2010	$	4,748
2011		4,622
2012		4,634
2013		4,622
2014		4,622
Thereafter		18,499
Total minimum lease payments	$	41,747
Less: executory costs		10,558
Net minimum lease payments	$	31,189
Less: amount representing interest		10,315
Present value of net minimum lease payments	$	20,874
Current liabilities	$	1,636
Non-current liabilities	$	19,238

During the year ended December 31, 2009, Cleco Power incurred immaterial amounts of contingent rent related to the increase in the PPI.

Oxbow Lignite Mine Acquisition

In April 2009, Cleco Power entered into an agreement with SWEPCO to purchase Oxbow from NAC. In September 2009, the LPSC approved the joint application authorizing the acquisition of Oxbow. On December 29, 2009, Cleco Power and SWEPCO completed the transaction. Cleco Power’s 50% portion of the purchase price for the lignite reserves was $12.9 million. SWEPCO likewise paid $12.9 million for its 50% interest in the lignite reserves. SWEPCO’s subsidiary, DHLC, acquired the mining equipment and related assets and permits for $15.6 million and will operate the new mine along with its current operations at the Dolet Hills Lignite Mine on similar terms. The recoverable lignite reserves of approximately 100 million tons contained within the Oxbow Mine permit area, together with the reserves from the Dolet Hills Lignite Mine, are expected to be sufficient to fuel the Dolet Hills Power Station until at least 2026. The existing Red River Lignite Supply and Transportation Agreement with NAC terminated upon the closing of this transaction.

Rodemacher Unit 3

In August 2005, Cleco Power entered into an EPC contract with Shaw to construct Rodemacher Unit 3. Cleco Power began construction of Rodemacher Unit 3 in May 2006. In May 2006, Cleco Power and Shaw entered into an Amended EPC Contract, which provided for substantial completion of construction of Rodemacher Unit 3 by September 30, 2009.

Pursuant to various amendments, in October 2009, Cleco Power and Shaw again amended the EPC contract to extend the substantial completion date to September 28, 2009. Various claims remain in dispute resolution between Cleco Power and Shaw including the claims for force majeure related costs, which have been agreed upon as not to exceed $24.0 million less a settlement credit of $6.0 million, plus various outstanding claims relating to fuel moisture and water and steam quality. The Registrants do not believe the resolution of these claims will have a material adverse effect on the Registrants’ results of operations, financial condition, or cash flows.

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Acadia Transactions

In February 2009, Cleco Power announced that it had chosen the acquisition of 50% of the Acadia Power Station, or one of its two 580-MW units, as the lowest bid in its 2007 long-term RFP for capacity beginning in 2010. Cleco Power will own and operate one unit and operate the other 580-MW unit on behalf of Acadia or a future owner. Cleco Power and the parties executed the definitive agreements in 2009, and received LPSC and FERC approvals for the transaction in January 2010 and February 2010, respectively. Beginning in January 2010, Acadia operated the plant and served Cleco Power under a tolling agreement covering 50% of the Acadia Power Station. The tolling agreement was approved by the LPSC in October 2009 and by FERC in December 2009. In February 2010, Cleco Corporation obtained a consent from its credit facility lenders relating to transactions included in the future sale of 50% of the Acadia Power Station to Cleco Power. Cleco Corporation paid the lenders $0.1 million for the consent, which will be included in interest expense. In February 2010, the transaction closed and the tolling agreement was terminated. For more information regarding the Cleco Power transaction, see Note 23 — “Subsequent Events — Acadia Transaction.”

In October 2009, Acadia and Entergy Louisiana announced that definitive agreements had been executed whereby Entergy Louisiana would acquire 50% of the Acadia Power Station, or one of its two 580-MW units. The transaction is anticipated to be completed in late 2010 or early 2011. The agreements provide that, beginning in May 2010, Acadia will serve Entergy Louisiana under a tolling agreement covering 50% of the Acadia Power Station until the transaction is completed. Both the asset transaction and interim tolling agreement require regulatory approval. Cleco Power will operate both units at Acadia Power Station after the Entergy Louisiana transaction is completed.

In connection with these transactions and in exchange for reasonable consideration, APH has agreed to indemnify, upon the closing of these transactions, Cajun and its affiliates against 100% of Acadia’s liabilities and other obligations related to both the Cleco Power and Entergy Louisiana transactions.

Other

Cleco has accrued for liabilities to third parties, employee medical benefits, and storm damages.

Risks and Uncertainties

Cleco Corporation

Cleco Corporation could be subject to possible adverse consequences if Cleco’s counterparties fail to perform their obligations or if Cleco Corporation or its affiliates are not in compliance with loan agreements or bond indentures.

Evangeline Tolling Agreement

JPMorgan Chase & Co. guaranteed JPMVEC’s obligations under the Evangeline Tolling Agreement and also is guaranteeing JPMVEC’s obligations under the Evangeline 2010 Tolling Agreement.

On February 22, 2010, Evangeline and JPMVEC terminated the Evangeline Tolling Agreement and executed the Evangeline 2010 Tolling Agreement. As a result, Cleco Corporation’s obligation under the standby letter of credit issued to JPMVEC was terminated. For additional information regarding the new tolling agreement, see Note 23 — “Subsequent Events — Evangeline Transactions.”

Other

Changes in the regulatory environment or market forces could cause Cleco to determine its assets have suffered an other-than-temporary decline in value, whereby an impairment would be required to be taken and Cleco’s financial condition could be materially adversely affected.

Cleco Power

Cleco Power supplies a portion of its customers’ electric power requirements from its own generation facilities. In addition to power obtained from power purchase agreements, Cleco Power purchases power from other utilities and marketers to supplement its generation at times of relatively high demand or when the purchase price of power is less than its own cost of generation. Due to its location on the transmission grid, Cleco Power relies on two main suppliers of electric transmission when accessing external power markets. At times, constraints limit the amount of purchased power these transmission providers can deliver into Cleco Power’s service territory.

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companies with comparable credit ratings. In November 2009, Moody’s downgraded Cleco Power’s credit rating by one level. This downgrade placed Cleco Power’s credit rating at Moody’s at a similar level to Cleco Power’s credit rating at Standard & Poor’s. Cleco Power pays fees and interest under its bank credit agreements based on the highest rating held. If Cleco Power’s credit ratings were to be downgraded by Moody’s and Standard & Poor’s, Cleco Power would be required to pay additional fees and higher interest rates under its bank credit agreements. Cleco Power’s collateral for derivatives is based on the lowest rating held. If Cleco Power’s credit ratings were to be downgraded by Moody’s or Standard & Poor’s, Cleco Power would be required to pay additional collateral for derivatives.

In August 2005, Cleco Power entered into an EPC contract with Shaw to construct Rodemacher Unit 3. In May 2006, Cleco Power and Shaw entered into an Amended EPC Contract. Under the terms of the Amended EPC Contract until final acceptance of Rodemacher Unit 3, in the event Cleco Power does not maintain a senior unsecured credit rating of either: (i) Baa3 or better from Moody’s or (ii) BBB- or better from Standard & Poor’s, Cleco Power will be required to provide a letter of credit to Shaw in the amount of $20.0 million. In the event of further downgrade to both of its credit ratings to: (i) Ba2 or below from Moody’s, and (ii) BB or below from Standard & Poor’s, Cleco Power will be required to provide an additional $15.0 million letter of credit to Shaw.

Note 16 — FERC Staff Investigations and LPSC Fuel Audit

FERC Staff Investigations

In July 2003, FERC issued an order approving a Consent Agreement between the FERC Staff and Cleco that settled the FERC investigation following Cleco’s disclosure in November 2002 of certain energy marketing and trading practices. The terms of the Consent Agreement, effective on August 24, 2003, included, but were not limited to: (i) filing revised codes of conduct by Cleco’s public utility subsidiaries that impose more stringent restrictions on affiliate relations; (ii) implementation of a Compliance Plan for FERC regulatory compliance; and (iii) payment of certain penalties and remedies, including payment of a $0.8 million civil penalty to FERC.

In November 2005, after a review of Cleco’s October 2005 quarterly compliance report, the FERC Staff initiated a preliminary, non-public investigation into certain representations made by Cleco. In response to data requests from the FERC Staff, Cleco provided information regarding those representations, as well as compliance with the Code of Conduct and Compliance Plan contained in the Consent Agreement. The information primarily concerned the possible sharing of employees and information among Cleco’s subsidiaries, as well as the accuracy of information furnished to the FERC Staff in connection with reporting on compliance with the Consent Agreement. In June 2007, FERC issued an order approving a Stipulation and Consent Agreement between Cleco and the FERC’s Office of Enforcement which completely resolved these matters. FERC’s investigation was terminated, and Cleco was released of any further claims arising from such investigation. Cleco agreed to pay a one-time civil penalty of $2.0 million and adhere to the Compliance Plan. In June 2007, Cleco paid the penalty, the payment of which was not passed through, directly or indirectly, to any existing or future customers.

LPSC Fuel Audit

The LPSC Fuel Adjustment Clause General Order issued November 6, 1997, in Docket No. U-21497 provides that an audit will be performed not less than every other year. Cleco Power currently has fuel adjustment clause filings for 2003 through 2008 subject to audit. In July 2006, the LPSC informed Cleco Power that it was planning to conduct a periodic fuel audit that included fuel adjustment clause filings for January 2003 through December 2004. In March 2009, the LPSC indicated its intent to proceed with the audit for the years 2003 through 2008. The total amount of fuel expenses included in the audit is approximately $3.2 billion. The audit is expected to proceed in the first quarter of 2010. Cleco Power could be required to make a substantial refund of previously recorded revenue as a result of these audits, and such refund could result in a material adverse effect on the Registrants’ results of operations, financial condition, and cash flows.

Note 17 — Affiliate Transactions

Cleco

Cleco has affiliate balances that were not eliminated as of December 31, 2009. The balances were not eliminated due to the use of the equity method of accounting for Evangeline, Perryville, Attala, and Acadia. For information on these affiliates, see Note 13 — “Equity Investment in Investees.”

Effective July 1, 1999, Cleco entered into service agreements with affiliates that provide Cleco access to professional services and goods. Services and goods provided by Cleco Power are charged at management’s estimate of fair market value or fully loaded cost, whichever is higher. Services provided to Cleco Power are charged at management’s estimate of fair market value or fully loaded cost, whichever is lower, with the exception of Support Group, which charges only fully loaded cost in order to comply with Cleco’s affiliate policy.

Affiliate goods and services received by Cleco primarily involve services provided by Support Group and Generation Services. Support Group provides joint and common administrative support services in the areas of information technology; finance, cash management, accounting and auditing; human resources; corporate communications; project consulting; risk management; strategic and corporate development; legal, ethics and regulatory compliance; facilities management; supply chain and inventory management and other administrative services. Generation Services provides electric power plant operations and maintenance expertise. Following is a summary of charges from each affiliate included in Cleco Corporation’s Consolidated Statements of Income.

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	FOR THE YEAR ENDED DECEMBER 31,
(THOUSANDS)	2009			2008			2007
Support Group
Fuel purchased	$	-		$	4		$	2
Other operations	$	2,417		$	2,155		$	1,712
Maintenance	$	38		$	112		$	184
Taxes other than income taxes	$	(18	)	$	(10	)	$	1
Other expenses	$	17		$	17		$	4
Cleco Power
Other operations	$	29		$	34		$	43
Maintenance	$	30		$	8		$	46
Generation Services
Other operations	$	3,365		$	3,143		$	1,800
Maintenance	$	4,157		$	3,810		$	2,310
CLE Intrastate
Fuel purchased	$	917		$	913		$	892

Following is a reconciliation of Cleco affiliate revenue.

	FOR THE YEAR ENDED DECEMBER 31,
(THOUSANDS)	2009		2008		2007
Evangeline	$	5,999	$	6,057	$	5,928
Perryville		81		11		43
Attala		3		3		2
Acadia		5,378		4,389		1,165
Total	$	11,461	$	10,460	$	7,138

Cleco had the following affiliate receivable and payable balances associated with the service agreements between Cleco and its affiliates.

					AT DECEMBER 31,
			2009				2008
	ACCOUNTS		ACCOUNTS		ACCOUNTS		ACCOUNTS
(THOUSANDS)	RECEIVABLE		PAYABLE		RECEIVABLE		PAYABLE
Evangeline	$	11,396	$	2,362	$	3,029	$	8,228
Perryville		102		-		2		-
Attala		54		-		-		-
Acadia		577		8		397		1
Total	$	12,129	$	2,370	$	3,428	$	8,229

Cleco Power

Effective July 1, 1999, Cleco Power entered into service agreements with affiliates that provide Cleco Power access to professional services and goods. The services and goods are charged to Cleco Power at management’s estimate of fair market value or fully loaded cost, whichever is lower, with the exception of Support Group, which charges only fully loaded cost in order to comply with Cleco’s affiliate policy.

Affiliate goods and services received by Cleco Power primarily involve services provided by Support Group. Support Group provides joint and common administrative support services in the areas of information technology; finance, cash management, accounting and auditing; human resources; corporate communications; project consulting; risk management; strategic and corporate development; legal, ethics and regulatory compliance; facilities management; supply chain and inventory management and other administrative services. A summary of charges from each affiliate included in Cleco Power’s Consolidated Statements of Income follows.

	FOR THE YEAR ENDED DECEMBER 31,
(THOUSANDS)	2009			2008			2007
Support Group
Other operations	$	36,593		$	34,316		$	36,305
Maintenance	$	1,916		$	1,792		$	2,600
Taxes other than income taxes	$	(199	)	$	(175	)	$	121
Other expenses	$	1,080		$	940		$	749
Interest charges	$	-		$	2		$	5
Income taxes	$	-		$	-		$	116
Diversified Lands
Other expenses	$	4		$	65		$	73

Cleco Power also entered into agreements to provide goods and services to affiliated companies. The goods and services are charged by Cleco Power at fully loaded cost or management’s estimate of fair market value, whichever is higher, in order to comply with Cleco’s affiliate policy. The majority of the services provided by Cleco Power to affiliates relates to the lease of office space to Support Group. Following is a reconciliation of Cleco Power’s affiliate revenue.

	FOR THE YEAR ENDED DECEMBER 31,
(THOUSANDS)	2009		2008		2007
Support Group	$	1,352	$	1,979	$	1,980
Midstream		20		28		28
Evangeline		22		29		42
Acadia		1		1		-
Total	$	1,395	$	2,037	$	2,050

Cleco Power had the following affiliate receivable and payable balances associated with the service agreements between Cleco Power and its affiliates.

					AT DECEMBER 31,
			2009				2008
	ACCOUNTS		ACCOUNTS		ACCOUNTS		ACCOUNTS
(THOUSANDS)	RECEIVABLE		PAYABLE		RECEIVABLE		PAYABLE
Cleco Corporation	$	11	$	19,191	$	-	$	856
Support Group		2,698		6,741		1,973		6,679
Midstream		9		1		9		-
Evangeline		45		2		44		1
Generation Services		30		2		22		-
Diversified Lands		5		-		10		-
Acadia		36		3		-		-
Others		2		-		1		-
Total	$	2,836	$	25,940	$	2,059	$	7,536

During 2009, Cleco Power made $30.0 million of distribution payments to Cleco Corporation. There were no distributions from Cleco Power to Cleco Corporation during 2008 or 2007.

Cleco Power received no equity contributions from Cleco Corporation in 2009 or 2008. During 2007, Cleco Power received equity contributions of $85.0 million from Cleco Corporation.

Affiliates that participate in the defined benefit pension plan sponsored by Cleco Power transfer their liability and an equal amount of cash on a periodic basis to Cleco Power. The following table shows the amounts transferred by affiliates during 2009 and 2008.

120

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	FOR THE YEAR ENDED DECEMBER 31,
(THOUSANDS)	2009		2008
Support Group	$	1,606	$	1,320
Generation Services		199		153
Midstream		39		15
Total	$	1,844	$	1,488

Note 18 — Intangible Asset

During the first quarter of 2008, Cleco Katrina/Rita acquired a $177.5 million intangible asset which includes $176.0 million for the right to bill and collect storm recovery charges from customers of Cleco Power and $1.5 million of financing costs. This intangible asset is expected to have a life of 12 years, but could have a life of up to 15 years depending on the time period required to collect the required amount from Cleco Power’s customers. The intangible asset is being amortized according to the estimated collections from Cleco Power’s customers. At the end of its life, this asset will have no residual value. During the twelve months ended December 31, 2009 and 2008, Cleco Katrina/Rita recognized amortization expense of $10.7 million and $9.7 million, respectively. For additional information on Cleco Katrina/Rita storm costs and securitization, see Note 3 — “Regulatory Assets and Liabilities — Deferred Storm Restoration Costs - Katrina/Rita.” The following tables provide additional information about this intangible asset.

(THOUSANDS)	AT DECEMBER 31, 2009
Gross carrying amount	$	177,537
Accumulated amortization		20,439
Intangible asset	$	157,098

(THOUSANDS)
Expected amortization expense
For the twelve months ending December 31, 2010	$	11,538
For the twelve months ending December 31, 2011	$	12,330
For the twelve months ending December 31, 2012	$	13,167
For the twelve months ending December 31, 2013	$	14,026
For the twelve months ending December 31, 2014	$	14,931
After 2014	$	91,106

Note 19 — Storm Restoration

In September 2008, Cleco Power’s distribution and transmission systems sustained substantial damage from two separate hurricanes. The damage to equipment from both storms required replacement, as well as repair of existing assets.

On September 1, 2008, Hurricane Gustav made landfall in southeastern Louisiana as a Category 2 hurricane, causing power outages to approximately 246,000, or 90%, of Cleco Power’s electric customers and affecting Cleco Power’s entire service territory. By September 9, 2008, power was restored to all customers who lost service after Hurricane Gustav. Hurricane Gustav’s restoration costs were approximately $66.1 million, of which 58.6%, or $38.7 million, was capitalized.

On September 13, 2008, Hurricane Ike made landfall in southeast Texas as a Category 2 hurricane, affecting power service to approximately 80,000 of Cleco Power’s electric customers in Cleco Power’s southern service territory. By September 16, 2008, restoration efforts for all customers whose service could be reconnected were complete. Hurricane Ike’s restoration costs were approximately $12.6 million, of which 63.5%, or $8.0 million, was capitalized.

With approval from the LPSC, the remaining uncapitalized costs were offset against Cleco Power’s existing storm damage reserves.

Note 20 — Calpine Bankruptcy Settlement

Bankruptcy Proceedings

In December 2005, the Calpine Debtors filed for protection under Chapter 11 of the U.S. Bankruptcy Code in the Calpine Debtors Bankruptcy Court. Prior to Cajun’s purchase, CAH, a wholly owned subsidiary of Calpine and one of the Calpine Debtors, owned a 50% interest in Acadia, and APH owned the other 50% interest in Acadia.

In December 2005, the Calpine Debtors filed a motion with the Calpine Debtors Bankruptcy Court seeking to reject the Calpine Tolling Agreements. In March 2006, the Calpine Debtors Bankruptcy Court entered an order permitting Acadia to suspend its obligations to CES under the Calpine Tolling Agreements in view of CES’s non-performance of the agreements.

Settlement Agreement

In April 2007, Cleco announced that a settlement agreement had been reached with Calpine, subject to the approval of the Calpine Debtors Bankruptcy Court, which resolved issues related to the Acadia Power Station. The settlement included the fixing of Acadia’s claims against the Calpine Debtors and an agreement by the parties to certain bidding procedures (Bidding Procedures) which governed the sale of CAH’s interest in Acadia and certain related assets (collectively, the CAH Assets). In May 2007, the Calpine Debtors Bankruptcy Court approved the terms of the settlement and entered orders approving the Claims Settlement Agreement and the Bidding Procedures Order.

The Claims Settlement Agreement addressed Acadia’s outstanding claims against the Calpine Debtors. Under the Claims Settlement Agreement, Acadia received a pre-petition general unsecured claim against each of CES and Calpine (as guarantor of CES’s obligations under the Calpine Tolling Agreements) for $185.0 million.

In May 2007, APH sold its claims of $85.0 million against CES and Calpine to JPMorgan Chase Bank, N.A. at 92% of face value. The pre-tax proceeds from this sale were $78.2 million which was included in APH’s equity income.

The Bidding Procedures Order set forth the procedures governing the sale of the CAH Assets. Under the Bidding Procedures Order, APH agreed to serve as the “stalking horse bidder” for the CAH Assets. APH’s agreement was subject to certain terms and conditions, including payment to APH of a $2.9 million break-up fee in the event APH was not the successful purchaser. APH and CAH entered into a purchase agreement whereby APH agreed to purchase the CAH Assets for $60.0 million plus assumed liabilities, subject to any higher or better offers.

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The Calpine Debtors Bankruptcy Court approved the transfer of the operations, maintenance and project management functions of the Acadia Power Station to subsidiaries of Midstream upon the closing of the CAH asset sale. A subsidiary of Calpine had been performing these functions since the Acadia Power Station became operational.

Acadia Auction Results

In July 2007, CAH conducted an auction for the CAH Assets. APH participated in the auction. At the conclusion of the auction, Cajun emerged as the successful bidder, with a price of $189.0 million.

In September 2007, after all regulatory approvals were received, the sale of CAH’s Assets to Cajun was completed. At the closing of the sale, APH received an $85.0 million payment from Cajun for the agreed upon value of the priority and guaranteed distributions, plus a $2.9 million break-up fee and other expense reimbursements. This $85.0 million payment is separate from APH’s $85.0 million pre-petition unsecured claim that it sold in May 2007. APH also acquired, for $1.25 million (subject, in certain circumstances, to reduction), Calpine’s interest in Acadia’s claim against Cleco Power regarding a potential electric metering error at the Acadia Power Station. APH recognized this as other expense on Cleco’s Consolidated Statements of Income.

At the completion of the sale, management reviewed the carrying value of APH’s 50% ownership in Acadia. Using Calpine’s sale as a market indicator of value, APH recognized an impairment charge of $45.8 million, which is the difference between the $234.8 million carrying value and the $189.0 million market value. The impairment charge is reflected in equity income from investees on Cleco’s Consolidated Statements of Income.

As a result of the closing and the subsequent settlement of future priority distribution payments owed to APH, the Acadia LLC Agreement was amended to remove APH’s priority distribution rights and give each member (APH and Cajun) a 50% ownership and economic interest in Acadia.

Note 21 — Accumulated Other Comprehensive Loss

The components of accumulated other comprehensive loss are summarized below for both Cleco and Cleco Power. Where applicable, transactions are reported net of income taxes.

Cleco

(THOUSANDS)	HOLDING GAINS ON AVAILABLE FOR SALE SECURITIES			LOSSES AND PRIOR SERVICE COST			NET GAIN (LOSS) ARISING DURING PERIOD			NET GAINS ON CASH FLOW HEDGES		TOTAL ACCUMULATED OTHER COMPREHENSIVE (LOSS) GAIN
Balance, December 31, 2007	$	73		$	(9,419	)	$	955		$	-	$	(8,391	)
Current-period change		(73	)		(215	)		(1,154	)		-		(1,442	)
Balance, December 31, 2008	$	-		$	(9,634	)	$	(199	)	$	-	$	(9,833	)
Current-period change		-			(160	)		(3,403	)		2,105		(1,458	)
Balance, December 31, 2009	$	-		$	(9,794	)	$	(3,602	)	$	2,105	$	(11,291	)

Cleco Power

(THOUSANDS)	LOSSES AND PRIOR SERVICE COST			NET GAIN (LOSS) ARISING DURING PERIOD			NET GAINS ON CASH FLOW HEDGES		TOTAL ACCUMULATED OTHER COMPREHENSIVE (LOSS) GAIN
Balance, December 31, 2007	$	(4,835	)	$	423		$	-	$	(4,412	)
Current-period change		(431	)		(333	)		-		(764	)
Balance, December 31, 2008	$	(5,266	)	$	90		$	-	$	(5,176	)
Current-period change		(433	)		(2,168	)		2,106		(495	)
Balance, December 31, 2009	$	(5,699	)	$	(2,078	)	$	2,106	$	(5,671	)

122

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CLECO POWER	2009 FORM 10-K

Note 22 — Miscellaneous Financial Information (Unaudited)

Cleco

Quarterly information for Cleco for 2009 and 2008 is shown in the following tables.

							2009
	1ST		2ND		3RD		4TH
(THOUSANDS, EXCEPT PER SHARE AMOUNTS)	QUARTER		QUARTER		QUARTER		QUARTER
Operating revenue	$	212,936	$	207,226	$	241,500	$	192,096
Operating income	$	17,238	$	31,867	$	40,677	$	17,027
Net income applicable to common stock	$	6,638	$	27,014	$	59,843	$	12,766
Basic net income per average share	$	.11	$	.45	$	.99	$	.21
Diluted net income per average common share	$	.11	$	.45	$	.99	$	.21
Dividends paid per common share	$	.225	$	.225	$	.225	$	.225
Closing market price per share
High	$	22.65	$	22.16	$	25.07	$	27.99
Low	$	18.52	$	19.72	$	21.35	$	24.16

							2008
	1ST		2ND		3RD		4TH
(THOUSANDS, EXCEPT PER SHARE AMOUNTS)	QUARTER		QUARTER		QUARTER		QUARTER
Operating revenue	$	222,551	$	274,787	$	343,675	$	239,185
Operating income	$	26,747	$	33,709	$	35,564	$	18,857
Net income applicable to common stock	$	22,060	$	29,377	$	37,121	$	13,537
Basic net income per average share	$	.37	$	.49	$	.62	$	.22
Diluted net income per average common share	$	.37	$	.49	$	.62	$	.22
Dividends paid per common share	$	.225	$	.225	$	.225	$	.225
Closing market price per share
High	$	27.18	$	24.73	$	26.88	$	25.37
Low	$	21.12	$	21.91	$	23.08	$	20.11

Cleco Corporation’s common stock is listed for trading on the New York Stock Exchange under the ticker symbol “CNL.” Cleco Corporation’s preferred stock is not listed on any stock exchange. On December 31, 2009, Cleco had 6,752 common shareholders and 86 preferred shareholders, as determined from the records of the transfer agent.

On January 29, 2010, Cleco Corporation’s Board of Directors declared a quarterly dividend of $0.225 per share payable on February 15, 2010, to common shareholders of record at the close of business on February 8, 2009. Preferred dividends also were declared payable March 1, 2010, to preferred shareholders of record at the close of business on February 16, 2010.

The Board of Directors of Cleco Corporation has approved a dividend policy that will increase its quarterly dividend rate, subject to future dividend declarations, from $0.225 per common share to $0.25 per common share beginning with the dividend payable May 15, 2010.

Cleco Power

Quarterly information for Cleco Power for 2009 and 2008 is shown in the following tables.

							2009
	1ST		2ND		3RD		4TH
(THOUSANDS)	QUARTER		QUARTER		QUARTER		QUARTER
Operating revenue	$	210,299	$	204,688	$	239,135	$	189,477
Operating income	$	16,876	$	33,073	$	40,651	$	20,862
Net income	$	15,018	$	30,206	$	43,552	$	22,390

							2008
	1ST		2ND		3RD		4TH
(THOUSANDS)	QUARTER		QUARTER		QUARTER		QUARTER
Operating revenue	$	220,450	$	272,889	$	341,342	$	237,001
Operating income	$	28,182	$	35,514	$	36,569	$	20,701
Net income	$	27,608	$	32,662	$	30,538	$	23,024

Note 23 — Subsequent Events

As of February 25, 2010, management has evaluated the potential recognition or disclosure of events or transactions that occurred in the period after the balance sheet date of December 31, 2009. The date February 25, 2010, represents the date that Cleco issued the financial statements for the year ended December 31, 2009.

Rodemacher Unit 3

On February 12, 2010, Cleco Power began commercial operations of Rodemacher Unit 3 and began using the new retail rate plan approved by the LPSC in October 2009.

Cleco Corporation Debt Issuance

On February 19, 2010, Cleco Corporation entered into a $150.0 million aggregate principal amount one-year bank term loan, which matures in 2011. The interest rate for the bank term loan was one-month LIBOR plus 2.75%.

Evangeline Transactions

On February 22, 2010, Evangeline and JPMVEC entered into the Evangeline Restructuring Agreement where the parties agreed to terminate the existing Evangeline Tolling Agreement and enter into the Evangeline 2010 Tolling Agreement, effective March 1, 2010. The other significant terms of the Evangeline Restructuring Agreement are:

The tolling agreement is a market-based tolling agreement, for Evangeline’s generating Units 6 and 7, ending December 31, 2011, with an option for JPMVEC to extend the term through December 31, 2012. The agreement also gives Evangeline the right to terminate its Unit 6 obligations prior to the expiration of the term;

§	$126.6 million of Evangeline’s 8.82% Senior Secured bonds due 2019, owned by JPMVEC, were transferred to Evangeline and subsequently retired; and $5.3 million of accrued interest associated with the bonds transferred to Evangeline was eliminated;

§	JPMVEC paid Evangeline $56.7 million; and

§	JPMVEC returned Cleco Corporation’s $15.0 million letter of credit issued under the Evangeline Tolling Agreement and the letter of credit was terminated.

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CLECO POWER	2009 FORM 10-K

The termination of the Evangeline Tolling Agreement was considered a termination of an operating lease and a triggering event requiring an asset impairment analysis. The $56.7 million cash payment from JPMVEC was partially a settlement of the $26.9 million operating lease asset that represented the straight line recognition of a fixed escalation. Management is currently evaluating the asset impairment analysis on Evangeline’s assets and related CLE Intrastate assets which at January 31, 2010, had a carrying value of $182.8 million and $0.8 million, respectively.

The terms of the Evangeline Restructuring Agreement, Evangeline issued an irrevocable redemption notice to call the remaining $35.2 million of 8.82% Senior Secured bonds outstanding, and paid the debt holders $1.5 million of accrued interest and a $10.2 million make-whole payment. As a result of the debt retirement, Evangeline will expense $2.2 million in unamortized debt issuance costs associated with the Evangeline bonds. The Evangeline bonds were non-recourse to Cleco Corporation and redemption of the bonds is permitted under Cleco Corporation’s revolving credit facility. Under the redemption of the bonds, $30.1 million of restricted cash will be released to Evangeline. Management is currently evaluating the result of any gain or loss resulting from these transactions.

Evangeline is contained within the Midstream segment where the impacts to these transactions will be reflected. In accordance with the authoritative guidance, effective January 1, 2010, the financial results for Evangeline will no longer be presented as equity income, but presented in the appropriate line items in the consolidated financials of Midstream.

Acadia Transaction

On February 23, 2010, the acquisition by Cleco Power of one of Acadia’s two 580-MW units, the related materials and supplies, and half of its common facilities was completed. The significant terms of the transaction are:

§	Cleco Power acquired one of Acadia’s two 580-MW units, the related materials and supplies, and half of the common facilities for $304.0 million;

§	Acadia will recognize a gain of approximately $87 million;

§	APH received $6.7 million from an affiliate of Cajun for indemnification of Cajun and its affiliates against 100% of APH’s liabilities and other obligations related to the Cleco Power transaction; and

§	Cleco Power will own and operate the unit, and operate the other unit on behalf of Acadia or a future owner.

City of Alexandria Settlement

On February 23, 2010, the Alexandria City Council approved a settlement of the case which included a $3.0 million litigation expense reimbursement to the City and a new five-year, energy-only power supply agreement. The supply agreement may be extended, at Cleco Power’s option, for two additional one-year terms. If the City performs its obligations under the new power supply agreement, then Cleco will pay a one-time $6.5 million performance bonus at the end of the five-year term to the City. The court dismissed the case with prejudice on February 24, 2010.

ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE

None.

ITEM 9A. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

As of December 31, 2009, evaluations were performed under the supervision and with the participation of Cleco Corporation and Cleco Power LLC (individually, “Registrant” and collectively, the “Registrants”) management, including the Chief Executive Officer (CEO) and Chief Financial Officer (CFO). The evaluations assessed the effectiveness of the Registrants’ disclosure controls and procedures. Based on the evaluations, the CEO and CFO have concluded that the Registrants’ disclosure controls and procedures are effective to ensure that information required to be disclosed by each Registrant in reports that it files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in Securities and Exchange Commission rules and forms; and that the Registrants’ disclosure controls and procedures are also effective in ensuring that such information is accumulated and communicated to the Registrants’ management, including the CEO and CFO, as appropriate to allow timely decisions regarding required disclosure.

Changes in Internal Controls over Financial Reporting

Under the supervision and with the participation of the Registrants’ management, including the CEO and CFO, the Registrants evaluated changes in internal control over financial reporting that occurred during the quarter ended December 31, 2009, and found no change that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

Management’s Reports on Internal Control Over Financial Reporting

The management of Cleco Corporation and Cleco Power is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Rule 13a-15(f) or 15d-15(f) promulgated under the Securities Exchange Act of 1934. Cleco Corporation’s and Cleco Power’s internal control over financial reporting is a process designed by, or under the supervision of, each of Cleco Corporation’s and Cleco Power’s principal executive and financial officers and effected by Cleco Corporation’s and Cleco Power’s board of directors or managers, as the case may be, management and other personnel, to provide reasonable assurance

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regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with accounting principles generally accepted in the United States of America.

Management has designed its internal control over financial reporting to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements in accordance with accounting principles generally accepted in the United States of America. Management’s assessments included review and testing of both the design effectiveness and operating effectiveness of controls over relevant assertions related to significant accounts and disclosures in the financial statements.

All internal control systems, no matter how well designed, have inherent limitations. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation.

The management of Cleco Corporation and Cleco Power, under the supervision of each of the Registrants’ principal executive officer and principal financial officer, conducted an assessment of the effectiveness of Cleco Corporation’s and Cleco Power’s respective internal control over financial reporting as of December 31, 2009. In making this assessment, management used the criteria in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on this assessment, the management of Cleco Corporation and Cleco Power concluded that, as of December 31, 2009, the Registrants’ internal control over financial reporting was effective.

The effectiveness of Cleco Corporation’s and Cleco Power’s internal control over financial reporting as of December 31, 2009, has been audited by PricewaterhouseCoopers LLP, an independent registered public accounting firm, as stated in their reports which appear on pages 65 and 66, respectively, of this Annual Report on Form 10-K.

Certifications

The certifications of the Registrants’ Chief Executive Officer and Chief Financial Officer required by Section 302 of the Sarbanes-Oxley Act of 2002 are filed as Exhibits 31.1, 31.2, 31.3, and 31.4 to this Annual Report on Form 10-K. Additionally, as required by Section 303A.12(a) of the New York Stock Exchange (“NYSE”) Listed Company Manual, Cleco’s Chief Executive Officer filed a certification with the NYSE on May 7, 2009, reporting that he was not aware of any violation by Cleco of the NYSE’s Corporate Governance listing standards.

ITEM 9B. OTHER INFORMATION

Stock Award to Mr. Madison

On February 22, 2010, the Board of Directors of Cleco Corporation approved a special award in the amount of 15,000 shares of Cleco Corporation common stock to Mr. Michael H. Madison, President and Chief Executive Officer of Cleco Corporation. This award was made pursuant to the 2010 LTICP. The shares will be restricted until May 26, 2013. During the restricted period, Mr. Madison may not sell, assign, transfer, pledge or otherwise dispose of the shares. Dividends will accrue on the shares during the restricted period without interest and will be paid to Mr. Madison upon the lapse of the restrictions. The shares (and any accrued dividends thereon) will be forfeited if Mr. Madison is no longer an employee of Cleco Corporation (other than because of death or disability) before the end of the restricted period. Upon a Change of Control (as defined in the 2010 LTICP), the restrictions will lapse and the shares (and any accrued dividends) will be delivered to Mr. Madison. The Compensation Committee or the Board of Directors may amend the terms and conditions of the award.

Acadia Transaction

§	Cleco Power acquired one of Acadia’s two 580-MW units, the related materials and supplies, and half of the common facilities for $304.0 million;

§	Acadia will recognize a gain of approximately $87 million;

§	APH received $6.7 million from an affiliate of Cajun for indemnification of Cajun and its affiliates against 100% of APH’s liabilities and other obligations related to the Cleco Power transaction; and

§	Cleco Power will own and operate the unit, and operate the other unit on behalf of Acadia or a future owner.

125

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CLECO POWER	2009 FORM 10-K

PART III

ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE OF THE REGISTRANTS

Audit Committee Financial Expert

Cleco’s board of directors has determined that Mr. W. Larry Westbrook, who serves as the Chairman of the Audit Committee of the Board of Directors, fulfills the requirements for an independent audit committee financial expert for both Cleco Corporation and Cleco Power.

Financial Manager’s Code of Conduct

Both Cleco Corporation and Cleco Power have a code of conduct that applies to their principal executive officer, principal financial officer, principal accounting officer, and treasurer. This code of conduct is posted on Cleco’s homepage on the Internet’s World Wide Web located at http://www.cleco.com. This code of conduct also is available free of charge by request sent to: Shareholder Services, Cleco, P.O. Box 5000, Pineville, LA 71361-5000.

CLECO

The information set forth, (i) under the caption “Proposal Number I — Election of Four Class I Directors,” (ii) under the caption “Section 16(a) Beneficial Ownership Reporting Compliance” and (iii) under the caption “Report of the Audit Committee” in the 2010 Proxy Statement relating to the Annual Meeting of Shareholders to be held on April 30, 2010, filed with the SEC pursuant to Regulation 14A under the Securities Exchange Act of 1934 (2010 Proxy Statement), is incorporated herein by reference. See also “Part I — Item 4 — Board of Directors of Cleco.”

CLECO POWER

The information called for by Item 10 with respect to Cleco Power is omitted pursuant to General Instruction I(2)(c) to Form 10-K (Omission of Information by Certain Wholly Owned Subsidiaries).

ITEM 11. EXECUTIVE COMPENSATION

CLECO

The information set forth, (i) under the subcaption “Independence and Organization of the Board of Directors” under the caption “Proposal Number I — Election of Four Class I Directors,” (ii) under the caption “Compensation Discussion and Analysis,” (iii) under the caption “Executive Officers Compensation,” (iv) under the caption “Director Compensation,” and (v) under the caption “Report of the Compensation Committee” in the 2010 Proxy Statement is incorporated herein by reference.

CLECO POWER

The information called for by Item 11 with respect to Cleco Power is omitted pursuant to General Instruction I(2)(c) to Form 10-K (Omission of Information by Certain Wholly Owned Subsidiaries).

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CLECO POWER	2009 FORM 10-K

ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS

CLECO

Security Ownership

The information set forth, (i) under the caption “Security Ownership of Directors and Management” and (ii) under the caption “Security Ownership of Certain Beneficial Owners” in the 2010 Proxy Statement is incorporated herein by reference.

Equity Compensation Plan Information

Cleco has compensation plans under which equity securities of Cleco Corporation are authorized for issuance as approved by security holders. Cleco does not have such plans that have not been approved by security holders. The table below provides information about compensation plans under which equity securities of Cleco Corporation were authorized for issuance at December 31, 2009.

PLAN CATEGORY	NUMBER OF SECURITIES TO BE ISSUED UPON EXERCISE OF OUTSTANDING OPTIONS, WARRANTS OR RIGHTS	WEIGHTED-AVERAGE EXERCISE PRICE OF OUTSTANDING OPTIONS, WARRANTS AND RIGHTS	NUMBER OF SECURITIES REMAINING AVAILABLE FOR FUTURE ISSUANCE UNDER EQUITY COMPENSATION PLANS (EXCLUDING SECURITIES REFLECTED IN COLUMN (a))
	(a)	(b)	(c)
Equity compensation plans approved by security holders
Employee Stock Purchase Plan	2,785 (1)	$25.96	464,703
Long-term incentive compensation plans (expires January 1, 2010)	286,183	$21.20	1,133,703(2)
Long-term incentive compensation plans (effective January 1, 2010)	-	$ -	2,250,000
Total	288,968	$21.25	3,848,406
(1) The number of options in column (a) for the Employee Stock Purchase Plan represents the number of options granted at December 31, 2009, based on employee withholdings and the option grant calculation under the plan.
(2) Stock options and restricted stock may be issued pursuant to the 2000 LTICP. This plan requires the number of securities available to be issued to be reduced by the number of options and the number of restricted shares previously awarded, net of forfeitures. At December 31, 2009, there were 284,415 shares of restricted stock awarded, net of forfeitures, pursuant to the 2000 LTICP. New options or restricted stock cannot be issued pursuant to the 2000 LTICP, which expired on December 31, 2009. However, stock options issued prior to December 31, 2009 under the 2000 LTICP remain outstanding until they expire.

For additional information on compensation plans using equity securities, see Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 7 — Common Stock.” This information should be read in conjunction with the Consolidated Financial Statements and related Notes thereto.

CLECO POWER

The information called for by Item 12 with respect to Cleco Power is omitted pursuant to General Instruction I(2)(c) to Form 10-K (Omission of Information by Certain Wholly Owned Subsidiaries).

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE

CLECO

The information set forth under the subcaptions “Independence and Organization of the Board of Directors,” and “Cleco’s Code of Business Conduct & Ethics” under the caption “Proposal Number I — Election of Four Class I Directors” in the 2010 Proxy Statement is incorporated herein by reference.

CLECO POWER

The information called for by Item 13 with respect to Cleco Power is omitted pursuant to General Instruction I(2)(c) to Form 10-K (Omission of Information by Certain Wholly Owned Subsidiaries).

ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES

CLECO

The information set forth under “Relationship with Accountants” regarding fees paid to Cleco’s independent auditors in the 2010 Proxy Statement is incorporated herein by reference.

CLECO POWER

The information set forth under “Relationship with Accountants” regarding fees paid to Cleco’s independent auditors in the 2010 Proxy Statement is incorporated herein by reference.

PricewaterhouseCoopers LLP provides professional services for Cleco Power that are directly billed to Cleco Corporation, the cost of which is allocated to Cleco Power though not billed directly to them.

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CLECO POWER	2009 FORM 10-K

PART IV

ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES

		FORM 10-K ANNUAL REPORT
	Report of Independent Registered Public Accounting Firm	65
	Report of Independent Registered Public Accounting Firm	66
15(a)(1)	Financial Statements of Cleco Corporation
	Consolidated Statements of Income for the years ended December 31, 2009, 2008, and 2007	67
	Consolidated Balance Sheets at December 31, 2009, and 2008	68
	Consolidated Statements of Cash Flows for the years ended December 31, 2009, 2008, and 2007	70
	Consolidated Statements of Comprehensive Income for the years ended December 31, 2009, 2008, and 2007	72
	Consolidated Statements of Changes in Common Shareholders’ Equity for the years ended December 31, 2009, 2008, and 2007	72
	Financial Statements of Cleco Power
	Cleco Power Consolidated Statements of Income for the years ended December 31, 2009, 2008, and 2007	73
	Cleco Power Consolidated Balance Sheets at December 31, 2009, and 2008	74
	Cleco Power Consolidated Statements of Cash Flows for the years ended December 31, 2009, 2008, and 2007	75
	Cleco Power Consolidated Statements of Comprehensive Income for the years ended December 31, 2009, 2008, and 2007	76
	Cleco Power Consolidated Statements of Changes in Member’s Equity for the years ended December 31, 2009, 2008, and 2007	76
	Notes to the Financial Statements	77
15(a)(2)	Financial Statement Schedules
	Schedule I — Financial Statements of Cleco Corporation
	Condensed Statements of Income for the years ended December 31, 2009, 2008, and 2007	133
	Condensed Balance Sheets at December 31, 2009, and 2008	134
	Condensed Statements of Cash Flows for the years ended December 31, 2009, 2008, and 2007	135
	Notes to the Condensed Financial Statements	136
	Schedule II — Valuation and Qualifying Accounts
	Cleco Corporation	138
	Cleco Power	138
15(c)(1)	Schedule III — Consolidated Financial Statements of Acadia Power Partners, LLC
	Report of Independent Registered Public Accounting Firm	141
	Consolidated Statements of Income for the years ended December 31, 2009, 2008, and 2007	142
	Consolidated Balance Sheets at December 31, 2009, and 2008	143
	Consolidated Statements of Cash Flows for the years ended December 31, 2009, 2008, and 2007	144
	Consolidated Statements of Changes in Members’ Capital for the years ended December 31, 2009, 2008, and 2007	145
	Notes to the Consolidated Financial Statements	146
	Financial Statement Schedules other than those shown in the above index are omitted because they are either not required or are not applicable or the required information is shown in the Consolidated Financial Statements and Notes thereto
15(a)(3)	List of Exhibits	129

The Exhibits designated by an asterisk are filed herewith, except for Exhibits 32.1, 32.2, 32.3, and 32.4, which are furnished herewith (and not filed for purposes of Section 18 of the Securities Exchange Act of 1934 or otherwise subject to the liability of that section). The Exhibits not so designated previously have been filed with the SEC and are incorporated herein by reference. The Exhibits designated by two asterisks are management contracts and compensatory plans and arrangements required to be filed as Exhibits to this Report.

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CLECO POWER	2009 FORM 10-K

EXHIBITS

CLECO		SEC FILE OR REGISTRATION NUMBER	REGISTRATION STATEMENT OR REPORT	EXHIBIT NUMBER
3(a)(1)	Articles of Incorporation of the Company, effective July 1, 1999	333-71643-01	S-4(6/30/99)	A
3(a)(2)	Articles of Amendment to the Amended and Restated Articles of Incorporation of Cleco setting forth the terms of the $25 Preferred Stock	1-15759	8-K(7/28/00)	1
3(a)(3)	Articles of Amendment to the Amended and Restated Articles of Incorporation to increase amount authorized common stock and to effect a two-for-one split of the Company’s common stock	1-15759	2001 Proxy Statement (3/01)	B-1
3(b)(1)	Bylaws of Cleco Corporation, Revised effective July 1, 2009	1-15759	10-Q(6/09)	3.1
3(b)(2)	Amendment to the Bylaws of Cleco Corporation, effective October 30, 2010	1-15759	10-Q(9/09)	3.1
4(a)(1)	Indenture of Mortgage dated as of July 1, 1950, between Cleco Power (as successor) and First National Bank of New Orleans, as Trustee	1-5663	10-K(1997)	4(a)(1)
4(a)(2)	First Supplemental Indenture dated as of October 1, 1951, to Exhibit 4(a)(1)	1-5663	10-K(1997)	4(a)(2)
4(a)(3)	Second Supplemental Indenture dated as of June 1, 1952, to Exhibit 4(a)(1)	1-5663	10-K(1997)	4(a)(3)
4(a)(4)	Third Supplemental Indenture dated as of January 1, 1954, to Exhibit 4(a)(1)	1-5663	10-K(1997)	4(a)(4)
4(a)(5)	Fourth Supplemental Indenture dated as of November 1, 1954, to Exhibit 4(a)(1)	1-5663	10-K(1997)	4(a)(5)
4(a)(6)	Tenth Supplemental Indenture dated as of September 1, 1965, to Exhibit 4(a)(1)	1-5663	10-K(1986)	4(a)(11)
4(a)(7)	Eleventh Supplemental Indenture dated as of April 1, 1969, to Exhibit 4(a)(1)	1-5663	10-K(1998)	4(a)(8)
4(a)(8)	Eighteenth Supplemental Indenture dated as of December 1, 1982, to Exhibit 4(a)(1)	1-5663	10-K(1993)	4(a)(8)
4(a)(9)	Nineteenth Supplemental Indenture dated as of January 1, 1983, to Exhibit 4(a)(1)	1-5663	10-K(1993)	4(a)(9)
4(a)(10)	Twenty-Sixth Supplemental Indenture dated as of March 15, 1990, to Exhibit 4(a)(1)	1-5663	8-K(3/90)	4(a)(27)
4(b)(1)	Indenture between Cleco Power (as successor) and Bankers Trust Company, as Trustee, dated as of October 1, 1988	33-24896	S-3(10/11/88)	4(b)
4(b)(2)	Agreement Appointing Successor Trustee dated as of April 1, 1996, by and among Central Louisiana Electric Company, Inc., Bankers Trust Company, and The Bank of New York	333-02895	S-3(4/29/96)	4(a)(2)
4(b)(3)	First Supplemental Indenture, dated as of December 1, 2000, between Cleco Utility Group Inc. and the Bank of New York	333-52540	S-3/A(1/26/01)	4(a)(2)
4(b)(4)	Second Supplemental Indenture, dated as of January 1, 2001, between Cleco Power LLC and The Bank of New York	333-52540	S-3/A(1/26/01)	4(a)(3)
4(b)(5)	Third Supplemental Indenture, dated as of April 26, 2001, between Cleco Power LLC and the Bank of New York	1-5663	8-K(4/26/01)	4(a)
4(b)(6)	Fourth Supplemental Indenture, dated as of February 1, 2002, between Cleco Power LLC and the Bank of New York	1-5663	8-K(2/6/02)	4.1
4(b)(7)	Sixth Supplemental Indenture providing for the issuance of $75,000,000 principal amount of 5.375% Notes due May 1, 2013	1-5663	8-K(4/28/03)	4.1
4(b)(8)	Seventh Supplemental Indenture, dated as of July 6, 2005, between Cleco Power LLC and the Bank of New York Trust Company, N.A.	1-5663	8-K(7/6/05)	4.1
4(b)(9)	Eighth Supplemental Indenture, dated as of November 30, 2005, between Cleco Power LLC and the Bank of New York Trust Company, N.A.	1-5663	8-K(11/28/05)	4.1
4(b)(10)	Ninth Supplemental Indenture, dated as of June 3, 2008, between Cleco Power LLC and The Bank of New York Trust Company, N.A.	1-5663	8-K(6/2/08)	4.1
4(c)	Agreement Under Regulation S-K Item 601(b)(4)(iii)(A)	1-5663	10-Q(9/99)	4(c)
4(d)(1)	Rights agreement between Cleco and EquiServe Trust Company, as Right Agent	1-15759	8-K(7/28/00)	1
4(d)(2)	First Amendment to Rights Agreement between Cleco Corporation and Computershare Trust Company, N.A., as Rights Agent	1-15759	8-K(3/2/06)	4.1
**10(a)(1)	2000 Long-Term Incentive Compensation Plan	333-71643-01	2000 Proxy Statement(3/00)	A
**10(a)(2)	2000 Long-Term Incentive Compensation Plan, Amendment Number 1, Effective as of December 12, 2003	1-15759	10-Q(3/05)	10(a)
**10(a)(3)	2000 Long-Term Incentive Compensation Plan, Amendment Number 2, Effective as of July 23, 2004	1-15759	10-Q(9/04)	10(a)
**10(a)(4)	2000 Long-Term Incentive Compensation Plan, Amendment Number 3, Dated as of January 28, 2005	1-15759	10-Q(3/05)	10(b)
**10(a)(5)	2000 Long-Term Incentive Compensation Plan, Amendment Number 4, Dated as of November 4, 2008	1-15759	10-K(2008)	10(a)(6)
**10(a)(6)	2000 Long-Term Incentive Compensation Plan, Amendment Number 5, Dated as of December 8, 2008	1-15759	8-K(12/9/08)	10.1
**10(a)(7)	2000 Long-Term Incentive Compensation Plan, Administrative Procedure No. 1	1-15759	10-K(2005)	10(a)(6)
10(a)(8)	Form of Notice and Acceptance of Directors’ Grant of Nonqualified Stock Options under Cleco’s 2000 Long-Term Incentive Compensation Plan	1-15759	10-Q(6/00)	10(a)
10(a)(9)	Form of Notice and Acceptance of Grant of Nonqualified Stock Options, with fixed option price under Cleco’s 2000 Long-Term Incentive Compensation Plan	1-15759	10-Q(6/00)	10(c)
10(a)(10)	Form of Notice and Acceptance of Grant of Nonqualified Stock Options, with variable option price under Cleco’s 2000 Long-Term Incentive Compensation Plan	1-15759	10-Q(6/00)	10(d)
**10(a)(11)	Form of Notice and Acceptance of Director’s Grant of Nonqualified Stock Option	1-5663	10-Q(9/01)	10
10(a)(12)	Form of Notice and Acceptance of Grant of Restricted Stock under Cleco’s 2000 Long-Term Incentive Compensation Plan	1-15759	10-Q(6/00)	10(b)
10(a)(13)	Notice and Acceptance of Grant of Restricted Stock and Allocation of Opportunity Shares	1-15759	10-Q(9/05)	10(c)
10(a)(14)	Notice and Acceptance of Grant of Restricted Stock and Common Stock Equivalent Units and Allocation of Opportunity Shares and Opportunity Common Stock Equivalent Units – 2007 Performance Cycle	1-15759	10-K(2006)	10(n)(3)
10(a)(15)	Notice and Acceptance of Grant of Restricted Stock and Common Stock Equivalent Units and Allocation of Opportunity Shares and Opportunity Common Stock Equivalent Units – 2008 Performance Cycle	1-15759	10-K(2007)	10(m)(4)
10(a)(16)	Notice and Acceptance of Grant of Restricted Stock and Common Stock Equivalent Units and Allocation of Opportunity Shares and Opportunity Common Stock Equivalent Units – 2009 Performance Cycle	1-15759	10-K(2008)	10(m)(4)

129

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

CLECO		SEC FILE OR REGISTRATION NUMBER	REGISTRATION STATEMENT OR REPORT	EXHIBIT NUMBER
**10(b)(1)	Annual Incentive Compensation Plan amended and restated as of January 23, 2003	1-15759	10-K(2003)	10(b)
**10(b)(2)	First Amendment to Annual Incentive Compensation Plan, effective as of January 1, 2009	1-15759	10-K(2008)	10(b)(2)
**10(b)(3)	Participation Agreement, Annual Incentive Compensation Plan	1-5663	10-K(1995)	10(c)
**10(c)(1)	Deferred Compensation Plan for Directors	1-5663	10-K(1992)	10(n)
**10(c)(2)	Summary of Director Compensation, Benefits and Policies, revised on July 31, 2009	1-15759	10-Q(9/09)	10.1
**10(d)(1)	Supplemental Executive Retirement Plan	1-5663	10-K(1992)	10(o)(1)
**10(d)(2)	First Amendment to Supplemental Executive Retirement Plan effective July 1, 1999	1-15759	10-K(2003)	10(e)(1)(a)
**10(d)(3)	Second Amendment to Supplemental Executive Retirement Plan dated July 28, 2000	1-15759	10-K(2003)	10(e)(1)(b)
**10(d)(4)	Supplemental Executive Retirement Plan Amended and Restated January 1, 2009	1-15759	10-K(2008)	10(f)(4)
**10(d)(5)	Supplemental Executive Retirement Plan (Amended and Restated January 1, 2009), Amendment No. 1	1-15759	8-K(12/9/08)	10.3
**10(d)(6)	Supplemental Executive Retirement Trust dated December 13, 2000	1-15759	10-K(2003)	10(e)(1)(c)
**10(d)(7)	Supplemental Executive Retirement Plan Participation Agreement between Cleco and Dilek Samil	1-15759	10-K(2002)	10(z)(1)
**10(d)(8)	Supplemental Executive Retirement Plan Participation Agreement between Cleco and Michael H. Madison	1-15759	10-K(2004)	10(v)(3)
**10(e)(1)	Executive Employment Agreement between Cleco Corporation and George W. Bausewine effective as of May 5, 2009	1-15759	10-Q(6/09)	10.1
**10(e)(2)	Executive Employment Agreement Compliance Addendum – Code Section 409A, effective January 1, 2009	1-15759	8-K(12/9/08)	10.4
**10(e)(3)	Form of Cleco Corporation Executive Employment Agreement (Level 1)	1-15759	8-K(1/9/09)	10.1
**10(e)(4)	Executive Employment Agreement between Cleco Corporation and Darren J. Olagues dated July 30, 2007	1-15759	8-K(4/28/09)	10.1
10(e)(5)*	Executive Employment Agreement (Level 1) between Cleco Corporation and Michael H. Madison, effective October 1, 2009
10(e)(6)*	Executive Employment Agreement (Level 1) between Cleco Corporation and Dilek Samil effective, January 1, 2009
10(e)(7)*	Executive Employment Agreement (Level 2) between Cleco Corporation and William G. Fontenot, effective July 28, 2009
10(e)(8)*	Executive Employment Agreement (Level 2) between Cleco Corporation and R. Russell Davis, effective July 28, 2009
10(e)(9)*	Executive Employment Agreement (Level 1) and addendum to Executive Employment Agreement (Level 1) between Cleco Corporation and Wade A. Hoefling, effective January 29, 2010
10(f)	401(k) Savings and Investment Plan Trust Agreement dated as of August 1, 1997, between UMB Bank, N.A. and Cleco	1-5663	10-K(1997)	10(m)
**10(g)(1)	2010 Long-Term Incentive Compensation Plan, effective as of January 1, 2010	1-15759	2009 Proxy Statement (3/12/09)	C
10(g)(2)*	Notice and Acceptance of Grant of Restricted Stock and Common Stock Equivalent Units and Allocation of Opportunity Shares and Opportunity Common Stock Equivalent Units – 2010 Performance Cycle
10(h)(1)	Cleco Corporation Employee Stock Purchase Plan	333-44364	S-8(8/23/00)	4.3
10(h)(2)	Employee Stock Purchase Plan, Amendment No. 1, dated January 22, 2004	1-15759	10-K(2003)	10(s)(1)
10(h)(3)	Employee Stock Purchase Plan, Amendment No. 2, effective as of January 1, 2006	1-15759	10-Q(6/05)	10(a)
**10(i)(1)	Cleco Corporation Deferred Compensation Plan	333-59696	S-8(4/27/01)	4.3
**10(i)(2)	First Amendment to Cleco Corporation Deferred Compensation Plan	1-15759	10-K(2008)	10(n)(5)
**10(i)(3)	Cleco Corporation Deferred Compensation Plan, Corrective Section 409A Amendment	1-15759	8-K(12/9)08)	10.2
10(i)(4)	Deferred Compensation Trust dated January 2001	1-15759	10-K(2003)	10(u)
10(j)(1)	First Amended and Restated Credit Agreement dated as of June 2, 2006 among Cleco Corporation, The Bank of New York, as Administrative Agent, and the lenders and other parties thereto	1-15759	10-Q(9/09)	10.2
10(j)(2)	Amendment No. 1 and Waiver No. 1 dated as of August 18, 2009, to and under the First Amended and Restated Credit Agreement, dated as of June 2, 2006, among Cleco Corporation and the Lenders party thereto	1-15759	10-Q(9/09)	10.4
*10(j)(3)	Loan Agreement dated as of February 19, 2010, among Cleco Corporation, JPMorgan Chase Bank, N.A., as Administrative Agent, and the lenders party thereto
10(k)(1)	Acadia Power Partners – Second amended and restated limited liability company agreement dated May 9, 2003	1-15759	10-Q(9/09)	10.3
10(k)(2)	Acadia Power Partners, LLC – First Amendment to Second Amended and Restated Limited Liability Company Agreement dated August 9, 2005	1-15759	10-Q(9/05)	10(a)
*12(a)	Computation of Ratios of Earnings (loss) to Fixed Charges and of Earnings (loss) to Combined Fixed Charges and Preferred Stock Dividends
*21	Subsidiaries of the Registrant
*23(a)	Consent of Independent Registered Public Accounting Firm
*23(c)	Consent of Independent Registered Public Accounting Firm
*24(a)	Power of Attorney from each Director of Cleco Corporation whose signature is affixed to this Form 10-K for the year ended December 31, 2009
*31.1	CEO Certification in accordance with section 302 of the Sarbanes-Oxley Act of 2002
*31.2	CFO Certification in accordance with section 302 of the Sarbanes-Oxley Act of 2002
*32.1	CEO Certification pursuant to section 906 of the Sarbanes-Oxley Act of 2002
*32.2	CFO Certification pursuant to section 906 of the Sarbanes-Oxley Act of 2002

130

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

CLECO POWER		SEC FILE OR REGISTRATION NUMBER	REGISTRATION STATEMENT OR REPORT	EXHIBIT NUMBER
3(a)	Articles of Organization and Initial Report of Cleco Power LLC, dated December 11, 2000	533-52540	S-3/A(1/26/01)	3(a)
3(b)	Operating Agreement of Cleco Power LLC (revised effective July 1, 2009)	1-5663	10-Q(6/09)	3.2
4(a)(1)	Indenture of Mortgage dated as of July 1, 1950, between the Company and First National Bank of New Orleans, as Trustee	1-5663	10-K(1997)	4(a)(1)
4(a)(2)	First Supplemental Indenture dated as of October 1, 1951, to Exhibit 4(a)(1)	1-5663	10-K(1997)	4(a)(2)
4(a)(3)	Second Supplemental Indenture dated as of June 1, 1952, to Exhibit 4(a)(1)	1-5663	10-K(1997)	4(a)(3)
4(a)(4)	Third Supplemental Indenture dated as of January 1, 1954, to Exhibit 4(a)(1)	1-5663	10-K(1997)	4(a)(4)
4(a)(5)	Fourth Supplemental Indenture dated as of November 1, 1954, to Exhibit 4(a)(1)	1-5663	10-K(1997)	4(a)(5)
4(a)(6)	Tenth Supplemental Indenture dated as of September 1, 1965, to Exhibit 4(a)(1)	1-5663	10-K(1986)	4(a)(11)
4(a)(7)	Eleventh Supplemental Indenture dated as of April 1, 1969, to Exhibit 4(a)(1)	1-5663	10-K(1998)	4(a)(8)
4(a)(8)	Eighteenth Supplemental Indenture dated as of December 1, 1982, to Exhibit 4(a)(1)	1-5663	10-K(1993)	4(a)(8)
4(a)(9)	Nineteenth Supplemental Indenture dated as of January 1, 1983, to Exhibit 4(a)(1)	1-5663	10-K(1993)	4(a)(9)
4(a)(10)	Twenty-Sixth Supplemental Indenture dated as of March 15, 1990, to Exhibit 4(a)(1)	1-5663	8-K(3/90)	4(a)(27)
4(b)(1)	Indenture between the Company and Bankers Trust Company, as Trustee, dated as of October 1, 1988	33-24896	S-3(10/11/88)	4(b)
4(b)(2)	Agreement Appointing Successor Trustee dated as of April 1, 1996, by and among Central Louisiana Electric Company, Inc., Bankers Trust Company, and The Bank of New York	333-02895	S-3(4/26/96)	4(a)(2)
4(b)(3)	First Supplemental Indenture, dated as of December 1, 2000, between Cleco Utility Group Inc. and the Bank of New York	333-52540	S-3/A(1/26/01)	4(a)(2)
4(b)(4)	Second Supplemental Indenture, dated as of January 1, 2001, between Cleco Power LLC and The Bank of New York	333-52540	S-3/A(1/26/01)	4(a)(3)
4(b)(5)	Third Supplemental Indenture, dated as of April 26, 2001, between Cleco Power LLC and the Bank of New York	1-5663	8-K(4/26/01)	4(a)
4(b)(6)	Fourth Supplemental Indenture, dated as of February 1, 2002, between Cleco Power LLC and the Bank of New York	1-5663	8-K(2/6/02)	4.1
4(b)(7)	Sixth Supplemental Indenture providing for the issuance of $75,000,000 principal amount of 5.375% Notes due May 1, 2013	1-5663	8-K(4/28/03)	4.1
4(b)(8)	Seventh Supplemental Indenture, dated as of July 6, 2005, between Cleco Power LLC and the Bank of New York Trust Company, N.A.	1-5663	8-K(7/6/05)	4.1
4(b)(9)	Eighth Supplemental Indenture, dated as of November 30, 2005, between Cleco Power LLC and the Bank of New York Trust Company, N.A.	1-5663	8-K(11/28/05)	4.1
4(b)(10)	Ninth Supplemental Indenture, dated as of June 3, 2008, between Cleco Power LLC and The Bank of New York Trust Company, N.A.	1-5663	8-K(6/2/08)	4.1
4(b)(11)	Tenth Supplemental Indenture, dated as of November 13, 2009, between Cleco Power LLC and The Bank of New York Mellon Trust Company, N.A. (as successor trustee)	1-5663	8-K(11/12/09)	4.1
4(c)	Agreement Under Regulation S-K Item 601(b)(4)(iii)(A)	333-71643-01	10-Q(9/99)	4(c)
4(d)	Loan Agreement, dated as of November 1, 2006, between Cleco Power LLC and the Rapides Finance Authority	1-5663	8-K(11/27/06)	4.1
4(e)	Loan Agreement, dated as of November 1, 2007, between Cleco Power LLC and the Rapides Finance Authority	1-5663	8-K(11/20/07)	4.1
4(f)	Loan Agreement, dated as of October 1, 2008, between Cleco Power LLC and the Rapides Finance Authority
4(g)	Loan Agreement, dated as of December 1, 2008, between Cleco Power LLC and the Louisiana Public Facilities Authority
**10(a)(1)	Supplemental Executive Retirement Plan	1-5663	10-K(1992)	10(o)(1)
**10(a)(2)	Form of Cleco Corporation Executive Employment Agreement (Level 1)	1-15759	8-K(1/9/09)	10.1
10(b)(1)	401(k) Savings and Investment Plan Trust Agreement dated as of August 1, 1997, between UMB Bank, N.A. and the Company	1-5663	10-K(1997)	10(m)
10(b)(2)	401(k) Savings and Investment Plan as amended and restated effective January 1, 2004	1-5663	10-Q(3/04)	10(a)
*10(b)(3)	401(k) Savings and Investment Plan, Stock Trust Agreement, Amendment Number 1, Effective January 1, 1999
10(b)(4)	401(k) Savings and Investment Plan, Stock Trust Agreement, Amendment Number 2, Effective January 1, 2004	1-5663	10-Q(6/04)	10(b)
10(b)(5)	401(k) Savings and Investment Plan, Stock Trust Agreement, Amendment Number 3, Effective October 1, 2005	1-5663	10-Q(9/05)	10(e)
10(b)(6)	401(k) Savings and Investment Plan, Stock Trust Agreement, Amendment Number 4 (designated as Amendment Number 3 in exhibit 10(b), Effective January 1, 2007	1-5663	10-Q(3/07)	10(b)
10(b)(7)	401(k) Savings and Investment Plan, First Amendment, effective as of June 1, 2005	1-5663	10-Q(6/05)	10(b)
10(b)(8)	401(k) Savings and Investment Plan, Amended and Restated, effective October 1, 2005	333-127496	S-8(8/12/05)	10.8
10(b)(9)	401(k) Savings and Investment Plan, Amended and Restated, Amendment No. 1, Effective January 1, 2006	1-5663	10-K(2006)	10(h)(8)
10(b)(10)	401(k) Savings and Investment Plan, Amendment No. 2	1-5663	10-Q(6/07)	10.4
10(b)(11)	401(k) Savings and Investment Plan, Amendment No. 3, Effective August 1, 2007	1-5663	10-Q(9/07)	10.2
10(b)(12)	401(k) Savings and Investment Plan, Amendment No. 4, Effective January 1, 2008	1-5663	10-K(2008)	10(g)(12)
10(b)(13)	401(k) Savings and Investment Plan, Amendment No. 5 and Plan of Merger with the Cleco Energy LLC 401(k) Savings Investment Plan, effective March 1, 2009	1-5663	10-Q(3/09)	10.3
10(c)(1)	First Amended and Restated Credit Agreement dated as of June 2, 2006 among Cleco Power LLC, The Bank of New York, as Administrative Agent, and the lenders and other parties thereto	1-5663	10-Q(6/06)	10.2
10(c)(2)	Amendment No. 1 and Waiver No. 1, dated as of August 18, 2009, to and under the First Amended and Restated Credit Agreement, dated as of June 2, 2006, among Cleco Corporation and the Lenders party thereto	1-5663	10-Q(9/09)	10.5
10(d)(1)	Storm Recovery Property Sale Agreement between Cleco Katrina/Rita Hurricane Recovery Funding LLC and Cleco Power LLC, dated March 6, 2008	1-5663	8-K(3/6/08)	10.1
10(d)(2)	Storm Recovery Property Servicing Agreement between Cleco Katrina/Rita Hurricane Recovery Funding LLC and Cleco Power LLC, dated March 6, 2008	1-5663	8-K(3/6/08)	10.2
10(d)(3)	Administration Agreement between Cleco Katrina/Rita Hurricane Recovery Funding LLC and Cleco Power LLC, dated March 6, 2008	1-5663	8-K(3/6/08)	10.3

131

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

CLECO POWER		SEC FILE OR REGISTRATION NUMBER	REGISTRATION STATEMENT OR REPORT	EXHIBIT NUMBER
*12(b)	Computation of Ratios of Earnings to Fixed Charges
*23(b)	Consent of Independent Registered Public Accounting Firm
*24(b)	Power of Attorney from each Manager of Cleco Power whose signature is affixed to this Form 10-K for the year ended December 31, 2009
*31.3	CEO Certification in accordance with section 302 of the Sarbanes-Oxley Act of 2002
*31.4	CFO Certification in accordance with section 302 of the Sarbanes-Oxley Act of 2002
*32.3	CEO Certification pursuant to section 906 of the Sarbanes-Oxley Act of 2002
*32.4	CFO Certification pursuant to section 906 of the Sarbanes-Oxley Act of 2002

132

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

CLECO CORPORATION (Parent Company Only)

SCHEDULE I

Condensed Statements of Income

	FOR THE YEAR ENDED DECEMBER 31,
(THOUSANDS)	2009			2008			2007
Operating expenses
Administrative and general	$	4,045		$	1,064		$	988
Other operating (income) expense		(1,363	)		1,938			3,028
Total operating expenses	$	2,682		$	3,002		$	4,016
Operating loss		(2,682	)		(3,002	)		(4,016	)
Equity income of subsidiaries, net of tax		94,566			104,648			144,886
Interest, net		14,974			3,342			15,814
Other income		4,157			-			-
Other expense		(110	)		(5,685	)		(877	)
Income before income taxes		110,905			99,303			155,807
Income tax (expense) benefit		(4,598	)		2,838			(4,018	)
Net income		106,307			102,141			151,789
Preferred dividends requirements, net		46			46			458
Income applicable to common stock	$	106,261		$	102,095		$	151,331
The accompanying notes are an integral part of the condensed financial statements.

133

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

CLECO CORPORATION (Parent Company Only)

SCHEDULE I

Condensed Balance Sheets

	AT DECEMBER 31,
(THOUSANDS)	2009			2008
Assets
Current assets
Cash and cash equivalents	$	7,080		$	5,941
Accounts receivable - affiliate		153,150			95,039
Other accounts receivable		1,298			21
Taxes receivable		14,476			8,317
Cash surrender value of life insurance policies		24,424			17,371
Total currents assets		200,428			126,689
Equity investment in investees		1,048,321			989,012
Deferred charges		27,929			12,202
Total assets	$	1,276,678		$	1,127,903
Liabilities and shareholders’ equity
Liabilities
Current liabilities
Accounts payable - affiliate	$	18,061		$	3,327
Other current liabilities		11,362			8,767
Total current liabilities		29,423			12,094
Long-term debt, net		95,000			30,000
Deferred credits		36,183			24,944
Total liabilities		160,606			67,038
Commitments and Contingencies (Note 6)
Shareholders’ equity
Preferred stock
Not subject to mandatory redemption, $100 par value, authorized 1,491,900 shares, issued 10,288 at December 31, 2009, and 2008, respectively		1,029			1,029
Common shareholders’ equity
Common stock, $1 par value, authorized 100,000,000 shares, issued 60,277,462 and 60,066,345 shares and outstanding 60,259,368 and 60,042,514 shares at December 31, 2009, and 2008, respectively		60,277			60,066
Premium on common stock		399,148			394,517
Retained earnings		667,220			615,514
Treasury stock, at cost 18,094 and 23,831 shares at December 31, 2009, and 2008, respectively		(311	)		(428	)
Accumulated other comprehensive loss		(11,291	)		(9,833	)
Total common shareholders’ equity		1,115,043			1,059,836
Total shareholders’ equity		1,116,072			1,060,865
Total liabilities and shareholders’ equity	$	1,276,678		$	1,127,903
The accompanying notes are an integral part of the condensed financial statements.

134

CLECO CORPORATION
CLECO POWER	2009 FORM 10-K

CLECO CORPORATION (Parent Company Only)

SCHEDULE I

Condensed Statements of Cash Flows

	FOR THE YEAR ENDED DECEMBER 31,
(THOUSANDS)	2009			2008			2007
Operating activities
Net cash provided by operating activities	$	6,007		$	18,536		$	164,437
Investing activities
Equity investment in investees		(16,254	)		(6,274	)		(93,427	)
Return of equity investment in investees		850			-			96
Other investing		(2,328	)		(299	)		(1,763	)
Net cash used in investing activities		(17,732	)		(6,573	)		(95,094	)
Financing activities
Retirement of long-term obligations		-			(100,000	)		-
Issuance of long-term obligations		65,000			30,000			-
Dividends paid on preferred stock		(46	)		(46	)		(458	)
Dividends paid on common stock		(54,221	)		(54,036	)		(53,282	)
Other financing		2,131			991			10,873
Net cash provided by (used in) financing activities		12,864			(123,091	)		(42,867	)
Net increase (decrease) in cash and cash equivalents		1,139			(111,128	)		26,476
Cash and cash equivalents at beginning of period		5,941			117,069			90,593
Cash and cash equivalents at end of period	$	7,080		$	5,941		$	117,069
Supplementary cash flow information
Interest paid	$	3,119		$	5,078		$	7,000
Income tax (refunded) paid, net	$	(34,792	)	$	38,113		$	15,165
Supplementary noncash investing and financing activity
Return on equity investment in investee	$	-		$	-		$	78,200
Issuance of treasury stock – LTICP	$	117		$	103		$	86
Issuance of common stock - LTICP/ESPP	$	-		$	163		$	22,151
The accompanying notes are an integral part of the condensed financial statements.

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CLECO POWER	2009 FORM 10-K

CLECO CORPORATION (Parent Company Only) Notes to the Condensed Financial Statements

Note 1 — Summary of Significant Accounting Policies

The condensed financial statements represent the financial information required by SEC Regulation S-X 5-04 for Cleco Corporation, which requires the inclusion of parent company only financial statements if the restricted net assets of consolidated subsidiaries exceed 25% of total consolidated net assets as of the last day of its most recent fiscal year. As of December 31, 2009, Cleco Corporation’s restricted net assets of consolidated subsidiaries were $637.0 million and exceeded 25% of its total consolidated net assets.

Cleco Corporation’s major, first-tier subsidiaries consist of Cleco Power and Midstream.

Cleco Power contains the LPSC-jurisdictional generation, transmission, and distribution electric utility operations serving Cleco’s traditional retail and wholesale customers. Midstream owns and operates merchant generation stations and invests in joint ventures that own and operate merchant generation stations.

In January 2007, FERC approved the transfer of the ownership interests of Attala and Perryville to Cleco Corporation whereby Attala and Perryville would become first-tier subsidiaries of Cleco Corporation. The transfer was effective February 1, 2007.

The accompanying financial statements have been prepared to present the financial position, results of operations, and cash flows of Cleco Corporation on a stand-alone basis as a holding company. Investments in subsidiaries and other investees are stated at cost plus equity in undistributed earnings from the date of acquisition. These financial statements should be read in conjunction with Cleco’s consolidated financial statements.

Note 2 — Debt

Cleco Corporation had no short-term debt outstanding at December 31, 2009, or 2008. At December 31, 2009, Cleco Corporation’s long-term debt outstanding was $95.0 million, of which none was due within one year, compared to $30.0 million of long-term debt at December 31, 2008, of which none was due within one year.

Cleco Corporation’s $150.0 million five-year credit facility matures on June 2, 2011. At December 31, 2009, $95.0 million was outstanding under this credit facility. This facility provides for working capital and other needs. Cleco Corporation’s borrowing costs under the facility are equal to LIBOR plus 0.65%, including facility fees.

In August 2009, Cleco Corporation entered into an amendment to its credit facility that increased thresholds in a representation relating to pension plan obligations above the amount of the current plan assets. Cleco Corporation incurred $0.1 million in expenses obtaining bank waivers related to the amendments. If Cleco Corporation were to default under the covenants in its various credit facilities, it would be unable to borrow additional funds under the facilities. Further, if Cleco Power were to default under its credit facility, Cleco Corporation would be considered in default under its credit facility.

At December 31, 2009, off-balance sheet commitments and outstanding credit facility borrowings reduced available borrowings by $15.0 million and $95.0 million, respectively, leaving available capacity of $40.0 million. An uncommitted line of credit with a bank in an amount up to $10.0 million also is available to support Cleco’s working capital needs.

Note 3 — Dividends and Equity Contributions

Some provisions in Cleco Power’s debt instruments restrict the amount of equity available for distribution to Cleco Corporation by Cleco Power under specified circumstances. The most restrictive covenant requires Cleco Power’s total indebtedness to be less than or equal to 65% of total capitalization. At December 31, 2009, approximately $349.6 million of member’s equity were unrestricted. Cleco Corporation received $30.0 million in distributions from Cleco Power in 2009. No distributions were received from Cleco Power for the years ended December 31, 2008, and 2007. Cleco Corporation made no equity contributions to Cleco Power in 2009 or 2008. During 2007, Cleco Corporation made equity contributions to Cleco Power of $85.0 million.

Cleco Corporation received no distributions from Midstream during the years ended December 31, 2009 or 2007. Cleco Corporation received $9.6 million in distributions from Midstream during the year ended December 31, 2008. For the years ended December 31, 2009, 2008, and 2007, Cleco Corporation made no equity contributions to Midstream.

Note 4 — Income Taxes

Cleco Corporation (Parent Company Only) Condensed Statements of Income reflect income tax expense of $4.6 million, income tax benefit of $2.8 million, and income tax expense of $4.0 million for the years ended 2009, 2008, and 2007, respectively. In addition to these amounts, income tax expense of $5.0 million, $21.3 million, and $66.8 million is reflected in equity income of subsidiaries, net of tax for the years ended 2009, 2008, and 2007, respectively.

Note 5 — Commitments and Contingencies

For information regarding commitments and contingencies related to Cleco Corporation, see Part II, Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 15 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Off-Balance Sheet Commitments and Disclosures about Guarantees.”

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Note 6 — Subsequent Events

As of February 25, 2010, management has evaluated the potential recognition or disclosure of events or transactions that occurred in the period after the balance sheet date of December 31, 2009. The date February 25, 2010, represents the date that Cleco Corporation issued the financial statements for the year ended December 31, 2009.

Debt Issuance

City of Alexandria Settlement

On February 23, 2010, the Alexandria City Council approved a settlement of the case which included a $3.0 million litigation expense reimbursement to the City and a new five-year, energy-only power supply agreement. The supply agreement may be extended, at Cleco Power’s option, for two additional one-year terms. If the City performs its obligations under the new power supply agreement, then Cleco Corporation will pay a one-time $6.5 million performance bonus at the end of the five-year term to the City. The court dismissed the case with prejudice on February 24, 2010.

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CLECO CORPORATION

SCHEDULE II

VALUATION AND QUALIFYING ACCOUNTS

Years ended December 31, 2009, 2008, and 2007

	BALANCE AT	ADDITIONS	UNCOLLECTIBLE	BALANCE AT
	BEGINNING	CHARGED TO COSTS	ACCOUNT WRITE-OFFS	END OF
Allowance For Uncollectible Accounts (THOUSANDS)	OF PERIOD	AND EXPENSES	LESS RECOVERIES	PERIOD(1)
Year Ended December 31, 2009	$1,632	$1,657	$2,116	$1,173
YEAR ENDED DECEMBER 31, 2008	$ 1,028	$ 3,821	$ 3,217	$ 1,632
YEAR ENDED DECEMBER 31, 2007	$ 789	$ ,859	$ 2,620	$ 1,028
(1) Deducted in the consolidated balance sheet

CLECO POWER LLC

SCHEDULE II

VALUATION AND QUALIFYING ACCOUNTS

Years ended December 31, 2009, 2008, and 2007

	BALANCE AT	ADDITIONS	UNCOLLECTIBLE	BALANCE AT
	BEGINNING	CHARGED TO COSTS	ACCOUNT WRITE-OFFS	END OF
Allowance For Uncollectible Accounts (THOUSANDS)	OF PERIOD	AND EXPENSES	LESS RECOVERIES	PERIOD(1)
Year Ended December 31, 2009	$1,632	$1,657	$2,116	$1,173
Year Ended December 31, 2008	$ 1,028	$ 3,821	$ 3,217	$ 1,632
Year Ended December 31, 2007	$ 789	$ 2,859	$ 2,620	$ 1,028
(1) Deducted in the consolidated balance sheet

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SCHEDULE III

ACADIA POWER PARTNERS, LLC

Consolidated Financial Statements

December 31, 2009, 2008, and 2007

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ACADIA POWER PARTNERS, LLC

TABLE OF CONTENTS

		PAGE(S)
Report of Independent Registered Public Accounting Firm		141
Consolidated Financial Statements

Consolidated Statements of Income	142
Consolidated Balance Sheets	143
Consolidated Statements of Cash Flows	144
Consolidated Statements of Changes in Members’ Capital	145
Notes to Financial Statements	146

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Report of Independent Registered Public Accounting Firm

To the Members of

Acadia Power Partners, LLC:

In our opinion, the accompanying consolidated balance sheets and the related consolidated statements of income, changes in members' capital, and cash flows present fairly, in all material respects, the financial position of Acadia Power Partners, LLC (the “Company”) and its subsidiary at December 31, 2009 and 2008, and the results of their operations and their cash flows for each of the three years in the period ending December 31, 2009 in conformity with accounting principles generally accepted in the United States of America. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits. We conducted our audits of these statements in accordance with standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

The accompanying consolidated financial statements have been prepared assuming that the Company will continue as a going concern. As discussed in Note 4 to the consolidated financial statements, the Company's plans to sell all of the materials and supplies inventory and property, plant, and equipment. The Company's plans to sell these assets raise substantial doubt about the Company's ability to continue as a going concern. Management's plans in regard to these matters are also described in Note 5. The consolidated financial statements do not include any adjustments that might result from the outcome of this uncertainty.

As discussed in Note 8 to the consolidated financial statements, the Company has significant transactions with related parties.

/s/ PricewaterhouseCoopers LLP

New Orleans, Louisiana

February 25, 2010

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ACADIA POWER PARTNERS, LLC

Consolidated Statements of Income

	FOR THE YEAR ENDED DECEMBER 31,
	2009			2008			2007
Operating revenue
Third party revenue	$	33,750,248		$	74,002,290		$	63,549,505
Affiliate revenue		16,795,867			-			-
Total operating revenue		50,546,115			74,002,290			63,549,505
Operating expenses
Fuel used for electric generation		35,898,268			63,373,553			53,438,518
Plant operations and maintenance		22,848,731			16,079,924			12,622,699
Depreciation		9,700,816			14,818,570			15,427,232
General and administrative		5,759,256			2,409,472			2,252,563
Loss on disposal of assets		10,846,187			191,398			3,525,254
Total operating expenses		85,053,258			96,872,917			87,266,266
Gain on settlement of bankruptcy claim		-			-			170,200,000
Operating (loss) income		(34,507,143	)		(22,870,627	)		146,483,239
Other income		21,025			120,595			62,617
Net (loss) income	$	(34,486,118	)	$	(22,750,032	)	$	146,545,856
The accompanying notes are an integral part of the consolidated financial statements.

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ACADIA POWER PARTNERS, LLC

Consolidated Balance Sheets

	AT DECEMBER 31,
	2009		2008
Assets
Current assets
Cash and cash equivalents	$	6,005,550	$	1,527,179
Accounts receivable – trade (less allowance for doubtful accounts of $0 in 2009 and $540,444 in 2008)		40,104		375,640
Accounts receivable - affiliate		7,722		838
Materials and supplies inventory		2,231,888		1,991,896
Prepayments		2,514,179		1,516,857
Total current assets		10,799,443		5,412,410
Property, plant and equipment, net		403,622,445		405,565,401
Total assets	$	414,421,888	$	410,977,811
Liabilities and members’ capital
Current liabilities
Accounts payable - trade	$	520,542	$	223,907
Accounts payable - affiliate		577,233		396,885
Accrued liabilities		4,338,843		759,245
Total current liabilities		5,436,618		1,380,037
Members’ capital		408,985,270		409,597,774
Total liabilities and members’ capital	$	414,421,888	$	410,977,811
The accompanying notes are an integral part of the consolidated financial statements.

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ACADIA POWER PARTNERS, LLC

Consolidated Statements of Cash Flows

	FOR THE YEAR ENDED DECEMBER 31,
	2009			2008			2007
Cash flow from operating activities
Net (loss) income	$	(34,486,118	)	$	(22,750,032	)	$	146,545,856
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation expense		9,700,816			14,818,570			15,427,232
Provision for doubtful accounts		-			540,444			-
Loss (gain) on disposal of assets		6,381,026			(17,404	)		3,415,892
Gain on settlement of bankruptcy claim, net		-			-			(170,200,000	)
Changes in operating assets and liabilities:
Accounts receivable		335,536			(128,501	)		(349	)
Accounts receivable, affiliate		(6,884	)		(819	)		(19	)
Materials and supplies inventory		(239,992	)		(129,721	)		(86,231	)
Prepayments		(997,322	)		582,127			(198,256	)
Accounts payable, trade		296,635			74,309			149,599
Accounts payable, affiliate		180,348			(73,826	)		(211,278	)
Accrued liabilities		3,636,934			173,713			(2,059,999	)
Net cash used in operating activities	$	(15,199,021	)	$	(6,911,140	)	$	(7,217,553	)
Cash flows from investing activities
Additions to property, plant and equipment	$	(14,196,222	)	$	(484,413	)	$	(1,444,884	)
Net cash used in investing activities	$	(14,196,222	)	$	(484,413	)	$	(1,444,884	)
Cash flows from financing activities
Contributions from members	$	33,873,614		$	-		$	16,814,741
Net cash provided by financing activities	$	33,873,614		$	-		$	16,814,741
Net increase (decrease) in cash and cash equivalents		4,478,371			(7,395,553	)		8,152,304
Cash and cash equivalents at beginning of period		1,527,179			8,922,732			770,428
Cash and cash equivalents at end of period	$	6,005,550		$	1,527,179		$	8,922,732
Supplementary noncash investing and financing transactions:
Acquisitions of property, plant and equipment in accrued liabilities	$	68,941		$	11,606		$	-
Distributions to members	$	-		$	-		$	170,200,000
The accompanying notes are an integral part of the consolidated financial statements.

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ACADIA POWER PARTNERS, LLC

Consolidated Statements of Changes in Members’ Capital

	CAJUN			CAH			APH			TOTAL MEMBERS’ CAPITAL
BALANCES AT JANUARY 1, 2007	$	-		$	171,237,642		$	267,949,567		$	439,187,209
Distributions of bankruptcy settlement		-			(92,000,000	)		(78,200,000	)		(170,200,000	)
Member contributions		6,207,370			2,200,000			8,407,371			16,814,741
Net (loss) income		(5,155,079	)		85,328,007			66,372,928			146,545,856
Interest on distributions		-			(4,130,988	)		4,130,988			-
Sale of CAH interest to Cajun		162,634,661			(162,634,661	)		-			-
Payment of priority distributions		52,486,951			-			(52,486,951	)		-
BALANCES AT DECEMBER 31, 2007		216,173,903			-			216,173,903			432,347,806
Net loss		(11,375,016	)		-			(11,375,016	)		(22,750,032	)
BALANCES AT DECEMBER 31, 2008	$	204,798,887		$	-		$	204,798,887		$	409,597,774
Member contributions		16,936,807			-			16,936,807			33,873,614
Net loss		(17,243,059	)		-			(17,243,059	)		(34,486,118	)
BALANCES AT DECEMBER 31, 2009	$	204,492,635		$	-		$	204,492,635		$	408,985,270
The accompanying notes are an integral part of the consolidated financial statements.

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ACADIA POWER PARTNERS, LLC Notes to Consolidated Financial Statements

Note 1 — Description of Business and Organization

Acadia Power Partners, LLC (Acadia) is a Delaware limited liability company formed on October 13, 1999, for the purpose of designing, developing, constructing, owning, and operating a 1,160 MW natural gas-fired electric generation plant (the Facility) located in Acadia Parish, Louisiana.

Acadia’s members (the Members) are Acadia Power Holdings LLC (APH), a subsidiary of Cleco Midstream Resources LLC (Midstream), and prior to September 13, 2007, Calpine Acadia Holdings, LLC (CAH), a subsidiary of Calpine Corporation (Calpine). On September 13, 2007, CAH sold its interest in Acadia along with certain related assets to Cajun Gas Energy L.L.C. (Cajun), an affiliate of pooled investment funds managed by King Street Capital Management, L.P.

In accordance with Acadia’s Second Amended and Restated Limited Liability Company Agreement (the LLC Agreement) dated May 9, 2003, the Members each own a 50% interest in Acadia and share in profits and losses of Acadia in proportion to their ownership interests. Acadia is governed by an executive committee with two representatives from each Member.

Note 2 — Calpine Bankruptcy

Bankruptcy Proceedings

In December 2005, Calpine and certain of its subsidiaries, including CAH, Calpine Energy Services, L.P. (CES), and Calpine Central, LP (CCLP), (collectively the Calpine Debtors), filed for protection under Chapter 11 (the Bankruptcy Filing) of the United States Bankruptcy Code in the U.S. Bankruptcy Court for the Southern District of New York (the Calpine Debtors Bankruptcy Court). The Calpine Debtors continued to operate their business and manage their properties as “debtors-in-possession” under the jurisdiction of the Calpine Debtors Bankruptcy Court. Acadia did not file for bankruptcy and continued to operate in the normal course of business. However, Acadia had an operation and maintenance agreement with CCLP, an indirect, wholly owned subsidiary of Calpine, and tolling agreements with CES. For information on these agreements, see Note 8 — “Related Party Transactions.” CCLP continued to operate under the terms of the operation and maintenance agreement; however CES ceased performance under the terms of the tolling agreements in 2006.

CAH’s Bankruptcy Filing was an event of default under the LLC Agreement. The LLC Agreement provides for the business of Acadia to continue without dissolution in the event of the bankruptcy of a Member. Any actions accorded to the Members under the default provisions of the LLC Agreement were subject to approval by the Calpine Debtors Bankruptcy Court. Such actions may include, among others, acquisition of all of the Facility by a single Member, the sale of the defaulting Member’s interest, or sale of the Facility to a third party. However, APH was precluded from exercising any remedies based on the default by virtue of the automatic stay provided under the Calpine Debtors Bankruptcy Court proceedings.

In March 2006, Acadia filed a motion with the Calpine Debtors Bankruptcy Court to compel CES to perform under the then-existing power purchase agreements and to pay amounts due and owed under such agreements since the commencement of CES’s Bankruptcy Filing. On March 15, 2006, Acadia and CES amended each of the power purchase agreements, suspending Acadia’s obligations under the power purchase agreements. The Calpine Debtors Bankruptcy Court approved these amendments on March 22, 2006. The amendments resolved certain relief requested by Acadia’s motion.

Settlement Agreement

In April 2007, a settlement agreement was reached with Calpine which resolved issues related to Acadia. The settlement included the fixing of Acadia’s claims against the Calpine Debtors and an agreement by the parties to certain bidding procedures governing the sale of CAH’s interest in Acadia and certain related assets (the CAH Assets). In May 2007, the Calpine Debtors Bankruptcy Court approved the terms included in the Claims Settlement Agreement and Bidding Procedures Order.

Under the Claims Settlement Agreement, Acadia received a pre-petition general unsecured claim against CES and Calpine relating to obligations under the tolling agreements of $185.0 million. Acadia recorded the amount, net of $14.8 million discount on the sale of the claim, as a gain on settlement of the bankruptcy claim. In May 2007, Acadia made a dividend by assignment of the claim to APH and CAH.

Under the Bidding Procedures Order governing the sale of the CAH Assets, APH agreed to purchase the CAH Assets for $60.0 million plus accrued liabilities, subject to any higher or better offers. However, in July 2007, CAH conducted an auction for the CAH Assets, and Cajun emerged as the successful bidder with a bid price of $189.0 million.

The Calpine Debtors Bankruptcy Court also approved the transfer of the operations, maintenance and project management functions performed by CCLP to subsidiaries of Midstream upon the closing of the CAH asset sale.

Note 3 — Acadia Transactions

In February 2009, Cleco Power LLC (Cleco Power) announced that it had chosen the acquisition of 50% of the Acadia Power Station, or one of its two 580-MW units, as the lowest bid in its 2007 long-term Request for Proposal (RFP). Cleco Power will own and operate one unit and operate the other 580-MW unit on behalf of Acadia or a future owner.

Cleco Power and the parties executed the definitive agreements in 2009, and received Louisiana Public Service Commission (LPSC) and Federal Energy Regulatory Commission (FERC) approvals for the transaction in January 2010 and February 2010, respectively. Beginning in January 2010, Acadia operated the plant and served Cleco Power under a

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tolling agreement covering 50% of the Acadia Power Station. The tolling agreement was approved by the LPSC in October 2009 and by FERC in December 2009. The tolling agreement was terminated when the transaction closed in February 2010. For more information regarding the Cleco Power transaction, see Note 12 — “Subsequent Events.”

In October 2009, Acadia and Entergy Louisiana LLC (Entergy Louisiana) announced that definitive agreements had been executed whereby Entergy Louisiana would acquire 50% of the Acadia Power Station, or one of its two 580-MW units. The transaction is anticipated to be completed in late 2010 or early 2011. The agreements provide that, beginning in May 2010, Acadia will serve Entergy Louisiana under a tolling agreement covering 50% of the Acadia Power Station until the transaction is completed. Both the asset transaction and interim tolling agreement require regulatory approval. Cleco Power will operate both units at Acadia Power Station after the Entergy Louisiana transaction is completed.

As a result of these transactions, certain assets met the criteria of assets held for sale and Acadia therefore meets the definition of discontinued operations. For more information regarding assets held for sale, see Note 4 — “Summary of Significant Accounting Policies — Assets Held for Sale.”

Note 4 — Summary of Significant Accounting Policies

Basis of Presentation

The accompanying consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America and include the accounts of Acadia and its wholly owned subsidiary, Acadia Partners Pipeline LLC (the Pipeline). All intercompany balances have been eliminated upon consolidation.

Comparability of Financial Statements

In the income statements for the years ended December 31, 2008 and 2007, depreciation expense was based on the depreciable assets classified as held for use during the entire year. In the income statement for the year ended December 31, 2009, depreciation expense was based on the depreciable assets classified as held for use for only part of 2009. Depreciation expense ceased to be recognized when the assets met the criteria as held for sale. Depreciation ceased in July and October 2009 for units one and two, respectively.

Cash and cash equivalents, accounts receivable, and prepayments are not considered assets held for sale.

Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and disclosures of contingent assets and liabilities at the date of these financial statements. Actual results could differ from these estimates. The most significant estimates with regard to these financial statements relate to the useful lives and carrying value of the Facility, related depreciation, and impairment of property, plant and equipment.

Statements of Cash Flows

The statements of cash flows are prepared using the “indirect method.” This method requires that net income be adjusted to remove the effects of all deferrals and accruals of operating cash receipts and payments and the effects of all investing and financing cash flow items.

Fair Value of Financial Instruments

The carrying amounts reported in the balance sheets for accounts receivable and accounts payable approximate their fair values due to their short–term maturities.

Concentration of Credit Risk

The financial instruments that potentially expose Acadia to credit risk consist primarily of short-term investments classified as cash equivalents and accounts receivable.

Acadia had $5.9 million in short-term investments in an institutional money market fund at December 31, 2009. If the counterparty failed to perform under the terms of the investment, Acadia would be exposed to a loss of the invested amounts. In order to mitigate this potential credit risk, Acadia has adopted investment guidelines for investments in money market funds, which specify the size, years in existence, portfolio makeup and rating agency category.

Acadia is required to classify assets and liabilities measured at their fair value according to three different levels depending on the inputs used in determining fair value.

§	Level 1 – unadjusted quoted prices in active, liquid markets for the identical asset or liability;

§	Level 2 – quoted prices for similar assets and liabilities in active markets or other inputs that are observable for the asset or liability, including inputs that can be corroborated by observable market data, observable interest rate yield curves and volatilities;

§	Level 3 – unobservable inputs based upon the entities own assumptions.

At December 31, 2009, Acadia’s short-term investment was a Level 2 investment with a fair value of $5.9 million.

Acadia has an agreement with Tenaska to market electricity on behalf of Acadia. The agreement can be terminated upon Acadia’s seven-day notice to Tenaska. Acadia recognizes revenue for sales under the agreement as deliveries are made. Acadia’s receivables relating to these sales have exposure to trends within the energy industry, including declines in the creditworthiness of its customers. Acadia does not believe there is significant credit risk associated with Tenaska due to its payment history. For information on the marketing

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agreement, see Note 9 — “Significant Contractual Obligations — Energy Management Services Agreement.”

Cash and Cash Equivalents

Acadia considers all highly liquid investments purchased with an original maturity of three months or less to be cash equivalents. The carrying amount of these instruments approximates fair value due to their short-term maturity.

Accounts Receivable and Accounts Payable

Accounts receivable and payable represent amounts due from customers and owed to vendors, respectively, and are recorded at the invoiced amount. Outstanding accounts receivable are reviewed by management and an allowance for doubtful accounts is established, if necessary. Acadia had no allowance for doubtful accounts at December 31, 2009, compared to its December 31, 2008 balance of $0.5 million. The $0.5 million allowance at December 31, 2008, was related to over-billings from Calpine to Acadia. In 2009, the associated accounts receivable were written off against the allowance for doubtful accounts.

Materials and Supplies Inventory

Materials and supplies inventory is comprised of spare parts and is valued at the lower of cost or market. The value of large spare parts estimated to be used within one year are determined using the specific identification method when issued from inventory. For other spare parts, the value of the part when issued from inventory is generally determined using the weighted average cost method.

Prepayments

Prepayments include prepaid expenses for insurance, prepaid Long Term Program (LTP) payments, and prepaid maintenance expenses related to the outage on unit two. Prepaid expense for insurance was $0.4 million at December 31, 2009, and 2008. Prepaid LTP payments were $0.6 million and $1.1 million at December 31, 2009, and 2008, respectively. Other prepaid maintenance expenses were $1.5 million and zero at December 31, 2009, and 2008, respectively. For additional information on the LTP, see Note 10 — “Commitments and Contingencies — Long Term Program.”

Assets Held for Sale

A group of assets that meet the following criteria are considered held for sale:

§	A plan to sell has been approved by a level of management with authority;

§	The asset is substantially available for immediate sale;

§	An active program to find a buyer has been initiated;

§	Except for events beyond an entity’s control (such as obtaining regulatory approvals), the sale of the asset within one year is probable;

§	The sale price is reasonable compared to its current fair market value; and

§	It is unlikely there will be significant changes to the plan or the plan will be withdrawn.

While an asset is held for sale, depreciation expense ceases to be recognized. At December 31, 2009, Acadia’s materials and supplies and long-lived assets at a carrying cost of $2.2 million and $403.6 million, respectively, met the criteria as held for sale. Concurrent with the classification as held for sale, Acadia performed an impairment test by comparing the fair market value less cost to sell to the carrying value of the assets. Since the fair market value less cost to sell was greater than the carrying value of the assets, no impairment was recognized.

Property, Plant and Equipment, Net

Property, plant and equipment, net is stated at cost less accumulated depreciation. Asset additions, when ready for their intended use, are transferred from construction work in progress to property, plant and equipment. Upon retirement or disposition, the difference between the net book value of the property and any proceeds received from the property is recorded as a gain or loss on asset disposition on the income statement. Any costs incurred to remove the asset are charged to expense.

The cost of repairs and minor replacements is charged to expense as incurred. The costs of substantial improvements are capitalized. Removal costs are expensed as incurred.

Property, plant and equipment, net of estimated salvage value of 10% is depreciated using the straight-line method over the estimated useful lives of the assets, generally 35 years for Acadia’s power plant assets, including interconnect pipelines. For all power plant assets with useful lives of 10 years or less, no salvage value is estimated. Annual depreciation provisions expressed as a percentage of total depreciable property for Acadia were 1.97% for 2009, 2.99% for 2008, and 3.11% for 2007.

In July 2009, unit one and half of the common facilities met the criteria as held for sale. In October 2009, the remaining unit two and common facilities met the criteria as held for sale. Depreciation expense ceased to be recognized on the respective plant in those months. Assets held for sale are reported at the lower of their fair value or net book value. An impairment test determined that the net book value of property, plant and equipment was lower than the fair market value; therefore, the amounts are reported on the depreciated cost basis. At December 31, 2009 and 2008, the components of property, plant and equipment, net consisted of the following:

				AT DECEMBER 31,
	2009			2008
Buildings, machinery and equipment	$	490,701,548		$	495,260,548
Land		2,777,618			2,777,618
Construction work in progress		1,177,457			266,927
Less: Accumulated Depreciation		(91,034,177	)		(92,739,692	)
Property, plant and equipment, net	$	403,622,446		$	405,565,401

The decreases in buildings, machinery and equipment, and accumulated depreciation were due to retirements related to a planned outage. For additional information on the outage, see Note 10 — “Commitments and Contingencies — Planned

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and Unscheduled Outages.” For the years ended December 31, 2009, 2008, and 2007, depreciation expense was $9.7 million, $14.8 million, and $15.4 million, respectively.

In accordance with the authoritative guidance on assets, Acadia evaluates the impairment of long-lived assets based on the projection of undiscounted cash flows whenever events or changes in circumstances indicate that the carrying amounts of such assets may not be recoverable. In accordance with these guidelines, such cash flows do not include interest or tax expense cash outflows. In the event such cash flows are not expected to be sufficient to recover the recorded value of the assets, the assets are written down to their estimated fair values.

Major Maintenance

During 2009 and 2008, as major maintenance occurred and as parts were replaced on the plant’s steam and combustion turbines, the maintenance costs were either expensed or transferred to property, plant and equipment and depreciated over the parts’ estimated useful lives, which is generally three to six years, depending on the nature of maintenance activity performed under the LTP in place at that time.

In January 2008, the LTP was amended, which amendment modified the maintenance and payment schedules. Under the amended LTP, major parts are now warrantied. Acadia makes quarterly payments to Siemens Energy based on a combination of the number of plant starts and/or run hours in that period. These payments are expensed as incurred. As outages occur, Acadia is billed for labor related to the outage and any parts not covered under the warranty. The labor is expensed as incurred, and accruals are recorded through the normal accounts payable process.

Revenue Recognition

In April 2006, Acadia entered into an agreement with Tenaska Power Services Company (Tenaska) to market electricity from Acadia. Acadia recognizes revenue for sales under the agreements as deliveries are made. For information on the marketing agreement, see Note 9 — “Significant Contractual Obligations — Energy Management Services Agreement.”

Acadia had a short-term power purchase agreement with Cleco Power for the months of March 2009 through September 2009. This agreement was approved by both FERC and the LPSC. Acadia recognized revenue for these sales as deliveries were made. For more information on the short-term power purchase agreement, see Note 8 — “Related Party Transactions — Power Purchase Agreement with Cleco Power.”

Other (Expense) Income

Other (expense) income is primarily removal costs related to property, plant and equipment, partially offset by interest income. For the years ended December 31, 2009 and 2008, removal costs were $10.8 million and $0.2 million, respectively. There were no removal costs in 2007.

Income Taxes

Acadia is a limited liability company and, for tax purposes, has elected to be treated as a partnership. The financial results of Acadia are included in tax returns of the individual members. Accordingly, no recognition has been given to income taxes in these consolidated financial statements.

Note 5 — Future Operations

The accompanying consolidated financial statements have been prepared assuming that Acadia will continue as a going concern.

At December 31, 2009, certain Acadia assets were considered assets held for sale due to the pending transactions between Acadia and Cleco Power and Entergy Louisiana. The Cleco Power transaction was completed in February 2010. If the Entergy Louisiana transaction is also completed, Acadia will no longer own any materials and supply inventory, property, plant and equipment, or land. Ongoing operations will be minimal, related only to the previously established receivables and payables and servicing of indemnities. Acadia will therefore meet the definition of discontinued operations. For additional information regarding the Cleco Power and Entergy Louisiana transactions, see Note 3 — “Acadia Transactions” and Note 12 — “Subsequent Events.”

If the Entergy Louisiana transaction does not occur, Acadia plans to continue to have a third party market electricity on its behalf. However, marketing opportunities for Acadia are significantly impacted by the price of gas, the current over supply of gas-fired generation in the region, and transmission availability which can in turn limit the number of possible customers for Acadia’s output. Due to these factors, management can not predict whether it or the third party marketer will be successful in its marketing efforts. Management plans to continue to identify potential customers and continue bilateral discussions with counterparties for long-term sales and similar agreements to further hedge Acadia’s exposure to market risk. However, due to these uncertainties and without the addition of non-operating cash flow such as external financing and/or additional equity from Acadia’s members, neither of which are assured or readily available, there is substantial doubt about Acadia’s ability to continue as a going concern. The consolidated financial statements do not include any adjustments to reflect the possible future effects on the recoverability and classification of assets or the amount and classification of liabilities that may result from the outcome of these uncertainties.

Note 6 — Business Risks

Several current issues in the power industry could have an effect on Acadia’s financial performance. Some of the business risks that could cause future results to differ from historical results include: (1) legislative and regulatory initiatives regarding deregulation, regulation or restructuring of the electric utility industry; (2) the extent and timing of the entry of additional competition in the market in which Acadia operates;

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(3) state, federal and other rate regulations in the areas in which Acadia does business; (4) changes in or application of environmental and other laws and regulations to which Acadia is subject; (5) changes in market conditions, including developments in energy and commodity supply, volume and pricing; (6) weather and other natural phenomena; (7) the direct or indirect effects on the business resulting from the financial difficulties of competitors of Acadia, including but not limited to, their effects on liquidity in the trading and power industry and the views of the capital markets regarding the energy or trading industry; and (8) LPSC and FERC approvals of the plans to dispose of Acadia’s assets as planned.

Note 7 — Recent Authoritative Guidance

Acadia adopted, or will adopt, the recent authoritative guidance listed below on their respective effective dates.

In December 2007, the Financial Accounting Standards Board (FASB) issued authoritative guidance on consolidations, which gives guidelines on the presentation and disclosure of noncontrolling interests (currently known as minority interests) of consolidated subsidiaries. This statement requires the noncontrolling interest to be included in the equity section of the balance sheet, requires disclosure on the face of the consolidated income statement of the amounts of consolidated net income attributable to the consolidated parent and the noncontrolling interest, and expands disclosures. The provisions of this statement are to be applied prospectively to fiscal years beginning on or after December 15, 2008. Early adoption of this statement is prohibited. The adoption of this statement will only impact the financial condition and results of operations of Acadia if it is involved in transactions within the scope of this statement after its effective date.

In September 2009, FASB issued various technical corrections to the Accounting Codification that did not have a material effect on the financial condition or results of operations of Acadia.

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Implementation of this amendment did not have an impact on the financial condition or results of operations of Acadia.

Note 8 — Related Party Transactions

Project Management Agreement/Operations and Maintenance Agreement

Acadia contracted with CCLP to provide project management services, which included the operation of the Facility and administrative and billing services, and operation and maintenance of the generating assets, under two separate agreements. The project management agreement (PMA) was dated February 29, 2000, and the operating and maintenance (O&M) agreement was dated July 27, 2001. Both were set to terminate on February 29, 2050, unless terminated by CCLP with 90 days notice. Acadia reimbursed CCLP for costs and expenses of $7.3 million in Plant operations and maintenance expense for the year ended December 31, 2007.

Beginning September 14, 2007, upon the closing of the CAH asset sale and with approval of the Calpine Debtors Bankruptcy Court, the project management function and the operation and maintenance functions were transferred to APH, who subsequently contracted with Cleco Generation Services LLC (Generation Services) and Cleco Support Group LLC (Support Group) to provide project management and O&M services. Generation Services is a subsidiary of Midstream and Support Group is a subsidiary of Cleco Corporation. The responsibilities and duties to be performed by Generation Services and Support Group under the PMA and the O&M agreements are the same as the responsibilities of CCLP under the original PMA and O&M agreements. For the years ended December 31, 2009, and 2008, Acadia recorded expenses to Generation Services of $4.5 million and $3.5 million, respectively, for O&M services. For the year ended December 31, 2009, and 2008, Acadia recorded expenses to Support Group of $1.1 million and $1.0 million, respectively, for project management services. At December 31, 2009, Acadia had affiliate payable balances of $0.4 million and $0.1 million to Generation Services and Support Group, respectively.

Electric Service Agreement

Acadia has an agreement for electric service with Cleco Power, a subsidiary of Cleco Corporation, dated December 15, 2001. The agreement covers electrical purchases of the Facility pursuant to Cleco Power’s LPSC Rate Schedule GS and its Rider Schedule for Long-Term Economic Development Services, subject to approval by the LPSC. Based on this agreement, Acadia recognized expenses of $1.9 million, $2.2 million and $2.1 million in Plant operations and maintenance expense for electricity received for the years ended December 31 2009, 2008, and 2007, respectively.

Interconnection and Operating Agreement

Acadia has an Interconnection and Operating Agreement with Cleco Power, dated February 25, 2000, pursuant to which Acadia’s Facility is interconnected to Cleco Power’s adjacent transmission facilities. Acadia is obligated to construct, own, operate and maintain all the interconnection facilities and equipment on its side of the point of interconnections, and Cleco Power is obligated to construct, own, operate, and maintain the interconnection facilities and equipment on its side of the point of interconnection. Based on this agreement, Acadia paid Cleco Power for the operation and maintenance of Acadia’s interconnection facilities and recognized expenses of less than $0.1 million in Plant operations and maintenance expense for each of the years ended December 31, 2009, 2008, and 2007.

Power Purchase Agreement with Cleco Power

Acadia had a short-term power purchase agreement with Cleco Power to provide 235-MW peaking product to Cleco Power. The product was for supply that started March 1, 2009, and ended October 1, 2009. Approvals from the LPSC and FERC were obtained for the agreement. The total affiliate revenue recognized for the Cleco Power power purchase agreement for the year ended December 31, 2009, was $16.8 million.

Other

Cleco Corporation routinely makes purchases on behalf of Acadia or makes payments for Acadia as financial obligations of Acadia arise. Amounts are reimbursed to Cleco Corporation by Acadia throughout the year. These purchases and/or payments amounted to $0.2 million, $1.3 million, and $0.1 million for the years ended December 31, 2009, 2008, and 2007, respectively. At December 31, 2009, and 2008, the balance owed to Cleco Corporation for these transactions was less than $0.1 million.

Note 9 — Significant Contractual Obligations

Energy Management Services Agreement

In April 2006, Acadia entered into an agreement with Tenaska to market electricity from Acadia. The agreement can be terminated upon Acadia’s seven-day notice to Tenaska. For the years ended December 31, 2009, 2008, and 2007, Acadia recognized $33.7 million, $74.0 million, and $63.5 million, respectively, in revenues related to this agreement. Acadia recognized $35.6 million, $63.3 million, and $53.3 million in operating expense related to this agreement for the years ended December 31, 2009, 2008, and 2007, respectively.

Tolling Agreements

In October 2000, Acadia entered into a tolling agreement with Aquila that was effective for 20 years beginning July 1, 2002. In May 2003, Acadia terminated this tolling agreement with Aquila in return for a cash settlement of $105.5 million. CAH and APH agreed to distribute the proceeds as follows: (i) CAH received the $105.5 million cash distribution in 2003; (ii) APH was entitled to receive an annual priority cash distribution of $14.0 million starting from July 2003 through June 30, 2022; (iii) all distributions in excess of the first $14.0 million were allocated between members in accordance with their respective interest; (iv) the priority distributions included

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imputed interest based on the rate of approximately 12.1%. Imputed interest for the years ended December 31, 2007 and 2006, of $4.1 million and $6.0 million, respectively, was recorded as an adjustment to the Member capital balances of APH and CAH. Due to the 2007 payment of the priority distributions, there was no imputed interest for the years ended December 31, 2008, and 2009.

The priority distribution for 2006 was not paid or accrued by Acadia due to the fact that there was no distributable cash, the management committee did not declare a distribution and there was uncertainty as to whether cash would be available and whether the management committee would declare a distribution in the future. Under the LLC Agreement, priority distributions are cumulative, but only to the extent of available distributable cash and management committee declaration.

In September 2007, subsequent to the approval of the Calpine Debtors Bankruptcy Court and the sale of the CAH Assets to Cajun, APH received payment from Cajun in the amount of $60.0 million for the agreed upon value of the priority distributions. The $60.0 million distributions, reduced by interest on the distribution previously recorded, is reflected in the Consolidated Statements of Changes in Members’ Capital for the year 2007.

Pipeline Operating Agreement

Millennium Midstream Energy, LLC assumed responsibility for pipeline operations and maintenance in 2005 under the Pipeline Operations Agreement. The agreement covers all operations, repair, improvements, alterations, inspections, testing, protection, and other operations and activities that are necessary to maintain pipeline assets in accordance with federal safety and maintenance standards and the regulations of the Louisiana Office of Conservation, and to accomplish the business objectives of Acadia. Acadia recognized expense of $0.1 million in Plant operations and maintenance expense for the year ended December 31, 2007 for these services. Acadia terminated this agreement in the first quarter of 2007, and responsibilities were assumed by Cleco Corporation.

In January 2008, Acadia executed a new pipeline operation and maintenance agreement with GT Operating Company LLC. Acadia recognized expenses of $0.1 million in Plant operations and maintenance expense for each of the years ended December 31, 2009 and 2008, respectively. Management anticipates no significant change to the level of payments for pipeline operations and maintenance in the future.

Note 10 — Commitments and Contingencies

Long-Term Program

Acadia entered into a LTP for spare parts, maintenance and related technical services on May 3, 2002 with Siemens Energy. The term of the agreement, with respect to each of Acadia’s four combustion turbines, began upon the commercial operation date and terminates on an individual combustion turbine basis at the end of the scheduled maintenance following the second major inspection of each respective combustion turbine or sixteen years, whichever comes first. In August 2006, an amendment was made to the LTP which established maintenance and payment schedules based on estimates of the number of starts in a given period. The actual timing of maintenance may vary based on actual starts versus estimated starts due to operational and performance considerations. Prior to this amendment, the maintenance and payment schedules were based on the estimated number of run hours.

In January 2008, Acadia and Siemens Energy executed an amendment to the LTP modifying the maintenance and payment schedules based on the number of plant starts and/or run hours. The purpose of the amendment was to attempt to better stabilize maintenance costs incurred for planned outages. Management anticipates no significant change to the current level of maintenance payments made to Siemens Energy in the future.

Planned and Unscheduled Outages

In 2007, based on updated 2006 outage information relating to the combustion gas turbine unit CT-25, an additional $0.4 million of net book value for turbine parts was charged to expense. Also in May and June of 2007, combustion gas turbine unit CT-11 had a planned one-month outage to perform work on the hot gas path (HGP). Turbine parts with a net book value of $3.1 million were charged to expense.

Siemens Energy replaced the Generator Rotor Pole Cross-Over on CT-24 and CT-25 generators during a planned outage in February 2008. This resulted in removal expense of $0.2 million and asset retirements of less than $0.1 million.

In the first and second quarters of 2009, Siemens Energy completed several projects at Acadia during an extended planned outage. The Generator Rotor Pole Cross-Over on CT-11 and CT-12 generators were replaced resulting in removal expense of $0.2 million and asset retirements of less than $0.1 million. Several High Pressure (HP), Intermediate Pressure (IP), and Low Pressure (LP) stationary and/or rotating blades and seals on Steam Turbine 13 and some of the HP blades on Steam Turbine 26 were replaced. This resulted in removal costs of $1.4 million and asset retirements of $2.0 million. Siemens Energy also performed Stator Coil Rewinds on CT-11 and CT-12. Generator parts with a net book value of $1.6 million and removal costs of $1.3 million were charged to expense.

In the fall of 2009, Siemens Energy began replacing several rows of HP, IP, and LP stationary and/or rotating blades on Steam Turbine 26. As of December 31, 2009, removal costs were $0.6 million and retirements totaled $1.0 million. Steam Turbine 26 blade replacements are expected to be completed in the first quarter of 2010. National Electric Coil began Stator Coil Rewinds on CT-24 and CT-25 in the fall of 2009. Stator Coil removal costs were $1.0 million and asset retirements were $1.7 million. The Stator Coil Rewinds on CT-24 and CT-25 are expected to be completed in the first quarter of 2010.

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Acadia Metering Dispute

A potential electric metering error issue surfaced as a result of a 2005 review of the metering at the Facility. The potential error caused Acadia to unknowingly generate excess power during the period June 2002 through May 2005, for which it received no compensation. Acadia’s management decided that a right to assert a claim for compensation existed against a company with a transmission interconnection with the Facility. In April 2007, Acadia assigned to each of its Members the right to assert a claim for 50% of the potential compensation owed by this company.

Other Contingencies

Acadia is involved in various legal and litigation matters arising in the normal course of business. Management does not expect that the outcome of these proceedings will have a material adverse effect on the financial position, results of operations or cash flows of Acadia.

Note 11 — Environmental Matters

The state of Louisiana regulates air and water emissions from Acadia’s facility under the authority of the Louisiana Department of Environmental Quality (LDEQ). In addition, the LDEQ has been delegated authority over and implements certain environmental regulatory programs established by the United States Environmental Protection Agency under the Clean Air Act and the Clean Water Act. The LDEQ establishes specific standards for performance and requires permits for certain electric generating units in Louisiana. Acadia is currently in compliance in all material respects with the LDEQ regulations as well as its air and water permit requirements.

However, on May 1, 2009, the Acadia Power Station became subject to certain daily maximum and monthly average discharge limitations for total sulfate under the terms of LPDES Water Discharge Permit No. LA0112836, issued by the LDEQ in April 2006. The facility was unable to achieve compliance with these discharge limitations and received a compliance order from the LDEQ on July 31, 2009, to address the total sulfate violations. In that compliance order, the LDEQ also noted violations of various daily maximum temperatures and whole effluent toxicity limits. The LDEQ also found that Acadia had previously corrected and resubmitted discharge monitoring reports for four months in 2007, which the LDEQ contends are not timely submittals. The LDEQ included these violations as well as the total sulfate violations in the compliance order. Acadia believes that the total sulfate limits in the LPDES permit were calculated in error and were erroneously low and as such applied for a permit modification to increase the total sulfate limitations in the permit. Acadia has now received a modified water discharge permit from the LDEQ which contains increased total sulfate limitations that can be met by the facility. Acadia is operating in compliance with and under the terms of the modified LPDES permit and has requested that the LDEQ close the compliance order. However, the LDEQ does have the ability to seek enforcement action on the violations of the water discharge permit limits experienced prior to the receipt of the water discharge permit modification. For each of the violations described above, the LDEQ has the right to seek civil penalties. At this time, Acadia is unable to determine whether the LDEQ will pursue any civil penalties as part of this enforcement action or what the penalty amounts will be.

Note 12 — Subsequent Events

As of February 25, 2010, management has evaluated the potential recognition or disclosure of events or transactions that occurred in the period after the balance sheet date of December 31, 2009. The date December 31, 2009, represents the date that Acadia issued the financial statements for the year ended December 31, 2009.

On February 23, 2010, the acquisition by Cleco Power of one of Acadia’s two 580-MW units, the related materials and supplies, and half of common facilities was completed. The significant terms of the transaction are:

§	Cleco Power acquired one of Acadia’s two 580-MW units, the related materials and supplies, and half of the common facilities for $304.0 million;

§	Acadia will recognize a gain of approximately $87 million;

§	APH received $6.7 million from an affiliate of Cajun for indemnification of Cajun and its affiliates against 100% of APH’s liabilities and other obligations related to the Cleco Power transaction; and

§	Cleco Power will own and operate the unit at Acadia and operate the remaining unit on behalf of Acadia or a future owner.

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Signatures

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this Report to be signed on its behalf by the undersigned, thereunto duly authorized.

		CLECO CORPORATION
		(Registrant)

	By:	/s/ Michael H. Madison
		(Michael H. Madison)
		(President, Chief Executive Officer and Director)

Date: February 25, 2010

Pursuant to the requirements of the Securities Exchange Act of 1934, this Report has been signed below by the following persons on behalf of the Registrant and in the capacities and on the dates indicated.

SIGNATURE	TITLE	DATE

/s/ Michael H. Madison	President, Chief Executive Officer and Director	February 25, 2010
(Michael H. Madison)	(Principal Executive Officer)
/s/ Darren J. Olagues	Senior Vice President & CFO	February 25, 2010
(Darren J. Olagues)	(Principal Financial Officer)
/s/ R. Russell Davis	Vice President – Investor Relations & CAO	February 25, 2010
(R. Russell Davis)	(Principal Accounting Officer)

	DIRECTORS*
	SHERIAN G. CADORIA
	RICHARD B. CROWELL
	J. PATRICK GARRETT
	ELTON R. KING
	LOGAN W. KRUGER
	WILLIAM L. MARKS
	ROBERT T. RATCLIFF, SR.
	PETER M. SCOTT III
	WILLIAM H. WALKER, JR.
	W. LARRY WESTBROOK

*By:	/s/ Michael H. Madison		February 25, 2010
	(Michael H. Madison, as Attorney-in-Fact)

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Signatures

		CLECO POWER LLC
		(Registrant)

	By:	/s/ Michael H. Madison
		(Michael H. Madison)
		(Chief Executive Officer and Manager)

Date: February 25, 2010

SIGNATURE	TITLE	DATE

/s/ Michael H. Madison	Chief Executive Officer and Manager	February 25, 2010
(Michael H. Madison)	(Principal Executive Officer)
/s/ Darren J. Olagues	Senior Vice President & CFO	February 25, 2010
(Darren J. Olagues)	(Principal Financial Officer)
/s/ R. Russell Davis	Vice President – Investor Relations & CAO	February 25, 2010
(R. Russell Davis)	(Principal Accounting Officer)

	MANAGERS*
	SHERIAN G. CADORIA
	RICHARD B. CROWELL
	J. PATRICK GARRETT
	ELTON R. KING
	LOGAN W. KRUGER
	WILLIAM L. MARKS
	ROBERT T. RATCLIFF, SR.
	PETER M. SCOTT III
	WILLIAM H. WALKER, JR.
	W. LARRY WESTBROOK

*By:	/s/ Michael H. Madison		February 25, 2010
	(Michael H. Madison, as Attorney-in-Fact)

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